Kosmos Energy (KOS) 10-Q 9 Nov 20 2020 Q3 Quarterly report Financial data

Cover

Cover - shares	9 Months Ended
	Sep. 30, 2020	Nov. 06, 2020
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2020
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		405,455,048
Entity Central Index Key	0001509991
Amendment Flag	false
Current Fiscal Year End Date	--12-31
Document Fiscal Year Focus	2020
Document Fiscal Period Focus	Q3

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Current assets:
Cash and cash equivalents	$ 300,819	$ 224,502
Restricted cash	827	4,302
Receivables:
Joint interest billings, net	36,423	81,424
Oil sales	29,227	64,142
Other	19,633	28,727
Inventories	142,232	114,412
Prepaid expenses and other	32,806	36,192
Derivatives	30,499	12,856
Total current assets	592,466	566,557
Property and equipment:
Oil and gas properties, net	3,354,484	3,624,751
Other property, net	11,820	17,581
Property and equipment, net	3,366,304	3,642,332
Other assets:
Restricted cash	542	542
Long-term receivables	101,118	43,430
Deferred financing costs, net of accumulated amortization of $16,643 and $14,681 at September 30, 2020 and December 31, 2019, respectively	4,359	6,321
Deferred tax assets	0	32,779
Derivatives	7,104	2,302
Other	21,608	22,969
Total assets	4,093,501	4,317,232
Current liabilities:
Accounts payable	184,086	149,483
Accrued liabilities	186,630	380,704
Current maturities of long-term debt	169,905	0
Derivatives	24,589	8,914
Total current liabilities	565,210	539,101
Long-term liabilities:
Long-term debt, net	2,191,433	2,008,063
Derivatives	6,283	11,478
Asset retirement obligations	247,564	230,526
Deferred tax liabilities	624,156	653,221
Other long-term liabilities	33,291	33,141
Total long-term liabilities	3,102,727	2,936,429
Stockholders’ equity:
Preference shares, $0.01 par value; 200,000,000 authorized shares; zero issued at September 30, 2020 and December 31, 2019	0	0
Common stock, $0.01 par value; 2,000,000,000 authorized shares; 449,673,344 and 445,779,367 issued at September 30, 2020 and December 31, 2019, respectively	4,497	4,458
Additional paid-in capital	2,300,586	2,297,221
Accumulated deficit	(1,642,512)	(1,222,970)
Treasury stock, at cost, 44,263,269 shares at September 30, 2020 and December 31, 2019, respectively	(237,007)	(237,007)
Total stockholders’ equity	425,564	841,702
Total liabilities and stockholders’ equity	$ 4,093,501	$ 4,317,232

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Statement of Financial Position [Abstract]
Deferred financing costs, accumulated amortization	$ 16,643	$ 14,681
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)	449,673,344	445,779,367
Treasury stock shares (in shares)	44,263,269	44,263,269

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands	Mar. 26, 2020	Sep. 30, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Revenues and other income:
Oil and gas revenue		$ 224,786,000			$ 357,036,000			$ 529,880,000	$ 1,049,759,000
Other income, net		1,000			(66,000)			2,000	(65,000)
Total revenues and other income		224,787,000			356,970,000			529,882,000	1,049,694,000
Costs and expenses:
Oil and gas production		84,277,000			95,540,000			234,627,000	266,316,000
Facilities insurance modifications, net		2,465,000			12,569,000			10,555,000	(5,174,000)
Exploration expenses		13,977,000			22,773,000			74,293,000	83,022,000
General and administrative		18,269,000			24,723,000			57,366,000	88,703,000
Depletion, depreciation and amortization		111,231,000			146,653,000			326,390,000	416,186,000
Impairment of long-lived assets		0	$ 0		0			150,820,000	0
Interest and other financing costs, net		27,068,000			30,721,000			83,177,000	125,565,000
Derivatives, net		1,187,000			(27,016,000)			(34,776,000)	35,884,000
Other expenses, net		2,805,000			11,472,000			27,962,000	11,798,000
Total costs and expenses		261,279,000			317,435,000			930,414,000	1,022,300,000
Income (loss) before income taxes		(36,492,000)			39,535,000			(400,532,000)	27,394,000
Income tax expense		892,000			23,470,000			19,010,000	47,398,000
Net income (loss)		$ (37,384,000)	$ (199,391,000)	$ (182,767,000)	$ 16,065,000	$ 16,837,000	$ (52,906,000)	$ (419,542,000)	$ (20,004,000)
Net income (loss) per share:
Basic (in dollars per share)		$ (0.09)			$ 0.04			$ (1.04)	$ (0.05)
Diluted (in dollars per share)		$ (0.09)			$ 0.04			$ (1.04)	$ (0.05)
Weighted average number of shares used to compute net income (loss) per share:
Basic (in shares)		405,409			401,466			405,131	401,319
Diluted (in shares)		405,409			410,992			405,131	401,319
Dividends declared per common share (in dollars per share)	$ 0.0452	$ 0		$ 0.0452	$ 0.0452	$ 0.0452	$ 0.0452	$ 0.0452	$ 0.1356

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, 2018		442,915
Balance at the beginning at Dec. 31, 2018	$ 941,478	$ 4,429	$ 2,341,249	$ (1,167,193)	$ (237,007)
Increase (Decrease) in Shareholders' Equity
Dividends ($0.0452 per share)	(18,744)		(18,744)
Equity-based compensation	8,744		8,744
Restricted stock awards and units (in shares)		2,610
Restricted stock awards and units	0	$ 26	(26)
Purchase of treasury stock / tax withholdings	(1,979)		(1,979)
Net income (loss)	(52,906)			(52,906)
Balance at the end (in shares) at Mar. 31, 2019		445,525
Balance at the end at Mar. 31, 2019	$ 876,593	$ 4,455	2,329,244	(1,220,099)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends declared per common stock (in dollars per share)	$ 0.0452
Balance at the beginning (in shares) at Dec. 31, 2018		442,915
Balance at the beginning at Dec. 31, 2018	$ 941,478	$ 4,429	2,341,249	(1,167,193)	(237,007)
Increase (Decrease) in Shareholders' Equity
Net income (loss)	(20,004)
Balance at the end (in shares) at Sep. 30, 2019		445,757
Balance at the end at Sep. 30, 2019	$ 891,030	$ 4,458	2,310,776	(1,187,197)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends declared per common stock (in dollars per share)	$ 0.1356
Balance at the beginning (in shares) at Mar. 31, 2019		445,525
Balance at the beginning at Mar. 31, 2019	$ 876,593	$ 4,455	2,329,244	(1,220,099)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends ($0.0452 per share)	(18,740)		(18,740)
Equity-based compensation	9,525		9,525
Restricted stock awards and units (in shares)		113
Restricted stock awards and units	0	$ 1	(1)
Purchase of treasury stock / tax withholdings	(4)		(4)
Net income (loss)	16,837			16,837
Balance at the end (in shares) at Jun. 30, 2019		445,638
Balance at the end at Jun. 30, 2019	$ 884,211	$ 4,456	2,320,024	(1,203,262)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends declared per common stock (in dollars per share)	$ 0.0452
Dividends ($0.0452 per share)	$ (18,753)		(18,753)
Equity-based compensation	9,507		9,507
Restricted stock awards and units (in shares)		119
Restricted stock awards and units	0	$ 2	(2)
Net income (loss)	16,065		0	16,065
Balance at the end (in shares) at Sep. 30, 2019		445,757
Balance at the end at Sep. 30, 2019	$ 891,030	$ 4,458	2,310,776	(1,187,197)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends declared per common stock (in dollars per share)	$ 0.0452
Balance at the beginning (in shares) at Dec. 31, 2019		445,779
Balance at the beginning at Dec. 31, 2019	$ 841,702	$ 4,458	2,297,221	(1,222,970)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends ($0.0452 per share)	(18,918)		(18,918)
Equity-based compensation	10,078		10,078
Restricted stock awards and units (in shares)		3,590
Restricted stock awards and units	0	$ 36	(36)
Purchase of treasury stock / tax withholdings	(4,947)		(4,947)
Net income (loss)	(182,767)			(182,767)
Balance at the end (in shares) at Mar. 31, 2020		449,369
Balance at the end at Mar. 31, 2020	$ 645,148	$ 4,494	2,283,398	(1,405,737)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends declared per common stock (in dollars per share)	$ 0.0452
Balance at the beginning (in shares) at Dec. 31, 2019		445,779
Balance at the beginning at Dec. 31, 2019	$ 841,702	$ 4,458	2,297,221	(1,222,970)	(237,007)
Increase (Decrease) in Shareholders' Equity
Net income (loss)	(419,542)
Balance at the end (in shares) at Sep. 30, 2020		449,673
Balance at the end at Sep. 30, 2020	$ 425,564	$ 4,497	2,300,586	(1,642,512)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends declared per common stock (in dollars per share)	$ 0.0452
Balance at the beginning (in shares) at Mar. 31, 2020		449,369
Balance at the beginning at Mar. 31, 2020	$ 645,148	$ 4,494	2,283,398	(1,405,737)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends ($0.0452 per share)	24		24
Equity-based compensation	8,406		8,406
Restricted stock awards and units (in shares)		206
Restricted stock awards and units	0	$ 2	(2)
Net income (loss)	(199,391)			(199,391)
Balance at the end (in shares) at Jun. 30, 2020		449,575
Balance at the end at Jun. 30, 2020	454,187	$ 4,496	2,291,826	(1,605,128)	(237,007)
Increase (Decrease) in Shareholders' Equity
Dividends ($0.0452 per share)	27		27
Equity-based compensation	8,734		8,734
Restricted stock awards and units (in shares)		98
Restricted stock awards and units	0	$ 1	(1)
Net income (loss)	(37,384)			(37,384)
Balance at the end (in shares) at Sep. 30, 2020		449,673
Balance at the end at Sep. 30, 2020	$ 425,564	$ 4,497	$ 2,300,586	$ (1,642,512)	$ (237,007)
Increase (Decrease) in Shareholders' Equity
Dividends declared per common stock (in dollars per share)	$ 0

CONSOLIDATED STATEMENTS OF ST_2

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - $ / shares	Mar. 26, 2020	Sep. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Statement of Stockholders' Equity [Abstract]
Dividends declared per common stock (in dollars per share)	$ 0.0452	$ 0	$ 0.0452	$ 0.0452	$ 0.0452	$ 0.0452	$ 0.0452	$ 0.1356

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Operating activities
Net loss	$ (419,542,000)	$ (20,004,000)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depletion, depreciation and amortization (including deferred financing costs)	333,120,000	423,160,000
Deferred income taxes	3,715,000	(69,840,000)
Unsuccessful well costs and leasehold impairments	24,338,000	7,361,000
Impairment of long-lived assets	150,820,000	0
Change in fair value of derivatives	(32,156,000)	34,003,000
Cash settlements on derivatives, net (including $22.8 million and $(27.0) million on commodity hedges during 2020 and 2019)	16,904,000	(24,701,000)
Equity-based compensation	26,392,000	27,382,000
Loss on extinguishment of debt	2,893,000	24,794,000
Other	6,673,000	9,600,000
Changes in assets and liabilities:
Decrease in receivables	88,107,000	12,886,000
Increase in inventories	(30,848,000)	(51,943,000)
Decrease in prepaid expenses and other	3,253,000	23,512,000
Decrease in accounts payable	(2,631,000)	(61,909,000)
Increase (decrease) in accrued liabilities	(150,381,000)	65,975,000
Net cash provided by operating activities	20,657,000	400,276,000
Investing activities
Oil and gas assets	(215,425,000)	(240,642,000)
Other property	(1,838,000)	(8,291,000)
Proceeds on sale of assets	1,713,000	0
Notes receivable from partners	(53,574,000)	(19,565,000)
Net cash used in investing activities	(269,124,000)	(268,498,000)
Financing activities
Borrowings under long-term debt	300,000,000	175,000,000
Payments on long-term debt	0	(325,000,000)
Advances under production prepayment agreement	50,000,000	0
Net proceeds from issuance of senior notes	0	641,875,000
Redemption of senior secured notes	0	(535,338,000)
Purchase of treasury stock / tax withholdings	(4,947,000)	(1,983,000)
Dividends	(19,174,000)	(54,447,000)
Deferred financing costs	(4,570,000)	(2,443,000)
Net cash provided by (used in) financing activities	321,309,000	(102,336,000)
Net increase in cash, cash equivalents and restricted cash	72,842,000	29,442,000
Cash, cash equivalents and restricted cash at beginning of period	229,346,000	185,616,000
Cash, cash equivalents and restricted cash at end of period	302,188,000	215,058,000
Cash paid for:
Interest, net of capitalized interest	101,908,000	78,691,000
Income taxes, net of refund received	68,330,000	27,768,000
Non-cash activity:
Production Prepayment Agreement converted to GoM Term Loan	$ 50,000,000	$ 0

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019
Statement of Cash Flows [Abstract]
Cash settlements on derivatives, net (commodity hedges)	$ 22.8	$ (27)

Organization

Organization	9 Months Ended
	Sep. 30, 2020
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Organization	Organization Kosmos Energy Ltd. changed its jurisdiction of incorporation from Bermuda to the State of Delaware, in the United States of America, (the "Redomestication") in December 2018. 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 U.S. Gulf of Mexico, as well as a world-class gas development offshore Mauritania and Senegal. We also maintain a sustainable proven basin exploration program in Equatorial Guinea, Ghana and U.S. Gulf of Mexico. Kosmos is listed on the New York Stock Exchange and London Stock Exchange 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 U.S. Gulf of Mexico. In addition, we have exploration activities in other countries in the Atlantic Margins.

Accounting Policies

Accounting Policies	9 Months Ended
	Sep. 30, 2020
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 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 consolidated financial statements and the accompanying notes should be read in conjunction with our audited consolidated financial statements for the year ended December 31, 2019, included in our annual report on Form 10-K. Impairment of Long‑Lived Assets We review our long‑lived assets for impairment when changes in circumstances indicate that the carrying amount of an asset may not be recoverable. ASC 360 — Property, Plant and Equipment requires an impairment loss to be recognized if the carrying amount of a long‑lived asset is not recoverable and exceeds its fair value. The carrying amount of a long‑lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. That assessment shall be based on the carrying amount of the asset at the date it is tested for recoverability, whether in use or under development. Assets to be disposed of and assets not expected to provide any future service potential to us are recorded at the lower of carrying amount or fair value. Oil and gas properties are grouped in accordance with ASC 932 — Extractive Activities-Oil and Gas. The basis for grouping is a reasonable aggregation of properties typically by field or by logical grouping of assets with significant shared infrastructure. For long-lived assets whereby the carrying value exceeds the estimated future undiscounted cash flows, the carrying amount is reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820 — Fair Value Measurement. If applicable, we utilize prices and other relevant information generated by market transactions involving assets and liabilities that are identical or comparable to the item being measured as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value measurements are typically based on judgmental assessments of future production, pricing estimates, capital and operating costs, market-based weighted average cost of capital, and risk adjustment factors applied to reserves. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a market-based weighted-average cost of capital. Although we base the fair value estimate of each asset group on assumptions we believe to be reasonable, those assumptions are inherently unpredictable and uncertain, and actual results could differ from the estimate. Negative revisions of estimated reserve quantities, increases in future cost estimates, divestiture of a significant component of the asset group, or sustained decreases in crude oil prices could lead to a reduction in expected future cash flows and possibly an additional impairment of long-lived assets in future periods. We believe the assumptions used in our analysis to test for impairment are appropriate and result in a reasonable estimate of future cash flows and fair value. Kosmos has consistently used an average of third-party industry forecasts to determine our pricing assumptions. Where unproved reserves exist, an appropriately risk-adjusted amount of these reserves may be included in the evaluation. 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, 2020 December 31, 2019 (In thousands) Cash and cash equivalents $ 300,819 $ 224,502 Restricted cash - current 827 4,302 Restricted cash - long-term 542 542 Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 302,188 $ 229,346 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 plus the Corporate Revolver or the Facility, whichever is greater. As of September 30, 2020, we exceeded this ratio and expect to restrict approximately $28.5 million to meet our requirements during the fourth quarter of 2020. In accordance with certain of our petroleum contracts, we have posted letters of credit related to performance guarantees for our minimum work obligations. Certain of these letters of credit are cash collateralized in accounts held by us and as such are classified as restricted cash. Upon completion of the minimum work obligations and/or entering into the next phase of the respective petroleum contract, the requirement to post the existing letters of credit will be satisfied and the cash collateral will be released. However, additional letters of credit may be required should we choose to move into the next phase of certain of our petroleum contracts. Inventories Inventories consisted of $131.7 million and $112.3 million of materials and supplies and $10.5 million and $2.1 million of hydrocarbons as of September 30, 2020 and December 31, 2019, 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. 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, 2020 2019 2020 2019 (In thousands) Revenues from contract with customer - Equatorial Guinea $ 43,003 $ 54,894 $ 95,520 $ 207,173 Revenues from contract with customer - Ghana 124,436 173,613 238,686 502,413 Revenues from contract with customers - U.S. Gulf of Mexico 55,620 123,861 198,294 338,292 Provisional oil sales contracts 1,727 4,668 (2,620) 1,881 Oil and gas revenue $ 224,786 $ 357,036 $ 529,880 $ 1,049,759 Restructuring Charges The Company accounts for restructuring charges and related termination benefits in accordance with ASC 712 — Compensation-Nonretirement Postemployment Benefits. Under this standard, the costs associated with termination benefits are recorded during the period in which the liability is incurred. During the three and nine months ended September 30, 2020, we recognized $(0.1) million and $13.3 million, respectively, in restructuring charges for employee severance and related benefit costs incurred as part of a corporate reorganization in Other expenses, net in the consolidated statement of operations. Concentration of Credit Risk Our revenue can be materially affected by current economic conditions and the price of oil. However, based on the current demand for crude oil and the fact that alternative purchasers are available, we believe that the loss of our marketing agent and/or any of the purchasers identified by our marketing agent would not have a long‑term material adverse effect on our financial position or results of operations. The continued economic disruption resulting from the COVID-19 pandemic 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. For our U.S. Gulf of Mexico operations, crude oil and natural gas are transported to customers using third-party pipelines. For the three months ended September 30, 2020 and 2019, revenue from Phillips 66 Company made up approximately 18% and 21%, respectively, and revenue from Shell Trading (US) Company made up approximately 7% and 11%, respectively, of our total consolidated revenue and was included in our U.S. Gulf of Mexico segment. For the nine months ended September 30, 2020 and 2019, revenue from Phillips 66 Company made up approximately 29% and 22%, respectively, and revenue from Shell Trading (US) Company made up approximately 12% and 9%, respectively, of our total consolidated revenue and was included in our U.S. Gulf of Mexico segment. Recent Accounting Standards In June 2016, ASU 2016-13, "Measurement of Credit Losses on Financial Instruments," was issued requiring measurement of all expected credit losses for certain types of financial instruments, including trade receivables, held at the reporting date based on historical experience, current conditions and reasonable and supportable forecasts. This standard was effective January 1, 2020. We assessed all receivable positions for expected credit losses through the implementation of ASU 2016-13, current expected credit loss standard (CECL). Our receivables are collectible in the original term of the underlying agreements and current expected credit losses under the CECL standard are not significant. In December 2019, the FASB issued ASU 2019-12, “Simplifying the Accounting for Income Taxes”. The amendments in the ASU are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. Early adoption is permitted, however, we do not plan to early adopt ASU 2019-12 at this time. ASU 2019-12 is not expected to have a material impact on our income tax expense.

Acquisitions and Divestitures

Acquisitions and Divestitures	9 Months Ended
	Sep. 30, 2020
Business Combinations [Abstract]
Acquisitions and Divestitures	Acquisitions and Divestitures2020 Transactions During the third quarter of 2020, Kosmos entered into an agreement with Shell to farm down interests in a portfolio of frontier exploration assets for cash consideration of $96.0 million and future contingent consideration of up to $100.0 million. Under the terms of the agreement, Shell will acquire Kosmos' participating interest in blocks offshore Sao Tome and Principe, Suriname, Namibia, and South Africa. The cash consideration will be allocated and paid by Shell on a country-by-country basis. The agreement is subject to customary conditions precedent, including regulatory and host government approvals and is expected to close during the fourth quarter of 2020. The future contingent consideration is based on the outcome of the first four wells drilled in the purchased assets, excluding South Africa, and is payable upon submission of an appraisal plan to the relevant governmental authority under the relevant host government contract. Shell will pay $50.0 million for each appraisal plan submitted, capped in the aggregate at a maximum of $100.0 million. The book value of the portfolio of exploration assets as of September 30, 2020 was approximately $4.5 million. In October 2020, Kosmos withdrew from Block C6 offshore Mauritania. During the second quarter of 2020, Kosmos made a decision to withdraw from our blocks offshore Cote d'Ivoire following our evaluation of seismic data. In July 2020, we provided notice to Staatsolie that we declined to enter the final exploration phase of the Suriname Block 45 petroleum agreement. 2019 Transactions During the first quarter of 2019, we agreed a petroleum contract covering offshore Marine XXI block with the national oil company of the Republic of the Congo, Societe Nationale des Petroles du Congo. The petroleum contract was subject to a required governmental approval process before the petroleum contract could be made effective. The petroleum contract had not been approved by the government of the Republic of Congo nor entered into force when, in February 2020, we terminated our interests in the Marine XXI block petroleum contract.

Joint Interest Billings, Relate

Joint Interest Billings, Related Party Receivables and Notes Receivables	9 Months Ended
	Sep. 30, 2020
Joint Interest Billings
Joint Interest Billings, Related Party Receivables and Notes Receivables	Joint Interest Billings, Related Party Receivables and Notes Receivables Joint Interest Billings The Company’s joint interest billings generally 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 consolidated balance sheets as current and long-term receivables based on when collection is expected to occur. In Ghana, the contractor group funded GNPC’s 5% share of the TEN development costs. The block partners are being reimbursed for such costs plus interest out of a portion of GNPC’s TEN production revenues. As of September 30, 2020 and December 31, 2019, the current portions of the joint interest billing receivables due from GNPC for the TEN fields development costs were $9.1 million and $14.0 million, respectively, and the long-term portions were $17.6 million and $16.0 million, respectively. Notes Receivables In February 2019, Kosmos and BP signed Carry Advance Agreements with the national oil companies of Mauritania and Senegal which obligate us separately to finance the respective national oil company’s share of certain development costs incurred through first gas production for Greater Tortue Ahmeyim Phase 1, currently projected in 2023. Kosmos’ share for the two agreements combined is up to $239.7 million, which is to be repaid with interest through the national oil companies’ share of future revenues. As of September 30, 2020 and December 31, 2019, the balance due from the national oil companies was $83.5 million and $27.4 million, respectively, which is classified as Long-term receivables on our consolidated balance sheets.

Property and Equipment

Property and Equipment	9 Months Ended
	Sep. 30, 2020
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, 2020 December 31, 2019 (In thousands) Oil and gas properties: Proved properties $ 5,220,739 $ 4,904,648 Unproved properties 535,466 814,065 Total oil and gas properties 5,756,205 5,718,713 Accumulated depletion (2,401,721) (2,093,962) Oil and gas properties, net 3,354,484 3,624,751 Other property 59,987 61,598 Accumulated depreciation (48,167) (44,017) Other property, net 11,820 17,581 Property and equipment, net $ 3,366,304 $ 3,642,332 We recorded depletion expense of $104.9 million and $139.1 million for the three months ended, September 30, 2020 and 2019, respectively, and $307.8 million and $394.1 million for the nine months ended September 30, 2020 and 2019, respectively. During the three months ended September 30, 2020 and 2019, no oil and gas asset impairments were recorded. During the nine months ended September 30, 2020 and 2019, we recorded asset impairments totaling $150.8 million and zero, respectively, in our consolidated statement of operations in connection with fair value assessments for oil and gas proved properties in the U.S. Gulf of Mexico.

Suspended Well Costs

Suspended Well Costs	9 Months Ended
	Sep. 30, 2020
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, 2020. The table excludes $12.1 million in costs that were capitalized and expensed during the same period. During the first quarter of 2020, the exploratory well costs associated with the Greater Tortue Ahmeyim Unit were reclassified to proved property as the execution of the Tortue Phase 1 SPA in February 2020 resulted in recognition of proved undeveloped reserves at that time. September 30, 2020 (In thousands) Beginning balance $ 445,790 Additions to capitalized exploratory well costs pending the determination of proved reserves 2,098 Reclassification due to determination of proved reserves (263,849) Capitalized exploratory well costs charged to expense — Ending balance $ 184,039 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, 2020 December 31, 2019 (In thousands, except well counts) Exploratory well costs capitalized for a period of one year or less $ 28,750 $ 29,121 Exploratory well costs capitalized for a period of one to two years — 78,245 Exploratory well costs capitalized for a period of three years or greater 155,289 338,424 Ending balance $ 184,039 $ 445,790 Number of projects that have exploratory well costs that have been capitalized for a period greater than one year 2 3 As of September 30, 2020, the projects with exploratory well costs capitalized for more than one year since the completion of drilling are related to the BirAllah discovery (formerly known as the Marsouin discovery) in Block C8 offshore Mauritania and the Yakaar and Teranga discoveries in the Cayar Offshore Profond block offshore Senegal. BirAllah Discovery — In November 2015, we completed the Marsouin-1 exploration well in the northern part of Block C8 offshore Mauritania, which encountered hydrocarbon pay. Following additional evaluation, a decision regarding commerciality is expected to be made. During the fourth quarter of 2019, we completed the nearby Orca-1 exploration well which encountered hydrocarbon pay. Following additional evaluation, a decision regarding commerciality is expected to be made. The BirAllah and Orca discoveries are being analyzed as a joint development. 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. Following additional evaluation, a decision regarding commerciality is expected to be made. The Yakaar and Teranga discoveries are being analyzed as a joint development.

Leases

Leases	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Leases	Leases We have commitments under operating leases primarily related to office leases. Our leases have initial lease terms ranging from one year to ten years. Certain lease agreements contain provisions for future rent increases. The components of lease cost for the three and nine months ended September 30, 2020 and 2019 are as follows: Three Months Ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Operating lease cost $ 1,511 $ 1,279 $ 4,668 $ 4,288 Short-term lease cost(1) 269 960 13,071 1,547 Total lease cost $ 1,780 $ 2,239 $ 17,739 $ 5,835 __________________________________ (1) Includes $12.2 million and zero during the nine months ended September 30, 2020 and 2019, respectively, of costs associated with short-term drilling contracts. Other information related to operating leases at September 30, 2020 and 2019, is as follows: September 30, 2020 December 31, 2019 (In thousands, except lease term and discount rate) Balance sheet classifications Other assets (right-of-use assets) $ 18,288 $ 20,008 Accrued liabilities (current maturities of leases) 2,081 1,139 Other long-term liabilities (non-current maturities of leases) 20,651 22,240 Weighted average remaining lease term 8.2 years 8.8 years Weighted average discount rate 9.9 % 9.8 % The table below presents supplemental cash flow information related to leases during the nine months ended September 30, 2020 and 2019: Nine Months Ended September 30, 2020 2019 (In thousands) Operating cash flows for operating leases $ 3,816 $ 3,077 Investing cash flows for operating leases(1) 12,225 — __________________________________ (1) Represents costs associated with short-term drilling contracts. Future minimum rental commitments under our leases at September 30, 2020, are as follows: Operating Leases(1) (In thousands) 2020(2) $ 1,039 2021 4,199 2022 4,262 2023 4,326 2024 3,489 Thereafter 16,106 Total undiscounted lease payments 33,421 Less: Imputed interest (10,689) Total lease liabilities $ 22,732 __________________________________ (1) Does not include purchase commitments for jointly owned fields and facilities where we are not the operator and excludes commitments for exploration activities, including well commitments, in our petroleum contracts. (2) Represents payments for the period from October 1, 2020 through December 31, 2020.

Debt

Debt	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Debt	Debt September 30, 2020 December 31, 2019 (In thousands) Outstanding debt principal balances: Facility $ 1,450,000 $ 1,400,000 Corporate Revolver 100,000 — Senior Notes 650,000 650,000 GoM Term Loan 200,000 — Total 2,400,000 2,050,000 Unamortized deferred financing costs and discounts(1) (38,662) (41,937) Total debt, net 2,361,338 2,008,063 Less: Current maturities of long-term debt(2) (169,905) — Long-term debt, net $ 2,191,433 $ 2,008,063 __________________________________ (1) Includes $26.4 million and $32.8 million of unamortized deferred financing costs related to the Facility as of September 30, 2020 and December 31, 2019, respectively; $8.2 million and $9.1 million of unamortized deferred financing costs and discounts related to the Senior Notes as of September 30, 2020 and December 31, 2019, respectively; and $4.1 million and zero of unamortized deferred financing costs related to the GoM Term Loan as of September 30, 2020 and December 31, 2019, respectively. (2) As a result of the Facility redetermination in October 2020, the borrowing base was lowered to $1.32 billion and the Company expects to make repayments totaling $130 million during the fourth quarter of 2020. Facility The Facility supports our oil and gas exploration, appraisal and development programs and corporate activities. As of September 30, 2020, borrowings under the Facility totaled $1.45 billion and the undrawn availability under the facility was $0.05 billion. In April 2020, following the lenders' annual redetermination, the available borrowing base and Facility size were both reduced from $1.6 billion to approximately $1.5 billion. In addition, as part of the April 2020 redetermination process, the Company agreed to conduct an additional redetermination in September 2020. In October 2020, as a result of the September redetermination, the available borrowing base was reduced to approximately $1.32 billion and the Company expects to make repayments totaling $130 million during the fourth quarter of 2020. Additionally, the Company agreed to conduct semi-annual redeterminations every March and September, beginning with March 2021. 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 plus the Corporate Revolver or the Facility, whichever is greater. As of September 30, 2020, we exceeded this ratio and expect to restrict approximately $28.5 million to meet our requirements during the fourth quarter of 2020. The Facility provides a revolving credit and letter of credit facility. The availability period for the revolving credit facility expires one month prior to the final maturity date. The letter of credit facility expires on the final maturity date. The available facility amount is subject to borrowing base constraints and, beginning on March 31, 2022, outstanding borrowings will be constrained by an amortization schedule. The Facility has a final maturity date of March 31, 2025. As of September 30, 2020, we had no letters of credit issued under the Facility. As result of the impact of COVID-19 on the demand for oil and the related significant decrease in oil prices, our ability to comply with one of our financial covenants, the debt cover ratio, may be impacted in future periods. Therefore, in July 2020, we proactively worked with our lender group, prior to any inability to comply with the financial covenants thereunder, to amend the debt cover ratio calculation through December 31, 2021. The amendment makes this covenant less restrictive during the stated period up to a maximum of 4.75x and thereafter gradually returns to the originally agreed upon ratio of 3.5x. We were in compliance with the financial covenants as of the most recent assessment date. The Facility contains customary cross default provisions. Corporate Revolver In August 2018, we amended and restated the Corporate Revolver from a number of financial institutions, maintaining the borrowing capacity at $400.0 million, extending the maturity date from November 2018 to May 2022 and lowering the margin to 5%. This results in lower commitment fees on the undrawn portion of the total commitments, which is 30% per annum of the respective margin. The Corporate Revolver is available for general corporate purposes and for oil and gas exploration, appraisal and development programs. As of September 30, 2020, there were $100.0 million in outstanding borrowings under the Corporate Revolver and the undrawn availability was $300.0 million. As of September 30, 2020, we have $4.4 million of net deferred financing costs related to the Corporate Revolver, which will be amortized over its remaining term. As result of the impact of COVID-19 on the demand for oil and the related significant decrease in oil prices, our ability to comply with one of our financial covenants, the debt cover ratio, may be impacted in future periods. Therefore, in July 2020, we proactively worked with our lender group, prior to any inability to comply with the financial covenants thereunder, to amend the debt cover ratio calculation through December 31, 2021. The amendment makes this covenant less restrictive during the stated period up to a maximum of 4.75x and thereafter gradually returns to the originally agreed upon ratio of 3.5x. We were in compliance with the financial covenants as of the most recent assessment date. The Corporate Revolver contains customary cross default provisions. Letters of Credit In 2019, we issued two letters of credit totaling $20.4 million under a new letter of credit arrangement, which does not currently require cash collateral. In October 2020, as a result of the Shell farm down transaction discussed in Note 3 — Acquisitions and Divestitures, the letter of credit requirement associated with Block 11 offshore Sao Tome and Principe totaling $3.4 million will no longer be required. 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 fees and other expenses. We used the net proceeds to redeem all of the Senior Secured Notes, 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 Senior Notes. The Senior Notes mature on April 4, 2026. Interest is payable in arrears each April 4 and October 4, commencing on October 4, 2019. The 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) and rank effectively junior in right of payment to all of its existing and future secured indebtedness (including all borrowings under the Facility). The Senior Notes are guaranteed on a senior, unsecured basis by certain subsidiaries owning the Company's Gulf of Mexico assets, and on a subordinated, unsecured basis by certain subsidiaries that guarantee the Facility. We were in compliance with the financial covenants contained in the Senior Notes as of September 30, 2020. The Senior Notes contain customary cross default provisions. GoM Term Loan In September 2020, the Company entered into a five-year $200 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 million subject to certain conditions. The net proceeds will be used to pay down a portion of the Facility and to fund U.S. Gulf of Mexico working capital and general operating expenses. The $50 million advanced under the Production Prepayment Agreement with Trafigura in the second quarter of 2020 has been extinguished and converted as part of the GoM Term Loan with the remaining $150 million provided by Beal Bank. The GoM Term Loan bears interest at an effective rate of approximately 6% per annum and matures in 2025, with principal repayments beginning in the fourth quarter of 2021. The GoM Term Loan contains customary affirmative and negative covenants, including covenants that affect our ability to incur additional indebtedness, create liens, merge, dispose of assets, and make distributions, dividends, investments or capital expenditures, among other things. The GoM Term Loan includes certain representations and warranties, indemnities and events of default that, subject to certain materiality thresholds and grace periods, arise as a result of a payment default, failure to comply with covenants, material inaccuracy of representation or warranty, and certain bankruptcy or insolvency proceedings. If there is an event of default, all or any portion of the outstanding indebtedness may be immediately due and payable and other rights may be exercised including against the collateral. At September 30, 2020, the estimated repayments of debt during the five fiscal year periods and thereafter are as follows: Payments Due by Year Total 2020(2) 2021 2022 2023 2024 Thereafter (In thousands) Principal debt repayments(1) $ 2,400,000 $ 130,244 $ 73,333 $ 312,494 $ 458,571 $ 458,572 $ 966,786 __________________________________ (1) Includes the scheduled principal maturities for the $650.0 million aggregate principal amount of Senior Notes and borrowings under the Facility, Corporate Revolver and GoM Term Loan. The scheduled maturities of debt related to the Facility as of September 30, 2020 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, 2020 through December 31, 2020. As a result of the Facility redetermination in October 2020, the borrowing base was lowered to $1.32 billion and the Company expects to make repayments totaling $130 million during the fourth quarter of 2020. 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, 2020 2019 2020 2019 (In thousands) Interest expense $ 29,760 $ 34,944 $ 90,031 $ 111,566 Amortization—deferred financing costs 2,255 2,285 6,730 6,974 Loss on extinguishment of debt 678 — 2,893 24,794 Capitalized interest (5,806) (7,077) (18,062) (21,330) Deferred interest 531 290 2,028 1,559 Interest income (1,269) (972) (3,371) (2,215) Other, net 919 1,251 2,928 4,217 Interest and other financing costs, net $ 27,068 $ 30,721 $ 83,177 $ 125,565

Production Prepayment Agreement

Production Prepayment Agreement	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Production Prepayment Agreement	Production Prepayment Agreement, netIn June 2020, the Company received $50 million from Trafigura under a Production Prepayment Agreement of crude oil sales related to a portion of our U.S. Gulf of Mexico production primarily in 2022 and 2023. As discussed in Note 8 — Debt, the Company has terminated the Production Prepayment Agreement and the initial prepayment of $50 million advanced under the Production Prepayment Agreement by Trafigura in the second quarter of 2020 has been extinguished and converted into the GoM Term Loan as of September 30, 2020.

Derivative Financial Instrument

Derivative Financial Instruments	9 Months Ended
	Sep. 30, 2020
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, 2020. Volumes and weighted average prices are net of any offsetting derivative contracts entered into. Weighted Average Price per Bbl Net Deferred Premium Payable/ Sold Purchased Term Type of Contract Index MBbl (Receivable) Swap Put Floor Ceiling Call 2020: Oct — Dec Swaps Dated Brent 2,637 $ — $ 42.67 $ — $ — $ — $ — Oct — Dec Swaps Argus LLS 1,500 — 29.98 — — — — Oct — Dec Call spreads NYMEX WTI (1) 1.20 — — — 45.00 35.00 Oct — Dec Swaps with sold puts Dated Brent 167 — 35.00 25.00 — — — Oct — Dec Three-way collars Dated Brent 500 — — 25.00 32.50 40.00 — Oct — Dec Sold calls(2) Dated Brent 2,375 (0.19) — — — 80.83 — 2021: Jan — Dec Swaps with sold puts Dated Brent 6,000 $ — $ 53.96 $ 42.92 $ — $ — $ — Jan — Dec Three-way collars Dated Brent 2,000 0.50 — 30.00 40.00 55.20 — Jan — Dec Sold calls(2) Dated Brent 7,000 — — — — 70.09 — 2022: Jan — Dec Sold calls(2) Dated Brent 1,581 $ — $ — $ — $ — $ 60.00 $ — __________________________________ (1) Added call spreads on 0.5 million barrels to open upside for U.S. Gulf of Mexico production. (2) Represents call option contracts sold to counterparties to enhance other derivative positions. In April 2020, we restructured the majority of our May 2020 through December 2020 derivative contracts, whereby we converted the existing hedges into 7.0 MMBbls of Dated Brent swap contracts with an average fixed price of $42.67 per barrel. In November 2020, we entered into Dated Brent three-way collar contracts for 1.0 MMBbl from January 2021 through December 2021 with a sold put price of $32.50 per barrel, a floor price of $40.00 per barrel and a ceiling price of $50.00 per barrel. The following tables disclose the Company’s derivative instruments as of September 30, 2020 and December 31, 2019, and gain/(loss) from derivatives during the three and nine months ended September 30, 2020 and 2019, respectively: Estimated Fair Value Asset (Liability) Type of Contract Balance Sheet Location September 30, 2020 December 31, 2019 (In thousands) Derivatives not designated as hedging instruments: Derivative assets: Commodity Derivatives assets—current $ 30,499 $ 12,856 Provisional oil sales Receivables: Oil Sales — (3,287) Commodity Derivatives assets—long-term 7,104 2,302 Derivative liabilities: Commodity Derivatives liabilities—current (24,589) (8,914) Commodity Derivatives liabilities—long-term (6,283) (11,478) Total derivatives not designated as hedging instruments $ 6,731 $ (8,521) 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) 2020 2019 2020 2019 (In thousands) Derivatives not designated as hedging instruments: Provisional oil sales Oil and gas revenue $ 1,727 $ 4,667 $ (2,620) $ 1,881 Commodity Derivatives, net (1,187) 27,016 34,776 (35,884) Total derivatives not designated as hedging instruments $ 540 $ 31,683 $ 32,156 $ (34,003) 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, 2020 and December 31, 2019, 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, 2020
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, 2020 and December 31, 2019, 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, 2020 Assets: Commodity derivatives $ — $ 37,603 $ — $ 37,603 Provisional oil sales — — — — Liabilities: Commodity derivatives — (30,872) — (30,872) Total $ — $ 6,731 $ — $ 6,731 December 31, 2019 Assets: Commodity derivatives $ — $ 15,158 $ — $ 15,158 Provisional oil sales — (3,287) — (3,287) Liabilities: Commodity derivatives — (20,392) — (20,392) Total $ — $ (8,521) $ — $ (8,521) 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 doubtful accounts, and other long-term assets approximate fair value. The estimates of fair value of these items are based on Level 2 inputs. Commodity Derivatives Our commodity derivatives represent crude oil collars, put options, call options and swaps for notional barrels of oil at fixed Dated Brent, NYMEX WTI, or Argus LLS 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 10 — 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, 2020 and December 31, 2019: September 30, 2020 December 31, 2019 Carrying Value Fair Value Carrying Value Fair Value (In thousands) Senior Notes $ 643,274 $ 569,088 $ 642,550 $ 664,957 GoM Term Loan 200,000 200,000 — — Corporate Revolver 100,000 100,000 — — Facility 1,450,000 1,450,000 1,400,000 1,400,000 Total $ 2,393,274 $ 2,319,088 $ 2,042,550 $ 2,064,957 The carrying value of our Senior Notes represents the principal amounts outstanding less unamortized discounts. The fair value of our Senior Notes is based on quoted market prices, which results in a Level 1 fair value measurement. The carrying values of the GoM Term Loan, Corporate Revolver 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. As a result of the impact of COVID-19 on the demand for oil and the related significant decrease in oil prices, we reviewed our long-lived assets for impairment at March 31, 2020, which resulted in impairment charges against earnings of $150.8 million, reducing the carrying value of the properties to their estimated fair values of $243.7 million. As part of our impairment analysis, the average per barrel Dated Brent price of third-party industry forecasts used for purposes of determining discounted future cash flows ranged from the mid-$30s in 2020 increasing to the mid-$50s over several years. The expected future cash flows were discounted using a rate of approximately 10 percent, which the Company believes is a market-based weighted average cost of capital for industry peers determined appropriate at the time of the valuation. These impairment charges are included in Impairments of long-lived assets on the consolidated statement of operations. The Company did not recognize additional impairment of proved oil and gas properties during the second and third quarters of 2020 as no impairment indicators were identified. If we experience further declines in oil pricing expectations, increases in our estimated future expenditures or a 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, 2020
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 $8.7 million and $9.5 million during the three months ended September 30, 2020 and 2019, respectively, and $26.4 million and $27.4 million during the nine months ended September 30, 2020 and 2019, respectively. The total tax benefit for the three months ended September 30, 2020 and 2019 was $1.8 million and $3.1 million, respectively, and $5.6 million and $5.9 million during the nine months ended September 30, 2020 and 2019, respectively. Additionally, we recorded a net tax shortfall (windfall) related to equity-based compensation of $0.1 million and nil for the three months ended September 30, 2020 and 2019, respectively, and $1.2 million and $1.2 million during the nine months ended September 30, 2020 and 2019, respectively. The fair value of awards vested during the three months ended September 30, 2020 and 2019 was $0.2 million and $0.7 million, respectively, and $26.0 million and $14.7 million during the nine months ended September 30, 2020 and 2019, 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 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, 2020: 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, 2019 4,731 $ 5.71 7,798 $ 8.42 Granted(1) 3,478 5.49 3,393 8.37 Forfeited(1) (907) 6.17 (478) 8.02 Vested (2,145) 5.90 (2,603) 9.47 Outstanding at September 30, 2020 5,157 5.38 8,110 8.11 __________________________________ (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, 2020, total equity-based compensation to be recognized on unvested restricted stock units is $32.9 million over a weighted average period of 1.86 years. In March 2018, the board of directors approved an amendment to the LTIP to add 11.0 million shares to the plan, which was approved by our stockholders at the Annual General Meeting in June 2018. The LTIP provides for the issuance of 50.5 million shares pursuant to awards under the plan. At September 30, 2020, 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 $12.96 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 44.0% to 52.0%. The risk-free interest rate was based on the U.S. treasury rate for a term commensurate with the expected life of the grant and ranged from 0.8% to 2.5%. For the restricted stock units awarded in 2019 and 2020, the Monte Carlo simulation model included estimated quarterly dividend inputs ranging from $0.045 to $0.050.

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Income Taxes	Income Taxes We provide for income taxes based on the laws and rates in effect in the countries in which our operations are conducted. The relationship between our pre‑tax income or loss from continuing operations and our income tax expense or benefit varies from period to period as a result of various factors, which include changes in total pre‑tax income or loss, the jurisdictions in which our income (loss) is earned, and the tax laws in those jurisdictions. 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. The income tax provision consists of United States, Ghanaian, and Equatorial Guinean income taxes, and Texas margin taxes. Our operations in other foreign jurisdictions have a 0% effective tax rate because they reside in countries with a 0% statutory rate or we have incurred losses in those jurisdictions and have full valuation allowances against the corresponding net deferred tax assets. In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized. For the three and nine months ended September 30, 2020, we increased our valuation allowance associated with our U.S. deferred tax assets by $8.5 million and $94.6 million, respectively, resulting in $30.9 million of net U.S. deferred tax expense. The valuation allowance was necessary due to the recent decline in oil prices and the impact on our expected ability to utilize U.S. tax losses in the future. In March 2020, the Coronavirus Aid, Relief, and Economic Security ACT ("CARES Act") became law. Among other things, the CARES Act permits taxpayers to carry back U.S. taxable losses generated during tax years 2018 through 2020 to the five tax years preceding the loss year to obtain tax refunds. Certain of our U.S. legal entities qualify for such relief and we recorded a current tax benefit of $4.9 million during the first quarter of 2020, with a total $12.2 million income tax refund claim. Other provisions of the CARES Act are not expected to have a material impact to our tax expense. Income (loss) before income taxes is composed of the following: Three Months Ended September 30, Nine Months Ended September 30, 2020 2019 2020 2019 (In thousands) United States $ (41,359) $ 3,464 $ (311,200) $ (70,776) Foreign—other 4,867 36,071 (89,332) 98,170 Income (loss) before income taxes $ (36,492) $ 39,535 $ (400,532) $ 27,394 For the three months ended, September 30, 2020 and 2019, our effective tax rate was 2% and 59%, respectively. For the nine months ended, September 30, 2020 and 2019, our effective tax rate was 5% and 173%, respectively. For the three and nine months ended September 30, 2020, our overall effective tax rate was impacted by deferred tax expense related to valuation allowances on certain U.S. deferred tax assets and by a current tax benefit related to certain U.S. tax losses incurred in 2018 and carried back to years with a higher income tax rate. Additionally, for the three and nine months ended September 30, 2020 and 2019, 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. Also, for the three and nine months ended September 30, 2019 our overall effective tax rate was impacted by non-deductible and non-taxable items associated with our U.S., Ghanaian, and Equatorial Guinean operations, and other losses and expenses, primarily related to exploration operations in tax-exempt jurisdictions or in taxable jurisdictions where we have valuation allowances against our deferred tax assets, and therefore, we do not realize any tax benefit on such losses or expenses. The Company files income tax returns in all jurisdictions where such requirements exist, however, our primary tax jurisdictions are the United States, Ghana and Equatorial Guinea. The Company is open to tax examinations in the United States for federal income tax return years 2017 through 2019, in Ghana to federal income tax return years 2014 through 2019, and in Equatorial Guinea for tax year 2019. As of September 30, 2020, the Company had no material uncertain tax positions. The Company’s policy is to recognize potential interest and penalties related to income tax matters in income tax expense.

Net Income (Loss) Per Share

Net Income (Loss) Per Share	9 Months Ended
	Sep. 30, 2020
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, 2020 2019 2020 2019 (In thousands, except per share data) Numerator: Net income (loss) allocable to common stockholders $ (37,384) $ 16,065 $ (419,542) $ (20,004) Denominator: Weighted average number of shares outstanding: Basic 405,409 401,466 405,131 401,319 Restricted stock awards and units(1) — 9,526 — — Diluted 405,409 410,992 405,131 401,319 Net income (loss) per share: Basic $ (0.09) $ 0.04 $ (1.04) $ (0.05) Diluted $ (0.09) $ 0.04 $ (1.04) $ (0.05) __________________________________ (1) We excluded outstanding restricted stock awards and units of 11.6 million and 0.7 million for the three months ended September 30, 2020 and 2019, respectively, and 11.4 million and 15.4 million for the nine months ended September 30, 2020 and 2019, 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, 2020
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 currently have a commitment to drill one exploration well in Namibia and two exploration wells in Mauritania. In Sao Tome and Principe, we also have 3D seismic acquisition requirements of approximately 8,800 square kilometers, and in Mauritania we have 100 line km requirement for controlled source electromagnetic data acquisition. In South Africa we have 2D seismic acquisition requirements of approximately 500 line kilometers. Upon closing of the Shell farm down transaction discussed in Note 3 — Acquisitions and Divestitures expected in the fourth quarter of 2020, the well and seismic commitments associated with the divested Sao Tome and Principe, Namibia and South Africa blocks will transfer to Shell. Performance Obligations As of September 30, 2020 and December 31, 2019, the Company had performance bonds totaling $195.4 million for our supplemental bonding requirements stipulated by the BOEM and $7.2 million to other operators related to costs anticipated for the plugging and abandonment of certain wells and the removal of certain facilities in our U.S. Gulf of Mexico fields. As of September 30, 2020 and December 31, 2019, we had zero cash collateral against these secured performance bonds. Dividends

Additional Financial Informatio

Additional Financial Information	9 Months Ended
	Sep. 30, 2020
Additional Financial Information
Additional Financial Information	Additional Financial Information Accrued Liabilities Accrued liabilities consisted of the following: September 30, 2020 December 31, 2019 (In thousands) Accrued liabilities: Exploration, development and production $ 87,849 $ 152,490 Revenue payable 24,435 32,482 Current asset retirement obligations 2,673 4,527 General and administrative expenses 4,696 44,575 Interest 3,361 33,584 Income taxes 51,016 103,566 Taxes other than income 2,035 3,375 Derivatives 6,571 4,837 Other 3,994 1,268 $ 186,630 $ 380,704 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, 2020: September 30, 2020 (In thousands) Asset retirement obligations: Beginning asset retirement obligations $ 235,053 Liabilities incurred during period 2,781 Liabilities settled during period (4,113) Revisions in estimated retirement obligations 2,139 Accretion expense 14,377 Ending asset retirement obligations $ 250,237 Facilities Insurance Modifications, Net Facilities insurance modifications, net consists of costs associated with the long-term solution to convert the Jubilee FPSO to a permanently spread moored facility, net of related insurance reimbursements. During the three months ended September 30, 2020 and 2019, we incurred approximately $2.5 million and $12.6 million, respectively in expenditures with no offsetting insurance recoveries. During the nine months ended, September 30, 2020 and 2019, we incurred approximately $10.6 million and $34.8 million, respectively, in expenditures offset by approximately zero and $40.0 million, respectively, in insurance recoveries. 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, 2020 2019 2020 2019 (In thousands) Loss on disposal of inventory $ 1,200 $ 1,232 $ 3,028 $ 1,419 (Gain) loss on ARO liability settlements (170) (746) 1,952 1,167 Restructuring charges (72) — 13,268 — Other, net 1,847 10,986 9,714 9,212 Other expenses, net $ 2,805 $ 11,472 $ 27,962 $ 11,798 The restructuring charges are for employee severance and related benefit costs incurred as part of a corporate reorganization.

Business Segment Information

Business Segment Information	9 Months Ended
	Sep. 30, 2020
Segment Reporting [Abstract]
Business Segment Information	Business Segment Information Kosmos is engaged in a single line of business, which is the exploration and development of oil and gas. At September 30, 2020, 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 Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Three months ended September 30, 2020 Revenues and other income: Oil and gas revenue $ 125,636 $ 43,530 $ — $ 55,620 $ — $ — $ 224,786 Other income, net 1 — — 37 33,003 (33,040) 1 Total revenues and other income 125,637 43,530 — 55,657 33,003 (33,040) 224,787 Costs and expenses: Oil and gas production 48,709 14,072 — 21,496 — — 84,277 Facilities insurance modifications, net 2,465 — — — — — 2,465 Exploration expenses 48 1,561 806 5,485 6,077 — 13,977 General and administrative 3,101 1,017 1,168 3,580 39,472 (30,069) 18,269 Depletion, depreciation and amortization 63,487 15,421 15 31,499 809 — 111,231 Impairment of long-lived assets — — — — — — — Interest and other financing costs, net(1) 13,117 (344) (6,607) 4,372 18,314 (1,784) 27,068 Derivatives, net — — — — 1,187 — 1,187 Other expenses, net (1,818) 384 658 3,250 1,518 (1,187) 2,805 Total costs and expenses 129,109 32,111 (3,960) 69,682 67,377 (33,040) 261,279 Income (loss) before income taxes (3,472) 11,419 3,960 (14,025) (34,374) — (36,492) Income tax expense (849) 7,048 — — (5,307) — 892 Net income (loss) $ (2,623) $ 4,371 $ 3,960 $ (14,025) $ (29,067) $ — $ (37,384) Consolidated capital expenditures $ 6,116 $ 9,853 $ 46,574 $ 30,677 $ 6,287 $ — $ 99,507 Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Nine months ended September 30, 2020 Revenues and other income: Oil and gas revenue $ 236,536 $ 95,050 $ — $ 198,294 $ — $ — $ 529,880 Other income, net 2 — — 488 42,258 (42,746) 2 Total revenues and other income 236,538 95,050 — 198,782 42,258 (42,746) 529,882 Costs and expenses: Oil and gas production 113,319 50,961 — 70,347 — — 234,627 Facilities insurance modifications, net 10,555 — — — — — 10,555 Exploration expenses 146 6,397 5,265 26,046 36,439 — 74,293 General and administrative 10,123 3,977 5,453 10,433 99,551 (72,171) 57,366 Depletion, depreciation and amortization 148,135 43,724 46 132,213 2,272 — 326,390 Impairment of long-lived assets — — — 150,820 — — 150,820 Interest and other financing costs, net(1) 41,270 (1,044) (19,455) 12,052 55,705 (5,351) 83,177 Derivatives, net — — — — (34,776) — (34,776) Other expenses, net (64,142) (8,993) 3,129 46,995 16,197 34,776 27,962 Total costs and expenses 259,406 95,022 (5,562) 448,906 175,388 (42,746) 930,414 Income (loss) before income taxes (22,868) 28 5,562 (250,124) (133,130) — (400,532) Income tax expense (6,679) (1,622) — 30,902 (3,591) — 19,010 Net income (loss) $ (16,189) $ 1,650 $ 5,562 $ (281,026) $ (129,539) $ — $ (419,542) Consolidated capital expenditures $ 31,192 $ 25,959 $ 51,897 $ 109,228 $ 32,082 $ — 250,358 As of September 30, 2020 Property and equipment, net $ 1,373,126 $ 449,020 $ 502,355 $ 1,015,905 $ 25,898 $ — $ 3,366,304 Total assets $ 1,511,667 $ 708,614 $ 717,323 $ 3,221,915 $ 12,782,894 $ (14,848,912) $ 4,093,501 ______________________________________ (1) Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside. Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Three months ended September 30, 2019 Revenues and other income: Oil and gas revenue $ 177,797 $ 55,378 $ — $ 123,861 $ — $ — $ 357,036 Other income, net 1 — — 200 5,706 (5,973) (66) Total revenues and other income 177,798 55,378 — 124,061 5,706 (5,973) 356,970 Costs and expenses: Oil and gas production 42,017 21,369 — 32,154 — — 95,540 Facilities insurance modifications, net 12,569 — — — — — 12,569 Exploration expenses 82 2,437 1,260 10,625 8,369 — 22,773 General and administrative 3,886 1,719 2,678 7,002 38,897 (29,459) 24,723 Depletion, depreciation and amortization 73,347 16,019 15 56,359 913 — 146,653 Interest and other financing costs, net(1) 16,821 — (6,703) 5,083 17,304 (1,784) 30,721 Derivatives, net — — — (1,745) (25,271) — (27,016) Other expenses, net (25,357) 615 9,141 550 1,253 25,270 11,472 Total costs and expenses 123,365 42,159 6,391 110,028 41,465 (5,973) 317,435 Income (loss) before income taxes 54,433 13,219 (6,391) 14,033 (35,759) — 39,535 Income tax expense (benefit) 10,585 6,110 — 2,942 3,833 — 23,470 Net income (loss) $ 43,848 $ 7,109 $ (6,391) $ 11,091 $ (39,592) $ — $ 16,065 Consolidated capital expenditures $ 28,398 $ 15,397 $ 842 $ 49,629 $ 13,127 $ — $ 107,393 Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Nine months ended September 30, 2019 Revenues and other income: Oil and gas revenue $ 502,800 $ 208,667 $ — $ 338,292 $ — $ — $ 1,049,759 Other income, net 2 — — 459 97,594 (98,120) (65) Total revenues and other income 502,802 208,667 — 338,751 97,594 (98,120) 1,049,694 Costs and expenses: Oil and gas production 117,027 60,645 — 88,644 — — 266,316 Facilities insurance modifications, net (5,174) — — — — — (5,174) Exploration expenses 189 8,080 9,745 32,834 32,174 — 83,022 General and administrative 15,844 5,303 6,505 19,288 127,416 (85,653) 88,703 Depletion, depreciation and amortization 204,108 55,323 46 153,768 2,941 — 416,186 Interest and other financing costs, net(1) 56,500 — (20,020) 16,654 77,782 (5,351) 125,565 Derivatives, net — — — 28,768 7,116 — 35,884 Other expenses, net 6,761 (1,629) 9,783 2,695 1,304 (7,116) 11,798 Total costs and expenses 395,255 127,722 6,059 342,651 248,733 (98,120) 1,022,300 Income (loss) before income taxes 107,547 80,945 (6,059) (3,900) (151,139) — 27,394 Income tax expense (benefit) 30,285 33,403 — (824) (15,466) — 47,398 Net income (loss) $ 77,262 $ 47,542 $ (6,059) $ (3,076) $ (135,673) $ — $ (20,004) Consolidated capital expenditures $ 96,861 $ 36,448 $ 7,132 $ 136,688 $ 41,177 $ — $ 318,306 As of September 30, 2019 Property and equipment, net $ 1,603,170 $ 460,044 $ 428,596 $ 1,263,945 $ 43,281 $ — $ 3,799,036 Total assets $ 1,844,328 $ 489,564 $ 568,743 $ 3,309,044 $ 12,078,321 $ (13,821,741) $ 4,468,259 ______________________________________ (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, 2020 2019 (In thousands) Consolidated capital expenditures: Consolidated Statements of Cash Flows - Investing activities: Oil and gas assets $ 215,425 $ 240,642 Other property 1,838 8,291 Adjustments: Changes in capital accruals (6,284) 11,083 Exploration expense, excluding unsuccessful well costs and leasehold impairments(1) 49,955 75,661 Capitalized interest (18,062) (21,330) Other 7,486 3,959 Total consolidated capital expenditures $ 250,358 $ 318,306 ______________________________________ (1) Unsuccessful well costs are included in oil and gas assets when incurred.

Accounting Policies (Policies)

Accounting Policies (Policies)	9 Months Ended
	Sep. 30, 2020
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 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 consolidated financial statements and the accompanying notes should be read in conjunction with our audited consolidated financial statements for the year ended December 31, 2019, included in our annual report on Form 10-K.
Impairment of Long‑Lived Assets	Impairment of Long‑Lived Assets We review our long‑lived assets for impairment when changes in circumstances indicate that the carrying amount of an asset may not be recoverable. ASC 360 — Property, Plant and Equipment requires an impairment loss to be recognized if the carrying amount of a long‑lived asset is not recoverable and exceeds its fair value. The carrying amount of a long‑lived asset is not recoverable if it exceeds the sum of the undiscounted cash flows expected to result from the use and eventual disposition of the asset. That assessment shall be based on the carrying amount of the asset at the date it is tested for recoverability, whether in use or under development. Assets to be disposed of and assets not expected to provide any future service potential to us are recorded at the lower of carrying amount or fair value. Oil and gas properties are grouped in accordance with ASC 932 — Extractive Activities-Oil and Gas. The basis for grouping is a reasonable aggregation of properties typically by field or by logical grouping of assets with significant shared infrastructure. For long-lived assets whereby the carrying value exceeds the estimated future undiscounted cash flows, the carrying amount is reduced to fair value. Fair value is generally estimated using the income approach described in the ASC 820 — Fair Value Measurement. If applicable, we utilize prices and other relevant information generated by market transactions involving assets and liabilities that are identical or comparable to the item being measured as the basis for determining fair value. The expected future cash flows used for impairment reviews and related fair value measurements are typically based on judgmental assessments of future production, pricing estimates, capital and operating costs, market-based weighted average cost of capital, and risk adjustment factors applied to reserves. These assumptions are applied to develop future cash flow projections that are then discounted to estimated fair value, using a market-based weighted-average cost of capital. Although we base the fair value estimate of each asset group on assumptions we believe to be reasonable, those assumptions are inherently unpredictable and
Reclassifications	Reclassifications
Cash, Cash Equivalents and Restricted Cash	Cash, Cash Equivalents and Restricted Cash 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 plus the Corporate Revolver or the Facility, whichever is greater. As of September 30, 2020, we exceeded this ratio and expect to restrict approximately $28.5 million to meet our requirements during the fourth quarter of 2020.
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
Restructuring Charges	Restructuring ChargesThe Company accounts for restructuring charges and related termination benefits in accordance with ASC 712 — Compensation-Nonretirement Postemployment Benefits. Under this standard, the costs associated with termination benefits are recorded during the period in which the liability is incurred.
Concentration of Credit Risk	Concentration of Credit RiskOur revenue can be materially affected by current economic conditions and the price of oil. However, based on the current demand for crude oil and the fact that alternative purchasers are available, we believe that the loss of our marketing agent and/or any of the purchasers identified by our marketing agent would not have a long‑term material adverse effect on our financial position or results of operations. The continued economic disruption resulting from the COVID-19 pandemic 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. For our U.S. Gulf of Mexico operations, crude oil and natural gas are transported to customers using third-party pipelines.
Recent Accounting Standards	Recent Accounting Standards In June 2016, ASU 2016-13, "Measurement of Credit Losses on Financial Instruments," was issued requiring measurement of all expected credit losses for certain types of financial instruments, including trade receivables, held at the reporting date based on historical experience, current conditions and reasonable and supportable forecasts. This standard was effective January 1, 2020. We assessed all receivable positions for expected credit losses through the implementation of ASU 2016-13, current expected credit loss standard (CECL). Our receivables are collectible in the original term of the underlying agreements and current expected credit losses under the CECL standard are not significant. In December 2019, the FASB issued ASU 2019-12, “Simplifying the Accounting for Income Taxes”. The amendments in the ASU are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. Early adoption is permitted, however, we do not plan to early adopt ASU 2019-12 at this time. ASU 2019-12 is not expected to have a material impact on our income tax expense.

Accounting Policies (Tables)

Accounting Policies (Tables)	9 Months Ended
	Sep. 30, 2020
Accounting Policies [Abstract]
Schedule of cash and cash equivalents	September 30, 2020 December 31, 2019 (In thousands) Cash and cash equivalents $ 300,819 $ 224,502 Restricted cash - current 827 4,302 Restricted cash - long-term 542 542 Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 302,188 $ 229,346
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, 2020 2019 2020 2019 (In thousands) Revenues from contract with customer - Equatorial Guinea $ 43,003 $ 54,894 $ 95,520 $ 207,173 Revenues from contract with customer - Ghana 124,436 173,613 238,686 502,413 Revenues from contract with customers - U.S. Gulf of Mexico 55,620 123,861 198,294 338,292 Provisional oil sales contracts 1,727 4,668 (2,620) 1,881 Oil and gas revenue $ 224,786 $ 357,036 $ 529,880 $ 1,049,759

Property and Equipment (Tables)

Property and Equipment (Tables)	9 Months Ended
	Sep. 30, 2020
Property, Plant and Equipment [Abstract]
Schedule of property and equipment	Property and equipment is stated at cost and consisted of the following: September 30, 2020 December 31, 2019 (In thousands) Oil and gas properties: Proved properties $ 5,220,739 $ 4,904,648 Unproved properties 535,466 814,065 Total oil and gas properties 5,756,205 5,718,713 Accumulated depletion (2,401,721) (2,093,962) Oil and gas properties, net 3,354,484 3,624,751 Other property 59,987 61,598 Accumulated depreciation (48,167) (44,017) Other property, net 11,820 17,581 Property and equipment, net $ 3,366,304 $ 3,642,332

Suspended Well Costs (Tables)

Suspended Well Costs (Tables)	9 Months Ended
	Sep. 30, 2020
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, 2020. The table excludes $12.1 million in costs that were capitalized and expensed during the same period. During the first quarter of 2020, the exploratory well costs associated with the Greater Tortue Ahmeyim Unit were reclassified to proved property as the execution of the Tortue Phase 1 SPA in February 2020 resulted in recognition of proved undeveloped reserves at that time. September 30, 2020 (In thousands) Beginning balance $ 445,790 Additions to capitalized exploratory well costs pending the determination of proved reserves 2,098 Reclassification due to determination of proved reserves (263,849) Capitalized exploratory well costs charged to expense — Ending balance $ 184,039
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, 2020 December 31, 2019 (In thousands, except well counts) Exploratory well costs capitalized for a period of one year or less $ 28,750 $ 29,121 Exploratory well costs capitalized for a period of one to two years — 78,245 Exploratory well costs capitalized for a period of three years or greater 155,289 338,424 Ending balance $ 184,039 $ 445,790 Number of projects that have exploratory well costs that have been capitalized for a period greater than one year 2 3

Leases (Tables)

Leases (Tables)	9 Months Ended
	Sep. 30, 2020
Leases [Abstract]
Schedule of components of lease costs and cash flow information	The components of lease cost for the three and nine months ended September 30, 2020 and 2019 are as follows: Three Months Ended September 30, Nine months ended September 30, 2020 2019 2020 2019 (In thousands) Operating lease cost $ 1,511 $ 1,279 $ 4,668 $ 4,288 Short-term lease cost(1) 269 960 13,071 1,547 Total lease cost $ 1,780 $ 2,239 $ 17,739 $ 5,835 __________________________________ (1) Includes $12.2 million and zero during the nine months ended September 30, 2020 and 2019, respectively, of costs associated with short-term drilling contracts. The table below presents supplemental cash flow information related to leases during the nine months ended September 30, 2020 and 2019: Nine Months Ended September 30, 2020 2019 (In thousands) Operating cash flows for operating leases $ 3,816 $ 3,077 Investing cash flows for operating leases(1) 12,225 — __________________________________ (1) Represents costs associated with short-term drilling contracts.
Schedule of other information on leases	Other information related to operating leases at September 30, 2020 and 2019, is as follows: September 30, 2020 December 31, 2019 (In thousands, except lease term and discount rate) Balance sheet classifications Other assets (right-of-use assets) $ 18,288 $ 20,008 Accrued liabilities (current maturities of leases) 2,081 1,139 Other long-term liabilities (non-current maturities of leases) 20,651 22,240 Weighted average remaining lease term 8.2 years 8.8 years Weighted average discount rate 9.9 % 9.8 %
Schedule of future minimum rental commitments	Future minimum rental commitments under our leases at September 30, 2020, are as follows: Operating Leases(1) (In thousands) 2020(2) $ 1,039 2021 4,199 2022 4,262 2023 4,326 2024 3,489 Thereafter 16,106 Total undiscounted lease payments 33,421 Less: Imputed interest (10,689) Total lease liabilities $ 22,732 __________________________________ (1) Does not include purchase commitments for jointly owned fields and facilities where we are not the operator and excludes commitments for exploration activities, including well commitments, in our petroleum contracts. (2) Represents payments for the period from October 1, 2020 through December 31, 2020.

Debt (Tables)

Debt (Tables)	9 Months Ended
	Sep. 30, 2020
Debt Disclosure [Abstract]
Schedule of debt	September 30, 2020 December 31, 2019 (In thousands) Outstanding debt principal balances: Facility $ 1,450,000 $ 1,400,000 Corporate Revolver 100,000 — Senior Notes 650,000 650,000 GoM Term Loan 200,000 — Total 2,400,000 2,050,000 Unamortized deferred financing costs and discounts(1) (38,662) (41,937) Total debt, net 2,361,338 2,008,063 Less: Current maturities of long-term debt(2) (169,905) — Long-term debt, net $ 2,191,433 $ 2,008,063 __________________________________ (1) Includes $26.4 million and $32.8 million of unamortized deferred financing costs related to the Facility as of September 30, 2020 and December 31, 2019, respectively; $8.2 million and $9.1 million of unamortized deferred financing costs and discounts related to the Senior Notes as of September 30, 2020 and December 31, 2019, respectively; and $4.1 million and zero of unamortized deferred financing costs related to the GoM Term Loan as of September 30, 2020 and December 31, 2019, respectively. (2) As a result of the Facility redetermination in October 2020, the borrowing base was lowered to $1.32 billion and the Company expects to make repayments totaling $130 million during the fourth quarter of 2020.
Schedule of estimated repayments of debt	At September 30, 2020, the estimated repayments of debt during the five fiscal year periods and thereafter are as follows: Payments Due by Year Total 2020(2) 2021 2022 2023 2024 Thereafter (In thousands) Principal debt repayments(1) $ 2,400,000 $ 130,244 $ 73,333 $ 312,494 $ 458,571 $ 458,572 $ 966,786 __________________________________ (1) Includes the scheduled principal maturities for the $650.0 million aggregate principal amount of Senior Notes and borrowings under the Facility, Corporate Revolver and GoM Term Loan. The scheduled maturities of debt related to the Facility as of September 30, 2020 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, 2020 through December 31, 2020. As a result of the Facility redetermination in October 2020, the borrowing base was lowered to $1.32 billion and the Company expects to make repayments totaling $130 million during the fourth quarter of 2020.
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, 2020 2019 2020 2019 (In thousands) Interest expense $ 29,760 $ 34,944 $ 90,031 $ 111,566 Amortization—deferred financing costs 2,255 2,285 6,730 6,974 Loss on extinguishment of debt 678 — 2,893 24,794 Capitalized interest (5,806) (7,077) (18,062) (21,330) Deferred interest 531 290 2,028 1,559 Interest income (1,269) (972) (3,371) (2,215) Other, net 919 1,251 2,928 4,217 Interest and other financing costs, net $ 27,068 $ 30,721 $ 83,177 $ 125,565

Derivative Financial Instrume_2

Derivative Financial Instruments (Tables)	9 Months Ended
	Sep. 30, 2020
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, 2020. Volumes and weighted average prices are net of any offsetting derivative contracts entered into. Weighted Average Price per Bbl Net Deferred Premium Payable/ Sold Purchased Term Type of Contract Index MBbl (Receivable) Swap Put Floor Ceiling Call 2020: Oct — Dec Swaps Dated Brent 2,637 $ — $ 42.67 $ — $ — $ — $ — Oct — Dec Swaps Argus LLS 1,500 — 29.98 — — — — Oct — Dec Call spreads NYMEX WTI (1) 1.20 — — — 45.00 35.00 Oct — Dec Swaps with sold puts Dated Brent 167 — 35.00 25.00 — — — Oct — Dec Three-way collars Dated Brent 500 — — 25.00 32.50 40.00 — Oct — Dec Sold calls(2) Dated Brent 2,375 (0.19) — — — 80.83 — 2021: Jan — Dec Swaps with sold puts Dated Brent 6,000 $ — $ 53.96 $ 42.92 $ — $ — $ — Jan — Dec Three-way collars Dated Brent 2,000 0.50 — 30.00 40.00 55.20 — Jan — Dec Sold calls(2) Dated Brent 7,000 — — — — 70.09 — 2022: Jan — Dec Sold calls(2) Dated Brent 1,581 $ — $ — $ — $ — $ 60.00 $ — __________________________________ (1) Added call spreads on 0.5 million barrels to open upside for U.S. Gulf of Mexico production.
Schedule of derivative instruments by balance sheet location	The following tables disclose the Company’s derivative instruments as of September 30, 2020 and December 31, 2019, and gain/(loss) from derivatives during the three and nine months ended September 30, 2020 and 2019, respectively: Estimated Fair Value Asset (Liability) Type of Contract Balance Sheet Location September 30, 2020 December 31, 2019 (In thousands) Derivatives not designated as hedging instruments: Derivative assets: Commodity Derivatives assets—current $ 30,499 $ 12,856 Provisional oil sales Receivables: Oil Sales — (3,287) Commodity Derivatives assets—long-term 7,104 2,302 Derivative liabilities: Commodity Derivatives liabilities—current (24,589) (8,914) Commodity Derivatives liabilities—long-term (6,283) (11,478) Total derivatives not designated as hedging instruments $ 6,731 $ (8,521)
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) 2020 2019 2020 2019 (In thousands) Derivatives not designated as hedging instruments: Provisional oil sales Oil and gas revenue $ 1,727 $ 4,667 $ (2,620) $ 1,881 Commodity Derivatives, net (1,187) 27,016 34,776 (35,884) Total derivatives not designated as hedging instruments $ 540 $ 31,683 $ 32,156 $ (34,003)

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	9 Months Ended
	Sep. 30, 2020
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, 2020 and December 31, 2019, 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, 2020 Assets: Commodity derivatives $ — $ 37,603 $ — $ 37,603 Provisional oil sales — — — — Liabilities: Commodity derivatives — (30,872) — (30,872) Total $ — $ 6,731 $ — $ 6,731 December 31, 2019 Assets: Commodity derivatives $ — $ 15,158 $ — $ 15,158 Provisional oil sales — (3,287) — (3,287) Liabilities: Commodity derivatives — (20,392) — (20,392) Total $ — $ (8,521) $ — $ (8,521)
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, 2020 and December 31, 2019: September 30, 2020 December 31, 2019 Carrying Value Fair Value Carrying Value Fair Value (In thousands) Senior Notes $ 643,274 $ 569,088 $ 642,550 $ 664,957 GoM Term Loan 200,000 200,000 — — Corporate Revolver 100,000 100,000 — — Facility 1,450,000 1,450,000 1,400,000 1,400,000 Total $ 2,393,274 $ 2,319,088 $ 2,042,550 $ 2,064,957

Equity-based Compensation (Tabl

Equity-based Compensation (Tables)	9 Months Ended
	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Schedule of plan activity	The following table reflects the outstanding restricted stock units as of September 30, 2020: 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, 2019 4,731 $ 5.71 7,798 $ 8.42 Granted(1) 3,478 5.49 3,393 8.37 Forfeited(1) (907) 6.17 (478) 8.02 Vested (2,145) 5.90 (2,603) 9.47 Outstanding at September 30, 2020 5,157 5.38 8,110 8.11 __________________________________ (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, 2020
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, 2020 2019 2020 2019 (In thousands) United States $ (41,359) $ 3,464 $ (311,200) $ (70,776) Foreign—other 4,867 36,071 (89,332) 98,170 Income (loss) before income taxes $ (36,492) $ 39,535 $ (400,532) $ 27,394

Net Income (Loss) Per Share (Ta

Net Income (Loss) Per Share (Tables)	9 Months Ended
	Sep. 30, 2020
Earnings Per Share [Abstract]
Schedule of reconciliation between net income (loss) and amounts used to compute basic and diluted EPS	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, 2020 2019 2020 2019 (In thousands, except per share data) Numerator: Net income (loss) allocable to common stockholders $ (37,384) $ 16,065 $ (419,542) $ (20,004) Denominator: Weighted average number of shares outstanding: Basic 405,409 401,466 405,131 401,319 Restricted stock awards and units(1) — 9,526 — — Diluted 405,409 410,992 405,131 401,319 Net income (loss) per share: Basic $ (0.09) $ 0.04 $ (1.04) $ (0.05) Diluted $ (0.09) $ 0.04 $ (1.04) $ (0.05) __________________________________ (1) We excluded outstanding restricted stock awards and units of 11.6 million and 0.7 million for the three months ended September 30, 2020 and 2019, respectively, and 11.4 million and 15.4 million for the nine months ended September 30, 2020 and 2019, 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, 2020
Additional Financial Information
Schedule of accrued liabilities	Accrued liabilities consisted of the following: September 30, 2020 December 31, 2019 (In thousands) Accrued liabilities: Exploration, development and production $ 87,849 $ 152,490 Revenue payable 24,435 32,482 Current asset retirement obligations 2,673 4,527 General and administrative expenses 4,696 44,575 Interest 3,361 33,584 Income taxes 51,016 103,566 Taxes other than income 2,035 3,375 Derivatives 6,571 4,837 Other 3,994 1,268 $ 186,630 $ 380,704
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, 2020: September 30, 2020 (In thousands) Asset retirement obligations: Beginning asset retirement obligations $ 235,053 Liabilities incurred during period 2,781 Liabilities settled during period (4,113) Revisions in estimated retirement obligations 2,139 Accretion expense 14,377 Ending asset retirement obligations $ 250,237
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, 2020 2019 2020 2019 (In thousands) Loss on disposal of inventory $ 1,200 $ 1,232 $ 3,028 $ 1,419 (Gain) loss on ARO liability settlements (170) (746) 1,952 1,167 Restructuring charges (72) — 13,268 — Other, net 1,847 10,986 9,714 9,212 Other expenses, net $ 2,805 $ 11,472 $ 27,962 $ 11,798

Business Segment Information (T

Business Segment Information (Tables)	9 Months Ended
	Sep. 30, 2020
Segment Reporting [Abstract]
Schedule of business segment information	Financial information for each area is presented below: Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Three months ended September 30, 2020 Revenues and other income: Oil and gas revenue $ 125,636 $ 43,530 $ — $ 55,620 $ — $ — $ 224,786 Other income, net 1 — — 37 33,003 (33,040) 1 Total revenues and other income 125,637 43,530 — 55,657 33,003 (33,040) 224,787 Costs and expenses: Oil and gas production 48,709 14,072 — 21,496 — — 84,277 Facilities insurance modifications, net 2,465 — — — — — 2,465 Exploration expenses 48 1,561 806 5,485 6,077 — 13,977 General and administrative 3,101 1,017 1,168 3,580 39,472 (30,069) 18,269 Depletion, depreciation and amortization 63,487 15,421 15 31,499 809 — 111,231 Impairment of long-lived assets — — — — — — — Interest and other financing costs, net(1) 13,117 (344) (6,607) 4,372 18,314 (1,784) 27,068 Derivatives, net — — — — 1,187 — 1,187 Other expenses, net (1,818) 384 658 3,250 1,518 (1,187) 2,805 Total costs and expenses 129,109 32,111 (3,960) 69,682 67,377 (33,040) 261,279 Income (loss) before income taxes (3,472) 11,419 3,960 (14,025) (34,374) — (36,492) Income tax expense (849) 7,048 — — (5,307) — 892 Net income (loss) $ (2,623) $ 4,371 $ 3,960 $ (14,025) $ (29,067) $ — $ (37,384) Consolidated capital expenditures $ 6,116 $ 9,853 $ 46,574 $ 30,677 $ 6,287 $ — $ 99,507 Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Nine months ended September 30, 2020 Revenues and other income: Oil and gas revenue $ 236,536 $ 95,050 $ — $ 198,294 $ — $ — $ 529,880 Other income, net 2 — — 488 42,258 (42,746) 2 Total revenues and other income 236,538 95,050 — 198,782 42,258 (42,746) 529,882 Costs and expenses: Oil and gas production 113,319 50,961 — 70,347 — — 234,627 Facilities insurance modifications, net 10,555 — — — — — 10,555 Exploration expenses 146 6,397 5,265 26,046 36,439 — 74,293 General and administrative 10,123 3,977 5,453 10,433 99,551 (72,171) 57,366 Depletion, depreciation and amortization 148,135 43,724 46 132,213 2,272 — 326,390 Impairment of long-lived assets — — — 150,820 — — 150,820 Interest and other financing costs, net(1) 41,270 (1,044) (19,455) 12,052 55,705 (5,351) 83,177 Derivatives, net — — — — (34,776) — (34,776) Other expenses, net (64,142) (8,993) 3,129 46,995 16,197 34,776 27,962 Total costs and expenses 259,406 95,022 (5,562) 448,906 175,388 (42,746) 930,414 Income (loss) before income taxes (22,868) 28 5,562 (250,124) (133,130) — (400,532) Income tax expense (6,679) (1,622) — 30,902 (3,591) — 19,010 Net income (loss) $ (16,189) $ 1,650 $ 5,562 $ (281,026) $ (129,539) $ — $ (419,542) Consolidated capital expenditures $ 31,192 $ 25,959 $ 51,897 $ 109,228 $ 32,082 $ — 250,358 As of September 30, 2020 Property and equipment, net $ 1,373,126 $ 449,020 $ 502,355 $ 1,015,905 $ 25,898 $ — $ 3,366,304 Total assets $ 1,511,667 $ 708,614 $ 717,323 $ 3,221,915 $ 12,782,894 $ (14,848,912) $ 4,093,501 ______________________________________ (1) Interest expense is recorded based on actual third-party and intercompany debt agreements. Capitalized interest is recorded on the business unit where the assets reside. Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Three months ended September 30, 2019 Revenues and other income: Oil and gas revenue $ 177,797 $ 55,378 $ — $ 123,861 $ — $ — $ 357,036 Other income, net 1 — — 200 5,706 (5,973) (66) Total revenues and other income 177,798 55,378 — 124,061 5,706 (5,973) 356,970 Costs and expenses: Oil and gas production 42,017 21,369 — 32,154 — — 95,540 Facilities insurance modifications, net 12,569 — — — — — 12,569 Exploration expenses 82 2,437 1,260 10,625 8,369 — 22,773 General and administrative 3,886 1,719 2,678 7,002 38,897 (29,459) 24,723 Depletion, depreciation and amortization 73,347 16,019 15 56,359 913 — 146,653 Interest and other financing costs, net(1) 16,821 — (6,703) 5,083 17,304 (1,784) 30,721 Derivatives, net — — — (1,745) (25,271) — (27,016) Other expenses, net (25,357) 615 9,141 550 1,253 25,270 11,472 Total costs and expenses 123,365 42,159 6,391 110,028 41,465 (5,973) 317,435 Income (loss) before income taxes 54,433 13,219 (6,391) 14,033 (35,759) — 39,535 Income tax expense (benefit) 10,585 6,110 — 2,942 3,833 — 23,470 Net income (loss) $ 43,848 $ 7,109 $ (6,391) $ 11,091 $ (39,592) $ — $ 16,065 Consolidated capital expenditures $ 28,398 $ 15,397 $ 842 $ 49,629 $ 13,127 $ — $ 107,393 Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Nine months ended September 30, 2019 Revenues and other income: Oil and gas revenue $ 502,800 $ 208,667 $ — $ 338,292 $ — $ — $ 1,049,759 Other income, net 2 — — 459 97,594 (98,120) (65) Total revenues and other income 502,802 208,667 — 338,751 97,594 (98,120) 1,049,694 Costs and expenses: Oil and gas production 117,027 60,645 — 88,644 — — 266,316 Facilities insurance modifications, net (5,174) — — — — — (5,174) Exploration expenses 189 8,080 9,745 32,834 32,174 — 83,022 General and administrative 15,844 5,303 6,505 19,288 127,416 (85,653) 88,703 Depletion, depreciation and amortization 204,108 55,323 46 153,768 2,941 — 416,186 Interest and other financing costs, net(1) 56,500 — (20,020) 16,654 77,782 (5,351) 125,565 Derivatives, net — — — 28,768 7,116 — 35,884 Other expenses, net 6,761 (1,629) 9,783 2,695 1,304 (7,116) 11,798 Total costs and expenses 395,255 127,722 6,059 342,651 248,733 (98,120) 1,022,300 Income (loss) before income taxes 107,547 80,945 (6,059) (3,900) (151,139) — 27,394 Income tax expense (benefit) 30,285 33,403 — (824) (15,466) — 47,398 Net income (loss) $ 77,262 $ 47,542 $ (6,059) $ (3,076) $ (135,673) $ — $ (20,004) Consolidated capital expenditures $ 96,861 $ 36,448 $ 7,132 $ 136,688 $ 41,177 $ — $ 318,306 As of September 30, 2019 Property and equipment, net $ 1,603,170 $ 460,044 $ 428,596 $ 1,263,945 $ 43,281 $ — $ 3,799,036 Total assets $ 1,844,328 $ 489,564 $ 568,743 $ 3,309,044 $ 12,078,321 $ (13,821,741) $ 4,468,259 ______________________________________ (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, 2020 2019 (In thousands) Consolidated capital expenditures: Consolidated Statements of Cash Flows - Investing activities: Oil and gas assets $ 215,425 $ 240,642 Other property 1,838 8,291 Adjustments: Changes in capital accruals (6,284) 11,083 Exploration expense, excluding unsuccessful well costs and leasehold impairments(1) 49,955 75,661 Capitalized interest (18,062) (21,330) Other 7,486 3,959 Total consolidated capital expenditures $ 250,358 $ 318,306 ______________________________________ (1) Unsuccessful well costs are included in oil and gas assets when incurred.

Organization (Details)

Organization (Details)	9 Months Ended
	Sep. 30, 2020segment
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Number of reportable segments	4

Accounting Policies - Additiona

Accounting Policies - Additional Details (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Dec. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Apr. 30, 2019	Dec. 31, 2018USD ($)
Cash, Cash Equivalents and Restricted Cash
Cash and cash equivalents	$ 300,819		$ 300,819			$ 224,502
Restricted cash - current	827		827			4,302
Restricted cash - long-term	542		542			542
Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows	302,188	$ 215,058	302,188	$ 215,058		229,346		$ 185,616
Inventories
Materials and supplies inventory	131,700		131,700			112,300
Hydrocarbons inventory	10,500		10,500			$ 2,100
Restructuring Charges
Restructuring charges	$ (72)	$ 0	$ 13,268	$ 0
Phillips 66 Company | Sales revenue, net | Customer concentration risk
Concentration of Credit Risk
Concentration risk, percentage	18.00%	21.00%	29.00%	22.00%
Shell Trading (US) Company | Sales revenue, net | Customer concentration risk
Concentration of Credit Risk
Concentration risk, percentage	7.00%	11.00%	12.00%	9.00%
Facility
Cash, Cash Equivalents and Restricted Cash
Net leverage ratio	2.50		2.50
Facility interest Or Senior Notes Plus The Corporate Revolver
Cash, Cash Equivalents and Restricted Cash
Period for contractual future payments			6 months
Facility interest Or Senior Notes Plus The Corporate Revolver | Forecast
Cash, Cash Equivalents and Restricted Cash
Restricted cash - current					$ 28,500
Senior Notes | Senior Notes
Cash, Cash Equivalents and Restricted Cash
Interest rate							7.125%

Accounting Policies - Summary o

Accounting Policies - Summary of Oil and Gas Revenue (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Disaggregation of Revenue [Line Items]
Provisional oil sales contracts	$ 540	$ 31,683	$ 32,156	$ (34,003)
Oil and gas revenue	224,786	357,036	529,880	1,049,759
Oil and gas revenue
Disaggregation of Revenue [Line Items]
Provisional oil sales contracts	1,727	4,668	(2,620)	1,881
Oil and gas revenue	224,786	357,036	529,880	1,049,759
Equatorial Guinea
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	43,003	54,894	95,520	207,173
Ghana
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	124,436	173,613	238,686	502,413
U.S. Gulf Of Mexico
Disaggregation of Revenue [Line Items]
Revenue from contracts with customers	$ 55,620	$ 123,861	$ 198,294	$ 338,292

Acquisitions and Divestitures (

Acquisitions and Divestitures (Details)	Mar. 31, 2019	Sep. 30, 2020USD ($)well	Dec. 31, 2019USD ($)
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Portfolio of exploration assets, book value		$ 3,354,484,000	$ 3,624,751,000
Farm Down Agreement | Blocks Offshore Sao Tome And Principe, Suriname, Namibia, And South Africa
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Amount of cash consideration expected to be received for frontier exploration portfolio		96,000,000
Future contingent consideration		$ 50,000,000
Number of wells | well		4
Portfolio of exploration assets, book value		$ 4,500,000
Farm Down Agreement | Blocks Offshore Sao Tome And Principe, Suriname, Namibia, And South Africa | Maximum
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Future contingent consideration		$ 100,000,000
Farm In Agreement | Block EG-24
Property Plant and Equipment Acquisitions and Divestitures [Line Items]
Participation interest acquired	80.00%

Joint Interest Billings, Rela_2

Joint Interest Billings, Related Party Receivables and Notes Receivables (Details) $ in Thousands	1 Months Ended	12 Months Ended
	Feb. 28, 2019USD ($)Agreement	Dec. 31, 2014	Sep. 30, 2020USD ($)	Dec. 31, 2019USD ($)
Oil and Gas Joint Interest Billing Receivables [Line Items]
Joint interest billings, net			$ 36,423	$ 81,424
Long-term receivables			101,118	43,430
Carry Advance Agreements | National oil companies of Mauritania and Senegal
Oil and Gas Joint Interest Billing Receivables [Line Items]
Long-term receivables			83,500	27,400
Number of agreements | Agreement	2
Share of development costs to be financed, up to	$ 239,700
TEN discoveries | GNPC
Oil and Gas Joint Interest Billing Receivables [Line Items]
Joint interest billings, net			9,100	14,000
Long-term receivables			$ 17,600	$ 16,000
GNPC | TEN discoveries
Oil and Gas Joint Interest Billing Receivables [Line Items]
GNPC's paying interest		5.00%

Property and Equipment (Details

Property and Equipment (Details) - USD ($)	3 Months Ended			9 Months Ended
	Sep. 30, 2020	Jun. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Oil and gas properties:
Proved properties	$ 5,220,739,000			$ 5,220,739,000		$ 4,904,648,000
Unproved properties	535,466,000			535,466,000		814,065,000
Total oil and gas properties	5,756,205,000			5,756,205,000		5,718,713,000
Accumulated depletion	(2,401,721,000)			(2,401,721,000)		(2,093,962,000)
Oil and gas properties, net	3,354,484,000			3,354,484,000		3,624,751,000
Other property	59,987,000			59,987,000		61,598,000
Accumulated depreciation	(48,167,000)			(48,167,000)		(44,017,000)
Other property, net	11,820,000			11,820,000		17,581,000
Property and equipment, net	3,366,304,000		$ 3,799,036,000	3,366,304,000	$ 3,799,036,000	$ 3,642,332,000
Depletion expense	104,900,000		139,100,000	307,800,000	394,100,000
Impairment of long-lived assets	$ 0	$ 0	$ 0	$ 150,820,000	$ 0

Suspended Well Costs - Narrativ

Suspended Well Costs - Narrative (Details) $ in Millions	9 Months Ended
	Sep. 30, 2020USD ($)
Extractive Industries [Abstract]
Capitalized exploratory well costs subsequently expensed in the same period	$ 12.1

Suspended Well Costs - Summary

Suspended Well Costs - Summary of Suspended Well Costs (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2020USD ($)	Sep. 30, 2020USD ($)project	Dec. 31, 2019USD ($)project
Reconciliation of capitalized exploratory well costs on completed wells
Beginning balance	$ 445,790
Additions to capitalized exploratory well costs pending the determination of proved reserves	2,098
Reclassification due to determination of proved reserves	(263,849)
Capitalized exploratory well costs charged to expense	0
Ending balance	184,039
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		$ 28,750	$ 29,121
Exploratory well costs capitalized for a period of one to two years		0	78,245
Exploratory well costs capitalized for a period of three years or greater		155,289	338,424
Ending balance	$ 184,039	$ 184,039	$ 445,790
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year | project		2	3

Leases - Leases (Details)

Leases - Leases (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Lease, Cost [Abstract]
Operating lease cost	$ 1,511,000	$ 1,279,000	$ 4,668,000	$ 4,288,000
Short-term lease cost	269,000	960,000	13,071,000	1,547,000
Total lease cost	$ 1,780,000	$ 2,239,000	$ 17,739,000	5,835,000
Balance sheet classifications
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible List]	us-gaap:OtherAssets		us-gaap:OtherAssets		us-gaap:OtherAssets
Operating Lease, Liability, Current, Statement of Financial Position [Extensible List]	us-gaap:AccruedLiabilitiesCurrent		us-gaap:AccruedLiabilitiesCurrent		us-gaap:AccruedLiabilitiesCurrent
Operating Lease, Liability, Noncurrent, Statement of Financial Position [Extensible List]	us-gaap:OtherLiabilitiesNoncurrent		us-gaap:OtherLiabilitiesNoncurrent		us-gaap:OtherLiabilitiesNoncurrent
Other assets (right-of-use assets)	$ 18,288,000		$ 18,288,000		$ 20,008,000
Accrued liabilities (current maturities of leases)	2,081,000		2,081,000		1,139,000
Other long-term liabilities (non-current maturities of leases)	$ 20,651,000		$ 20,651,000		$ 22,240,000
Weighted average remaining lease term	8 years 2 months 12 days		8 years 2 months 12 days		8 years 9 months 18 days
Weighted average discount rate	9.90%		9.90%		9.80%
Operating cash flows for operating leases			$ 3,816,000	3,077,000
Investing cash flows for operating leases			12,225,000	0
Lessee, Operating Lease, Liability, Payment, Due [Abstract]
2020	$ 1,039,000		1,039,000
2021	4,199,000		4,199,000
2022	4,262,000		4,262,000
2023	4,326,000		4,326,000
2024	3,489,000		3,489,000
Thereafter	16,106,000		16,106,000
Total undiscounted lease payments	33,421,000		33,421,000
Less: Imputed interest	(10,689,000)		(10,689,000)
Total lease liabilities	$ 22,732,000		22,732,000
Short-term drilling contracts
Lease, Cost [Abstract]
Short-term lease cost			$ 12,200,000	$ 0
Minimum
Lessee, Lease, Description [Line Items]
Operating lease, initial term	1 year		1 year
Maximum
Lessee, Lease, Description [Line Items]
Operating lease, initial term	10 years		10 years

Debt - Schedule of Instruments

Debt - Schedule of Instruments (Details) - USD ($)	3 Months Ended
	Dec. 31, 2020	Oct. 31, 2020	Sep. 30, 2020	Apr. 30, 2020	Mar. 31, 2020	Dec. 31, 2019	Aug. 31, 2018
Debt
Total			$ 2,400,000,000			$ 2,050,000,000
Unamortized deferred financing costs and discounts			(38,662,000)			(41,937,000)
Total debt, net			2,361,338,000			2,008,063,000
Less: Current maturities of long-term debt			(169,905,000)			0
Long-term debt, net			2,191,433,000			2,008,063,000
Facility | Revolving credit facility
Debt
Total			1,450,000,000			1,400,000,000
Unamortized deferred financing costs			26,400,000			32,800,000
Maximum borrowing capacity				$ 1,500,000,000	$ 1,600,000,000
Facility | Revolving credit facility | Subsequent Event
Debt
Maximum borrowing capacity		$ 1,320,000,000
Facility | Revolving credit facility | Forecast
Debt
Repayments of debt	$ 130,000,000
Corporate Revolver | Revolving credit facility
Debt
Total			100,000,000			0
Maximum borrowing capacity							$ 400,000,000
Senior Notes | Senior Notes
Debt
Total			650,000,000			650,000,000
Unamortized deferred financing costs and discounts			(8,200,000)			(9,100,000)
GoM Term Loan | Secured Debt
Debt
Total			200,000,000			0
Unamortized deferred financing costs			$ 4,100,000			$ 0

Debt - Facility (Details)

Debt - Facility (Details)	1 Months Ended		3 Months Ended	9 Months Ended
	Jul. 31, 2020	Feb. 28, 2018	Dec. 31, 2020USD ($)	Sep. 30, 2020USD ($)	Oct. 31, 2020USD ($)	Apr. 30, 2020USD ($)	Mar. 31, 2020USD ($)	Dec. 31, 2019USD ($)	Apr. 30, 2019
Debt Instrument [Line Items]
Restricted cash				$ 827,000				$ 4,302,000
Facility
Debt Instrument [Line Items]
Net leverage ratio				2.50
Senior Notes | Senior Notes
Debt Instrument [Line Items]
Interest rate									7.125%
Facility interest Or Senior Notes Plus The Corporate Revolver
Debt Instrument [Line Items]
Period for contractual future payments				6 months
Facility interest Or Senior Notes Plus The Corporate Revolver | Forecast
Debt Instrument [Line Items]
Restricted cash			$ 28,500,000
Revolving credit facility | Facility
Debt Instrument [Line Items]
Amount outstanding				$ 1,450,000,000
Undrawn availability				50,000,000
Maximum borrowing capacity						$ 1,500,000,000	$ 1,600,000,000
Availability period of revolving-credit		1 month
Amount outstanding under letters of credit				$ 0
Revolving credit facility | Facility | Stated Period
Debt Instrument [Line Items]
Debt cover ratio	4.75
Revolving credit facility | Facility | Normal Period
Debt Instrument [Line Items]
Debt cover ratio	3.5
Revolving credit facility | Facility | Forecast
Debt Instrument [Line Items]
Repayments of debt			$ 130,000,000
Revolving credit facility | Facility | Subsequent Event
Debt Instrument [Line Items]
Maximum borrowing capacity					$ 1,320,000,000

Debt - Corporate Revolver (Deta

Debt - Corporate Revolver (Details)	1 Months Ended
	Jul. 31, 2020	Aug. 31, 2018USD ($)	Sep. 30, 2020USD ($)	Dec. 31, 2019USD ($)
Debt Instrument [Line Items]
Net deferred financing costs			$ 4,359,000	$ 6,321,000
Corporate Revolver | Revolving credit facility
Debt Instrument [Line Items]
Maximum borrowing capacity		$ 400,000,000
Applicable margin		5.00%
Commitment fee percentage		30.00%
Amount outstanding			100,000,000
Undrawn availability			300,000,000
Net deferred financing costs			$ 4,400,000
Corporate Revolver | Stated Period | Revolving credit facility
Debt Instrument [Line Items]
Debt cover ratio	4.75
Corporate Revolver | Normal Period | Revolving credit facility
Debt Instrument [Line Items]
Debt cover ratio	3.5

Debt - Letters of Credit (Detai

Debt - Letters of Credit (Details) $ in Millions	Oct. 31, 2020USD ($)	Dec. 31, 2019USD ($)letter_of_credit
Block 11 Offshore Sao Tome And Principe | Subsequent Event
Debt Instrument [Line Items]
Amount outstanding	$ 3.4
Letter of credit arrangement
Debt Instrument [Line Items]
Number of letters of credit | letter_of_credit		2
Amount outstanding		$ 20.4

Debt - 7.125% Senior Notes due

Debt - 7.125% Senior Notes due 2026 (Details) - Senior Notes - 7.125% Senior Notes due 2026	1 Months Ended
	Apr. 30, 2019USD ($)
Debt Instrument [Line Items]
Interest rate	7.125%
Debt, face amount	$ 650,000,000
Net proceeds from debt	$ 640,000,000

Debt - GoM Term Loan (Details)

Debt - GoM Term Loan (Details) - GoM Term Loan - Secured Debt	1 Months Ended
	Sep. 30, 2020USD ($)
Debt Instrument [Line Items]
Debt term	5 years
Debt, face amount	$ 200,000,000
Proceeds from debt, net of issuance costs	197,700,000
Additional incremental commitments	$ 100,000,000
Debt instrument, interest rate, effective percentage	6.00%
Trafigura
Debt Instrument [Line Items]
Debt, face amount	$ 50,000,000
Beal Bank
Debt Instrument [Line Items]
Debt, face amount	$ 150,000,000

Debt - Maturities (Details)

Debt - Maturities (Details) - USD ($)	3 Months Ended
	Dec. 31, 2020	Oct. 31, 2020	Sep. 30, 2020	Apr. 30, 2020	Mar. 31, 2020	Dec. 31, 2019
Scheduled maturities of debt during the five year period and thereafter
Total			$ 2,400,000,000			$ 2,050,000,000
2020			130,244,000
2021			73,333,000
2022			312,494,000
2023			458,571,000
2024			458,572,000
Thereafter			966,786,000
Facility | Revolving credit facility
Scheduled maturities of debt during the five year period and thereafter
Total			1,450,000,000			1,400,000,000
Maximum borrowing capacity				$ 1,500,000,000	$ 1,600,000,000
Facility | Revolving credit facility | Subsequent Event
Scheduled maturities of debt during the five year period and thereafter
Maximum borrowing capacity		$ 1,320,000,000
Facility | Revolving credit facility | Forecast
Scheduled maturities of debt during the five year period and thereafter
Repayments of debt	$ 130,000,000
Senior Notes | 7.125% Senior Notes due 2026
Scheduled maturities of debt during the five year period and thereafter
Total			$ 650,000,000			$ 650,000,000

Debt - Interest and Other Finan

Debt - Interest and Other Financing Costs, Net (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Debt Disclosure [Abstract]
Interest expense	$ 29,760	$ 34,944	$ 90,031	$ 111,566
Amortization—deferred financing costs	2,255	2,285	6,730	6,974
Loss on extinguishment of debt	678	0	2,893	24,794
Capitalized interest	(5,806)	(7,077)	(18,062)	(21,330)
Deferred interest	531	290	2,028	1,559
Interest income	(1,269)	(972)	(3,371)	(2,215)
Other, net	919	1,251	2,928	4,217
Interest and other financing costs, net	$ 27,068	$ 30,721	$ 83,177	$ 125,565

Production Prepayment Agreeme_2

Production Prepayment Agreement (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended	9 Months Ended
	Jun. 30, 2020	Jun. 30, 2020	Sep. 30, 2020	Sep. 30, 2019
Debt Instrument [Line Items]
Advances under production prepayment agreement			$ 50,000	$ 0
Trafigura
Debt Instrument [Line Items]
Advances under production prepayment agreement	$ 50,000	$ 50,000

Derivative Financial Instrume_3

Derivative Financial Instruments - Schedule of oil derivative contracts (Details)	9 Months Ended
	Sep. 30, 2020$ / bblMBbls
Dated Brent | Term October 2020 to December 2020 | Swaps
Derivative Financial Instruments
Volume (mbbls) | MBbls	2,637
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	0
Swap (usd per bbl)	42.67
Sold Put (usd per bbl)	0
Floor (usd per bbl)	0
Ceiling (usd per bbl)	0
Purchased Call (usd per bbl)	0
Dated Brent | Term October 2020 to December 2020 | Swaps with sold puts
Derivative Financial Instruments
Volume (mbbls) | MBbls	167
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	0
Swap (usd per bbl)	35
Sold Put (usd per bbl)	25
Floor (usd per bbl)	0
Ceiling (usd per bbl)	0
Purchased Call (usd per bbl)	0
Dated Brent | Term October 2020 to December 2020 | Three-way collars
Derivative Financial Instruments
Volume (mbbls) | MBbls	500
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	0
Swap (usd per bbl)	0
Sold Put (usd per bbl)	25
Floor (usd per bbl)	32.50
Ceiling (usd per bbl)	40
Purchased Call (usd per bbl)	0
Dated Brent | Term October 2020 to December 2020 | Sold calls
Derivative Financial Instruments
Volume (mbbls) | MBbls	2,375
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	(0.19)
Swap (usd per bbl)	0
Sold Put (usd per bbl)	0
Floor (usd per bbl)	0
Ceiling (usd per bbl)	80.83
Purchased Call (usd per bbl)	0
Dated Brent | Term January 2021 To December 2021 | Swaps with sold puts
Derivative Financial Instruments
Volume (mbbls) | MBbls	6,000
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	0
Swap (usd per bbl)	53.96
Sold Put (usd per bbl)	42.92
Floor (usd per bbl)	0
Ceiling (usd per bbl)	0
Purchased Call (usd per bbl)	0
Dated Brent | Term January 2021 To December 2021 | Three-way collars
Derivative Financial Instruments
Volume (mbbls) | MBbls	2,000
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	0.50
Swap (usd per bbl)	0
Sold Put (usd per bbl)	30
Floor (usd per bbl)	40
Ceiling (usd per bbl)	55.20
Purchased Call (usd per bbl)	0
Dated Brent | Term January 2021 To December 2021 | Sold calls
Derivative Financial Instruments
Volume (mbbls) | MBbls	7,000
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	0
Swap (usd per bbl)	0
Sold Put (usd per bbl)	0
Floor (usd per bbl)	0
Ceiling (usd per bbl)	70.09
Purchased Call (usd per bbl)	0
Dated Brent | Term January 2022 To December 2022 | Sold calls
Derivative Financial Instruments
Volume (mbbls) | MBbls	1,581
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	0
Swap (usd per bbl)	0
Sold Put (usd per bbl)	0
Floor (usd per bbl)	0
Ceiling (usd per bbl)	60
Purchased Call (usd per bbl)	0
Argus LLS | Term October 2020 to December 2020 | Swaps
Derivative Financial Instruments
Volume (mbbls) | MBbls	1,500
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	0
Swap (usd per bbl)	29.98
Sold Put (usd per bbl)	0
Floor (usd per bbl)	0
Ceiling (usd per bbl)	0
Purchased Call (usd per bbl)	0
NYMEX WTI | Term October 2020 to December 2020 | Call spreads
Derivative Financial Instruments
Volume (mbbls) | MBbls	500
Weighted Average Price Per Bbl [Abstract]
Net Deferred Premium Payable/(Receivable) usd per bbl)	1.20
Swap (usd per bbl)	0
Sold Put (usd per bbl)	0
Floor (usd per bbl)	0
Ceiling (usd per bbl)	45
Purchased Call (usd per bbl)	35

Derivative Financial Instrume_4

Derivative Financial Instruments - Narrative (Details) - Dated Brent	Nov. 09, 2020$ / bblMBbls	Apr. 30, 2020$ / bblMBbls	Sep. 30, 2020$ / bblMBbls
Swap Contracts | Term May 2020 to December 2020
Derivative Financial Instruments
Volume (mmbbls) | MBbls		7,000
Swap (usd per bbl)		42.67
Three-Way Collars | Term January 2021 To December 2021
Derivative Financial Instruments
Volume (mmbbls) | MBbls			2,000
Swap (usd per bbl)			0
Sold Put (usd per bbl)			30
Floor (usd per bbl)			40
Ceiling (usd per bbl)			55.20
Three-Way Collars | Term January 2021 To December 2021 | Subsequent Event
Derivative Financial Instruments
Volume (mmbbls) | MBbls	1,000
Sold Put (usd per bbl)	32.50
Floor (usd per bbl)	40
Ceiling (usd per bbl)	50

Derivative Financial Instrume_5

Derivative Financial Instruments - Derivatives instrument and gain/loss from derivatives (Details) - USD ($) $ in Thousands	Sep. 30, 2020	Dec. 31, 2019
Derivative instruments, Balance Sheet Location
Derivatives assets—current	$ 30,499	$ 12,856
Derivatives assets—long-term	7,104	2,302
Derivatives liabilities—current	(24,589)	(8,914)
Derivatives liabilities—long-term	(6,283)	(11,478)
Derivatives not designated as hedging instruments
Derivative instruments, Balance Sheet Location
Total derivatives not designated as hedging instruments	6,731	(8,521)
Derivatives not designated as hedging instruments | Commodity
Derivative instruments, Balance Sheet Location
Derivatives assets—current	30,499	12,856
Derivatives assets—long-term	7,104	2,302
Derivatives liabilities—current	(24,589)	(8,914)
Derivatives liabilities—long-term	(6,283)	(11,478)
Derivatives not designated as hedging instruments | Provisional oil sales | Receivables: Oil Sales
Derivative instruments, Balance Sheet Location
Derivatives assets—current	$ 0	$ (3,287)

Derivative Financial Instrume_6

Derivative Financial Instruments - Schedule of derivative instruments by location of gain/(loss) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Derivative instruments, Location of Gain/(Loss)
Amount of Gain/(Loss)	$ 540	$ 31,683	$ 32,156	$ (34,003)
Provisional oil sales | Oil and gas revenue
Derivative instruments, Location of Gain/(Loss)
Amount of Gain/(Loss)	1,727	4,667	(2,620)	1,881
Commodity | Derivatives, net
Derivative instruments, Location of Gain/(Loss)
Amount of Gain/(Loss)	$ (1,187)	$ 27,016	$ 34,776	$ (35,884)

Fair Value Measurements (Detail

Fair Value Measurements (Details)	3 Months Ended			9 Months Ended
	Sep. 30, 2020USD ($)	Jun. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Sep. 30, 2020USD ($)	Sep. 30, 2019USD ($)	Dec. 31, 2019USD ($)
Liabilities:
Impairment of long-lived assets	$ 0	$ 0	$ 0	$ 150,820,000	$ 0
Carrying Value
Liabilities:
Long-term debt	2,393,274,000			2,393,274,000		$ 2,042,550,000
Fair Value
Liabilities:
Long-term debt	2,319,088,000			2,319,088,000		2,064,957,000
Senior Notes | Senior Notes | Carrying Value
Liabilities:
Long-term debt	643,274,000			643,274,000		642,550,000
Senior Notes | Senior Notes | Fair Value
Liabilities:
Long-term debt	569,088,000			569,088,000		664,957,000
GoM Term Loan | Secured Debt | Carrying Value
Liabilities:
Long-term debt	200,000,000			200,000,000		0
GoM Term Loan | Secured Debt | Fair Value
Liabilities:
Long-term debt	200,000,000			200,000,000		0
Corporate Revolver | Facility | Carrying Value
Liabilities:
Long-term debt	100,000,000			100,000,000		0
Corporate Revolver | Facility | Fair Value
Liabilities:
Long-term debt	100,000,000			100,000,000		0
Facility | Facility | Carrying Value
Liabilities:
Long-term debt	1,450,000,000			1,450,000,000		1,400,000,000
Facility | Facility | Fair Value
Liabilities:
Long-term debt	1,450,000,000			1,450,000,000		1,400,000,000
Recurring basis
Liabilities:
Total fair value, net	6,731,000			6,731,000		(8,521,000)
Recurring basis | Quoted Prices in Active Markets for Identical Assets (Level 1)
Liabilities:
Total fair value, net	0			0		0
Recurring basis | Significant Other Observable Inputs (Level 2)
Liabilities:
Total fair value, net	6,731,000			6,731,000		(8,521,000)
Recurring basis | Significant Unobservable Inputs (Level 3)
Liabilities:
Total fair value, net	0			0		0
Recurring basis | Commodity derivatives
Assets:
Derivative asset, fair value	37,603,000			37,603,000		15,158,000
Liabilities:
Derivative liability, fair value	(30,872,000)			(30,872,000)		(20,392,000)
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	37,603,000			37,603,000		15,158,000
Liabilities:
Derivative liability, fair value	(30,872,000)			(30,872,000)		(20,392,000)
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		(3,287,000)
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		(3,287,000)
Recurring basis | Provisional oil sales | Significant Unobservable Inputs (Level 3)
Assets:
Derivative asset, fair value	0			0		$ 0
Nonrecurring basis
Liabilities:
Proved oil and gas reserves, fair value	$ 243,700,000			$ 243,700,000
Nonrecurring basis | Valuation technique, discounted cash flow | Measurement input, discount rate
Liabilities:
Long-lived assets, measurement input	0.10			0.10

Equity-based Compensation - Nar

Equity-based Compensation - Narrative (Details) - LTIP - USD ($)	1 Months Ended	3 Months Ended		9 Months Ended
	Mar. 31, 2018	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense recognized		$ 8,700,000	$ 9,500,000	$ 26,400,000	$ 27,400,000
Tax benefit		1,800,000	3,100,000	5,600,000	5,900,000
Net tax shortfall (windfall) related to equity-based compensation		100,000	0	1,200,000	1,200,000
Fair value of awards vested		$ 200,000	$ 700,000	$ 26,000,000	$ 14,700,000
Vesting period				3 years
Number of additional shares authorized (in shares)	11,000,000
Number of shares authorized (in shares)		50,500,000		50,500,000
Number of shares remaining available for grant (in shares)		6,000,000		6,000,000
Restricted Stock Units (RSUs)
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Compensation expense not yet recognized		$ 32,900,000		$ 32,900,000
Weighted average period over which compensation expense is to be recognized				1 year 10 months 9 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)				$ 8.37
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)				200.00%
Grant date fair value of awards granted (in dollars per share)				$ 12.96
Expected volatility				52.00%
Risk-free interest rate				2.50%
Expected quarterly dividends (in dollars per share)				$ 0.050
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)				0.00%
Grant date fair value of awards granted (in dollars per share)				$ 1.06
Expected volatility				44.00%
Risk-free interest rate				0.80%
Expected quarterly dividends (in dollars per share)				$ 0.045

Equity-based Compensation - Sch

Equity-based Compensation - Schedule of awards (Details) - LTIP shares in Thousands	9 Months Ended
	Sep. 30, 2020$ / sharesshares
Service Vesting Restricted Stock Units
Outstanding unvested awards activity
Outstanding at the beginning of the period (in shares) | shares	4,731
Granted (in shares) | shares	3,478
Forfeited (in shares) | shares	(907)
Vested (in shares) | shares	(2,145)
Outstanding at the end of the period (in shares) | shares	5,157
Weighted-Average Grant-Date Fair Value
Outstanding at beginning of the period (in dollars per share)	$ 5.71
Granted (in dollars per share)	5.49
Forfeited (in dollars per share)	6.17
Vested (in dollars per share)	5.90
Outstanding at the end of the period (in dollars per share)	$ 5.38
Market/Service Vesting Restricted Stock Units
Outstanding unvested awards activity
Outstanding at the beginning of the period (in shares) | shares	7,798
Granted (in shares) | shares	3,393
Forfeited (in shares) | shares	(478)
Vested (in shares) | shares	(2,603)
Outstanding at the end of the period (in shares) | shares	8,110
Weighted-Average Grant-Date Fair Value
Outstanding at beginning of the period (in dollars per share)	$ 8.42
Granted (in dollars per share)	8.37
Forfeited (in dollars per share)	8.02
Vested (in dollars per share)	9.47
Outstanding at the end of the period (in dollars per share)	8.11
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	0.00%
Market/Service Vesting Restricted Stock Units | Maximum
Weighted-Average Grant-Date Fair Value
Granted (in dollars per share)	$ 12.96
Vesting percentage of the awards granted	200.00%

Income Taxes (Details)

Income Taxes (Details) - USD ($)	3 Months Ended			9 Months Ended
	Sep. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Income Taxes
Effective tax rate	2.00%		59.00%	5.00%	173.00%
Tax benefit from CARES Act		$ 4,900,000
Income tax refund claim from CARES Act		$ 12,200,000
Income (loss) before income taxes	$ (36,492,000)		$ 39,535,000	$ (400,532,000)	$ 27,394,000
Uncertain tax positions	0			0
United States
Income Taxes
Increase in valuation allowance	8,500,000			94,600,000
Change in deferred tax expense related to valuation allowances				30,900,000
Income (loss) before income taxes	(41,359,000)		3,464,000	$ (311,200,000)	(70,776,000)
Foreign—other
Income Taxes
Effective tax rate				0.00%
Statutory tax rate				0.00%
Income (loss) before income taxes	$ 4,867,000		$ 36,071,000	$ (89,332,000)	$ 98,170,000

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, 2020	Jun. 30, 2020	Mar. 31, 2020	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Sep. 30, 2020	Sep. 30, 2019
Numerator:
Net income (loss) allocable to common stockholders	$ (37,384)	$ (199,391)	$ (182,767)	$ 16,065	$ 16,837	$ (52,906)	$ (419,542)	$ (20,004)
Weighted average number of shares outstanding:
Basic (in shares)	405,409			401,466			405,131	401,319
Restricted stock awards and units (in shares)	0			9,526			0	0
Diluted (in shares)	405,409			410,992			405,131	401,319
Net income (loss) per share:
Basic (in dollars per share)	$ (0.09)			$ 0.04			$ (1.04)	$ (0.05)
Diluted (in dollars per share)	$ (0.09)			$ 0.04			$ (1.04)	$ (0.05)
Outstanding restricted stock awards and units excluded from the computations of diluted net income per share (in shares)	11,600			700			11,400	15,400

Commitments and Contingencies (

Commitments and Contingencies (Details)	Mar. 26, 2020$ / shares	Sep. 30, 2020USD ($)$ / shares	Mar. 31, 2020$ / shares	Sep. 30, 2019$ / shares	Jun. 30, 2019$ / shares	Mar. 31, 2019$ / shares	Sep. 30, 2020USD ($)exploration_wellkmkm²$ / shares	Sep. 30, 2019$ / shares	Dec. 31, 2019USD ($)
Operating Leased Assets [Line Items]
Dividends declared per common stock (in dollars per share) | $ / shares	$ 0.0452	$ 0	$ 0.0452	$ 0.0452	$ 0.0452	$ 0.0452	$ 0.0452	$ 0.1356
Namibia
Operating Leased Assets [Line Items]
Number of exploration wells | exploration_well							1
Mauritania
Operating Leased Assets [Line Items]
Number of exploration wells | exploration_well							2
3D seismic requirements | km							100
Sao Tome and Principe
Operating Leased Assets [Line Items]
3D seismic requirements | km²							8,800
South Africa
Operating Leased Assets [Line Items]
2D seismic requirements | km							500
U.S. Gulf Of Mexico | Surety Bond
Operating Leased Assets [Line Items]
Cash collateral		$ 0					$ 0		$ 0
U.S. Gulf Of Mexico | Bureau of Ocean Energy Management | Surety Bond
Operating Leased Assets [Line Items]
Required performance bonds		195,400,000					195,400,000		195,400,000
U.S. Gulf Of Mexico | Third Party | Surety Bond
Operating Leased Assets [Line Items]
Required performance bonds		$ 7,200,000					$ 7,200,000		$ 7,200,000

Additional Financial Informat_3

Additional Financial Information (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019	Dec. 31, 2019
Accrued liabilities:
Exploration, development and production	$ 87,849,000		$ 87,849,000		$ 152,490,000
Revenue payable	24,435,000		24,435,000		32,482,000
Current asset retirement obligations	2,673,000		2,673,000		4,527,000
General and administrative expenses	4,696,000		4,696,000		44,575,000
Interest	3,361,000		3,361,000		33,584,000
Income taxes	51,016,000		51,016,000		103,566,000
Taxes other than income	2,035,000		2,035,000		3,375,000
Derivatives	6,571,000		6,571,000		4,837,000
Other	3,994,000		3,994,000		1,268,000
Accrued liabilities	186,630,000		186,630,000		$ 380,704,000
Asset retirement obligations:
Beginning asset retirement obligations			235,053,000
Liabilities incurred during period			2,781,000
Liabilities settled during period			(4,113,000)
Revisions in estimated retirement obligations			2,139,000
Accretion expense			14,377,000
Ending asset retirement obligations	250,237,000		250,237,000
Facilities insurance modifications, expenditures	2,500,000	$ 12,600,000	10,600,000	$ 34,800,000
Facilities insurance modifications, insurance recoveries			0	40,000,000
Other Expenses, Net
Loss on disposal of inventory	1,200,000	1,232,000	3,028,000	1,419,000
(Gain) loss on ARO liability settlements	(170,000)	(746,000)	1,952,000	1,167,000
Restructuring charges	(72,000)	0	13,268,000	0
Other, net	1,847,000	10,986,000	9,714,000	9,212,000
Other expenses, net	$ 2,805,000	$ 11,472,000	$ 27,962,000	$ 11,798,000

Business Segment Information -

Business Segment Information - Business Segment Information (Details)	3 Months Ended						9 Months Ended
	Sep. 30, 2020USD ($)	Jun. 30, 2020USD ($)	Mar. 31, 2020USD ($)	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Sep. 30, 2020USD ($)segment	Sep. 30, 2019USD ($)	Dec. 31, 2019USD ($)
Segment Reporting Information [Line Items]
Number of reportable segments | segment							4
Oil and gas revenue	$ 224,786,000			$ 357,036,000			$ 529,880,000	$ 1,049,759,000
Other income, net	1,000			(66,000)			2,000	(65,000)
Total revenues and other income	224,787,000			356,970,000			529,882,000	1,049,694,000
Oil and gas production	84,277,000			95,540,000			234,627,000	266,316,000
Facilities insurance modifications, net	2,465,000			12,569,000			10,555,000	(5,174,000)
Exploration expenses	13,977,000			22,773,000			74,293,000	83,022,000
General and administrative	18,269,000			24,723,000			57,366,000	88,703,000
Depletion, depreciation and amortization	111,231,000			146,653,000			326,390,000	416,186,000
Impairment of long-lived assets	0	$ 0		0			150,820,000	0
Interest and other financing costs, net	27,068,000			30,721,000			83,177,000	125,565,000
Derivatives, net	1,187,000			(27,016,000)			(34,776,000)	35,884,000
Other expenses, net	2,805,000			11,472,000			27,962,000	11,798,000
Total costs and expenses	261,279,000			317,435,000			930,414,000	1,022,300,000
Income (loss) before income taxes	(36,492,000)			39,535,000			(400,532,000)	27,394,000
Income tax expense	892,000			23,470,000			19,010,000	47,398,000
Net income (loss)	(37,384,000)	$ (199,391,000)	$ (182,767,000)	16,065,000	$ 16,837,000	$ (52,906,000)	(419,542,000)	(20,004,000)
Consolidated capital expenditures	99,507,000			107,393,000			250,358,000	318,306,000
Property and equipment, net	3,366,304,000			3,799,036,000			3,366,304,000	3,799,036,000	$ 3,642,332,000
Total assets	4,093,501,000			4,468,259,000			4,093,501,000	4,468,259,000	$ 4,317,232,000
Corporate & Other
Segment Reporting Information [Line Items]
Oil and gas revenue	0			0			0	0
Other income, net	33,003,000			5,706,000			42,258,000	97,594,000
Total revenues and other income	33,003,000			5,706,000			42,258,000	97,594,000
Oil and gas production	0			0			0	0
Facilities insurance modifications, net	0			0			0	0
Exploration expenses	6,077,000			8,369,000			36,439,000	32,174,000
General and administrative	39,472,000			38,897,000			99,551,000	127,416,000
Depletion, depreciation and amortization	809,000			913,000			2,272,000	2,941,000
Impairment of long-lived assets	0						0
Interest and other financing costs, net	18,314,000			17,304,000			55,705,000	77,782,000
Derivatives, net	1,187,000			(25,271,000)			(34,776,000)	7,116,000
Other expenses, net	1,518,000			1,253,000			16,197,000	1,304,000
Total costs and expenses	67,377,000			41,465,000			175,388,000	248,733,000
Income (loss) before income taxes	(34,374,000)			(35,759,000)			(133,130,000)	(151,139,000)
Income tax expense	(5,307,000)			3,833,000			(3,591,000)	(15,466,000)
Net income (loss)	(29,067,000)			(39,592,000)			(129,539,000)	(135,673,000)
Consolidated capital expenditures	6,287,000			13,127,000			32,082,000	41,177,000
Property and equipment, net	25,898,000			43,281,000			25,898,000	43,281,000
Total assets	12,782,894,000			12,078,321,000			12,782,894,000	12,078,321,000
Eliminations
Segment Reporting Information [Line Items]
Oil and gas revenue	0			0			0	0
Other income, net	(33,040,000)			(5,973,000)			(42,746,000)	(98,120,000)
Total revenues and other income	(33,040,000)			(5,973,000)			(42,746,000)	(98,120,000)
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	(30,069,000)			(29,459,000)			(72,171,000)	(85,653,000)
Depletion, depreciation and amortization	0			0			0	0
Impairment of long-lived assets	0						0
Interest and other financing costs, net	(1,784,000)			(1,784,000)			(5,351,000)	(5,351,000)
Derivatives, net	0			0			0	0
Other expenses, net	(1,187,000)			25,270,000			34,776,000	(7,116,000)
Total costs and expenses	(33,040,000)			(5,973,000)			(42,746,000)	(98,120,000)
Income (loss) before income taxes	0			0			0	0
Income tax expense	0			0			0	0
Net income (loss)	0			0			0	0
Consolidated capital expenditures	0			0			0	0
Property and equipment, net	0			0			0	0
Total assets	(14,848,912,000)			(13,821,741,000)			(14,848,912,000)	(13,821,741,000)
Ghana | Operating Segments
Segment Reporting Information [Line Items]
Oil and gas revenue	125,636,000			177,797,000			236,536,000	502,800,000
Other income, net	1,000			1,000			2,000	2,000
Total revenues and other income	125,637,000			177,798,000			236,538,000	502,802,000
Oil and gas production	48,709,000			42,017,000			113,319,000	117,027,000
Facilities insurance modifications, net	2,465,000			12,569,000			10,555,000	(5,174,000)
Exploration expenses	48,000			82,000			146,000	189,000
General and administrative	3,101,000			3,886,000			10,123,000	15,844,000
Depletion, depreciation and amortization	63,487,000			73,347,000			148,135,000	204,108,000
Impairment of long-lived assets	0						0
Interest and other financing costs, net	13,117,000			16,821,000			41,270,000	56,500,000
Derivatives, net	0			0			0	0
Other expenses, net	(1,818,000)			(25,357,000)			(64,142,000)	6,761,000
Total costs and expenses	129,109,000			123,365,000			259,406,000	395,255,000
Income (loss) before income taxes	(3,472,000)			54,433,000			(22,868,000)	107,547,000
Income tax expense	(849,000)			10,585,000			(6,679,000)	30,285,000
Net income (loss)	(2,623,000)			43,848,000			(16,189,000)	77,262,000
Consolidated capital expenditures	6,116,000			28,398,000			31,192,000	96,861,000
Property and equipment, net	1,373,126,000			1,603,170,000			1,373,126,000	1,603,170,000
Total assets	1,511,667,000			1,844,328,000			1,511,667,000	1,844,328,000
Equatorial Guinea | Operating Segments
Segment Reporting Information [Line Items]
Oil and gas revenue	43,530,000			55,378,000			95,050,000	208,667,000
Other income, net	0			0			0	0
Total revenues and other income	43,530,000			55,378,000			95,050,000	208,667,000
Oil and gas production	14,072,000			21,369,000			50,961,000	60,645,000
Facilities insurance modifications, net	0			0			0	0
Exploration expenses	1,561,000			2,437,000			6,397,000	8,080,000
General and administrative	1,017,000			1,719,000			3,977,000	5,303,000
Depletion, depreciation and amortization	15,421,000			16,019,000			43,724,000	55,323,000
Impairment of long-lived assets	0						0
Interest and other financing costs, net	(344,000)			0			(1,044,000)	0
Derivatives, net	0			0			0	0
Other expenses, net	384,000			615,000			(8,993,000)	(1,629,000)
Total costs and expenses	32,111,000			42,159,000			95,022,000	127,722,000
Income (loss) before income taxes	11,419,000			13,219,000			28,000	80,945,000
Income tax expense	7,048,000			6,110,000			(1,622,000)	33,403,000
Net income (loss)	4,371,000			7,109,000			1,650,000	47,542,000
Consolidated capital expenditures	9,853,000			15,397,000			25,959,000	36,448,000
Property and equipment, net	449,020,000			460,044,000			449,020,000	460,044,000
Total assets	708,614,000			489,564,000			708,614,000	489,564,000
Mauritania/Senegal | Operating Segments
Segment Reporting Information [Line Items]
Oil and gas revenue	0			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	806,000			1,260,000			5,265,000	9,745,000
General and administrative	1,168,000			2,678,000			5,453,000	6,505,000
Depletion, depreciation and amortization	15,000			15,000			46,000	46,000
Impairment of long-lived assets	0						0
Interest and other financing costs, net	(6,607,000)			(6,703,000)			(19,455,000)	(20,020,000)
Derivatives, net	0			0			0	0
Other expenses, net	658,000			9,141,000			3,129,000	9,783,000
Total costs and expenses	(3,960,000)			6,391,000			(5,562,000)	6,059,000
Income (loss) before income taxes	3,960,000			(6,391,000)			5,562,000	(6,059,000)
Income tax expense	0			0			0	0
Net income (loss)	3,960,000			(6,391,000)			5,562,000	(6,059,000)
Consolidated capital expenditures	46,574,000			842,000			51,897,000	7,132,000
Property and equipment, net	502,355,000			428,596,000			502,355,000	428,596,000
Total assets	717,323,000			568,743,000			717,323,000	568,743,000
U.S. Gulf of Mexico | Operating Segments
Segment Reporting Information [Line Items]
Oil and gas revenue	55,620,000			123,861,000			198,294,000	338,292,000
Other income, net	37,000			200,000			488,000	459,000
Total revenues and other income	55,657,000			124,061,000			198,782,000	338,751,000
Oil and gas production	21,496,000			32,154,000			70,347,000	88,644,000
Facilities insurance modifications, net	0			0			0	0
Exploration expenses	5,485,000			10,625,000			26,046,000	32,834,000
General and administrative	3,580,000			7,002,000			10,433,000	19,288,000
Depletion, depreciation and amortization	31,499,000			56,359,000			132,213,000	153,768,000
Impairment of long-lived assets	0						150,820,000
Interest and other financing costs, net	4,372,000			5,083,000			12,052,000	16,654,000
Derivatives, net	0			(1,745,000)			0	28,768,000
Other expenses, net	3,250,000			550,000			46,995,000	2,695,000
Total costs and expenses	69,682,000			110,028,000			448,906,000	342,651,000
Income (loss) before income taxes	(14,025,000)			14,033,000			(250,124,000)	(3,900,000)
Income tax expense	0			2,942,000			30,902,000	(824,000)
Net income (loss)	(14,025,000)			11,091,000			(281,026,000)	(3,076,000)
Consolidated capital expenditures	30,677,000			49,629,000			109,228,000	136,688,000
Property and equipment, net	1,015,905,000			1,263,945,000			1,015,905,000	1,263,945,000
Total assets	$ 3,221,915,000			$ 3,309,044,000			$ 3,221,915,000	$ 3,309,044,000

Business Segment Information _2

Business Segment Information - Consolidated Capital Expenditures (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2020	Sep. 30, 2019	Sep. 30, 2020	Sep. 30, 2019
Segment Reporting [Abstract]
Oil and gas assets			$ 215,425	$ 240,642
Other property			1,838	8,291
Changes in capital accruals			(6,284)	11,083
Exploration expense, excluding unsuccessful well costs and leasehold improvements			49,955	75,661
Capitalized interest			(18,062)	(21,330)
Other			7,486	3,959
Consolidated capital expenditures	$ 99,507	$ 107,393	$ 250,358	$ 318,306