Cover
Cover - shares | 6 Months Ended | |
Jun. 30, 2019 | Aug. 01, 2019 | |
Cover page. | ||
Document Type | 10-Q | |
Document Quarterly Report | true | |
Document Period End Date | Jun. 30, 2019 | |
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 $0.01 par value | |
Trading Symbol | KOS | |
Security Exchange Name | NYSE | |
City Area Code | 214 | |
Local Phone Number | 445 9600 | |
Entity Current Reporting Status | Yes | |
Entity Interactive Data Current | Yes | |
Entity Filer Category | Large Accelerated Filer | |
Entity Small Business | false | |
Entity Emerging Growth Company | false | |
Entity Shell Company | false | |
Entity Common Stock, Shares Outstanding | 401,458,556 | |
Entity Central Index Key | 0001509991 | |
Document Fiscal Year Focus | 2019 | |
Document Fiscal Period Focus | Q2 | |
Amendment Flag | false | |
Current Fiscal Year End Date | --12-31 |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands | Jun. 30, 2019 | Dec. 31, 2018 |
Current assets: | ||
Cash and cash equivalents | $ 176,908 | $ 173,515 |
Restricted cash | 327 | 4,527 |
Receivables: | ||
Joint interest billings, net | 55,360 | 64,572 |
Oil sales | 83,685 | 48,164 |
Related party | 0 | 5,580 |
Other | 21,899 | 21,690 |
Inventories | 108,528 | 84,827 |
Prepaid expenses and other | 41,496 | 68,040 |
Derivatives | 11,511 | 38,785 |
Total current assets | 499,714 | 509,700 |
Property and equipment: | ||
Oil and gas properties, net | 3,832,525 | 3,444,864 |
Other property, net | 15,048 | 14,837 |
Property and equipment, net | 3,847,573 | 3,459,701 |
Other assets: | ||
Equity method investment | 0 | 51,896 |
Restricted cash | 7,574 | 7,574 |
Long-term receivables | 28,140 | 19,002 |
Deferred financing costs, net of accumulated amortization of $13,373 and $12,065 at June 30, 2019 and December 31, 2018, respectively | 7,629 | 8,937 |
Deferred tax assets | 43,710 | 14,004 |
Derivatives | 7,264 | 14,312 |
Other | 24,130 | 3,063 |
Total assets | 4,465,734 | 4,088,189 |
Current liabilities: | ||
Accounts payable | 157,373 | 176,540 |
Accrued liabilities | 258,379 | 195,596 |
Derivatives | 26,897 | 12,172 |
Total current liabilities | 442,649 | 384,308 |
Long-term liabilities: | ||
Long-term debt, net | 2,129,340 | 2,120,547 |
Derivatives | 5,776 | 10,181 |
Asset retirement obligations | 276,692 | 145,336 |
Deferred tax liabilities | 697,792 | 477,179 |
Other long-term liabilities | 29,274 | 9,160 |
Total long-term liabilities | 3,138,874 | 2,762,403 |
Stockholders’ equity: | ||
Preference shares, $0.01 par value; 200,000,000 authorized shares; zero issued at June 30, 2019 and December 31, 2018 | 0 | 0 |
Common stock, $0.01 par value; 2,000,000,000 authorized shares; 445,638,161 and 442,914,675 issued at June 30, 2019 and December 31, 2018, respectively | 4,456 | 4,429 |
Additional paid-in capital | 2,320,024 | 2,341,249 |
Accumulated deficit | (1,203,262) | (1,167,193) |
Treasury stock, at cost, 44,263,269 and 44,263,269 shares at June 30, 2019 and December 31, 2018, respectively | (237,007) | (237,007) |
Total stockholders’ equity | 884,211 | 941,478 |
Total liabilities and stockholders’ equity | $ 4,465,734 | $ 4,088,189 |
CONSOLIDATED BALANCE SHEETS (Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands | Jun. 30, 2019 | Dec. 31, 2018 |
Statement of Financial Position [Abstract] | ||
Deferred financing costs, accumulated amortization | $ 13,373 | $ 12,065 |
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) | 445,638,161 | 442,914,675 |
Treasury stock shares (in shares) | 44,263,269 | 44,263,269 |
CONSOLIDATED STATEMENTS OF OPER
CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands, $ in Thousands | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2019 | Mar. 31, 2019 | Jun. 30, 2018 | Mar. 31, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Revenues and other income: | ||||||
Oil and gas revenue | $ 395,933 | $ 215,191 | $ 692,723 | $ 342,387 | ||
Other income, net | 1 | 282 | 1 | 263 | ||
Total revenues and other income | 395,934 | 215,473 | 692,724 | 342,650 | ||
Costs and expenses: | ||||||
Oil and gas production | 90,977 | 49,815 | 170,776 | 96,583 | ||
Facilities insurance modifications, net | 2,278 | 1,029 | (17,743) | 9,478 | ||
Exploration expenses | 29,905 | 77,481 | 60,249 | 98,674 | ||
General and administrative | 28,072 | 17,497 | 63,980 | 39,380 | ||
Depletion, depreciation and amortization | 151,438 | 74,289 | 269,533 | 128,566 | ||
Interest and other financing costs, net | 59,803 | 18,870 | 94,844 | 44,564 | ||
Derivatives, net | (14,185) | 140,272 | 62,900 | 178,750 | ||
Gain on equity method investments, net | 0 | (16,100) | 0 | (34,796) | ||
Other expenses, net | (1,793) | 938 | 326 | 4,643 | ||
Total costs and expenses | 346,495 | 364,091 | 704,865 | 565,842 | ||
Income (loss) before income taxes | 49,439 | (148,618) | (12,141) | (223,192) | ||
Income tax expense (benefit) | 32,602 | (45,345) | 23,928 | (69,693) | ||
Net income (loss) | $ 16,837 | $ (52,906) | $ (103,273) | $ (50,226) | $ (36,069) | $ (153,499) |
Net income (loss) per share: | ||||||
Basic (in dollars per share) | $ 0.04 | $ (0.26) | $ (0.09) | $ (0.39) | ||
Diluted (in dollars per share) | $ 0.04 | $ (0.26) | $ (0.09) | $ (0.39) | ||
Weighted average number of shares used to compute net income (loss) per share: | ||||||
Basic (in shares) | 401,323 | 396,826 | 401,244 | 396,218 | ||
Diluted (in shares) | 408,230 | 396,826 | 401,244 | 396,218 | ||
Dividends declared per common stock (in dollars per share) | $ 0.0452 | $ 0.0452 | $ 0 | $ 0.0904 | $ 0 |
CONSOLIDATED STATEMENTS OF SHAR
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' 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, 2017 | 398,599 | ||||
Balance at the beginning at Dec. 31, 2017 | $ 897,112 | $ 3,986 | $ 2,014,525 | $ (1,073,202) | $ (48,197) |
Increase (Decrease) in Shareholders' Equity | |||||
Equity-based compensation | 8,392 | 8,392 | |||
Restricted stock awards and units (in shares) | 6,380 | ||||
Restricted stock awards and units | 0 | $ 64 | (64) | ||
Purchase of treasury stock / tax withholdings | (11,874) | (11,364) | (510) | ||
Net (loss) income | (50,226) | (50,226) | |||
Balance at the end (in shares) at Mar. 31, 2018 | 404,979 | ||||
Balance at the end at Mar. 31, 2018 | 843,404 | $ 4,050 | 2,011,489 | (1,123,428) | (48,707) |
Balance at the beginning (in shares) at Dec. 31, 2017 | 398,599 | ||||
Balance at the beginning at Dec. 31, 2017 | 897,112 | $ 3,986 | 2,014,525 | (1,073,202) | (48,197) |
Increase (Decrease) in Shareholders' Equity | |||||
Net (loss) income | (153,499) | ||||
Balance at the end (in shares) at Jun. 30, 2018 | 407,557 | ||||
Balance at the end at Jun. 30, 2018 | 744,131 | $ 4,076 | 2,015,463 | (1,226,701) | (48,707) |
Balance at the beginning (in shares) at Mar. 31, 2018 | 404,979 | ||||
Balance at the beginning at Mar. 31, 2018 | 843,404 | $ 4,050 | 2,011,489 | (1,123,428) | (48,707) |
Increase (Decrease) in Shareholders' Equity | |||||
Equity-based compensation | 9,821 | 9,821 | |||
Restricted stock awards and units (in shares) | 2,578 | ||||
Restricted stock awards and units | 0 | $ 26 | (26) | ||
Purchase of treasury stock / tax withholdings | (5,821) | (5,821) | |||
Net (loss) income | (103,273) | (103,273) | |||
Balance at the end (in shares) at Jun. 30, 2018 | 407,557 | ||||
Balance at the end at Jun. 30, 2018 | 744,131 | $ 4,076 | 2,015,463 | (1,226,701) | (48,707) |
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 (loss) income | (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) |
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 (loss) income | (36,069) | ||||
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) |
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 (loss) income | 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) |
CONSOLIDATED STATEMENTS OF SH_2
CONSOLIDATED STATEMENTS OF SHAREHOLDERS' EQUITY (Parenthetical) - $ / shares | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2019 | Mar. 31, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Statement of Stockholders' Equity [Abstract] | |||||
Dividends declared per common stock (in dollars per share) | $ 0.0452 | $ 0.0452 | $ 0 | $ 0.0904 | $ 0 |
CONSOLIDATED STATEMENTS OF CASH
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands | 6 Months Ended | |
Jun. 30, 2019 | Jun. 30, 2018 | |
Operating activities | ||
Net loss | $ (36,069) | $ (153,499) |
Adjustments to reconcile net loss to net cash provided by operating activities: | ||
Depletion, depreciation and amortization | 274,222 | 133,289 |
Deferred income taxes | (56,730) | (81,876) |
Unsuccessful well costs and leasehold impairments | 7,099 | 44,654 |
Change in fair value of derivatives | 65,686 | 177,790 |
Cash settlements on derivatives, net (including $(18.7) million and $(57.3) million on commodity hedges during 2019 and 2018) | (21,044) | (56,221) |
Equity-based compensation | 17,932 | 17,085 |
Loss on extinguishment of debt | 24,794 | 4,056 |
Distributions in excess of equity in earnings | 0 | 5,234 |
Other | 7,417 | 449 |
Changes in assets and liabilities: | ||
(Increase) decrease in receivables | (23,996) | 10,067 |
(Increase) decrease in inventories | (19,021) | 800 |
Decrease in prepaid expenses and other | 29,380 | 4,888 |
Decrease in accounts payable | (76,031) | (13,316) |
Increase (decrease) in accrued liabilities | 28,751 | (92,967) |
Net cash provided by operating activities | 222,390 | 433 |
Investing activities | ||
Oil and gas assets | (153,268) | (92,650) |
Other property | (5,230) | (2,815) |
Return of investment from KTIPI | 0 | 79,970 |
Notes receivable from partners | (5,983) | 0 |
Net cash used in investing activities | (164,481) | (15,495) |
Financing activities | ||
Borrowings under long-term debt | 175,000 | 0 |
Payments on long-term debt | (300,000) | (100,000) |
Net proceeds from issuance of senior notes | 641,875 | 0 |
Redemption of senior secured notes | (535,338) | 0 |
Purchase of treasury stock / tax withholdings | (1,983) | (17,695) |
Dividends | (36,289) | 0 |
Deferred financing costs | (1,981) | (25,743) |
Net cash used in financing activities | (58,716) | (143,438) |
Net decrease in cash, cash equivalents and restricted cash | (807) | (158,500) |
Cash, cash equivalents and restricted cash at beginning of period | 185,616 | 304,986 |
Cash, cash equivalents and restricted cash at end of period | 184,809 | 146,486 |
Cash paid for: | ||
Interest, net of capitalized interest | 65,307 | 47,845 |
Income taxes | $ 14,619 | $ 22,596 |
CONSOLIDATED STATEMENTS OF CA_2
CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions | 6 Months Ended | |
Jun. 30, 2019 | Jun. 30, 2018 | |
Statement of Cash Flows [Abstract] | ||
Cash settlements on derivatives, net (commodity hedges) | $ (18.7) | $ (57.3) |
Organization
Organization | 6 Months Ended |
Jun. 30, 2019 | |
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 (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 exploration program balanced between proven basin infrastructure-led exploration (Equatorial Guinea and U.S. Gulf of Mexico), emerging basins (Mauritania, Senegal and Suriname) and frontier basins (Cote d'Ivoire, Namibia and Sao Tome and Principe). 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 | 6 Months Ended |
Jun. 30, 2019 | |
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 Securities and Exchange Commission (“SEC”) for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by Generally Accepted Accounting Principles in the United States of America (“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, 2018 , included in our annual report on Form 10-K. Reclassifications Certain prior period amounts have been reclassified to conform with the current presentation. Such reclassifications had no significant impact on our reported net income (loss) , current assets, total assets, current liabilities, total liabilities, stockholders’ equity or cash flows. Additionally, as a result of our outstanding shares in KTIPI being transferred for an undivided interest in the Ceiba Field and Okume Complex (effective January 1, 2019), our previously reported equity method investment in KTIPI has been allocated to the respective assets and liabilities on a relative fair value basis. See Note 7 — Equity Method Investments for additional information. Cash, Cash Equivalents and Restricted Cash June 30, December 31, (In thousands) Cash and cash equivalents $ 176,908 $ 173,515 Restricted cash - current 327 4,527 Restricted cash - long-term 7,574 7,574 Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 184,809 $ 185,616 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. In accordance with certain of our petroleum contracts, we have posted letters of credit related to performance guarantees for our minimum work obligations. 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 $98.2 million and $83.4 million of materials and supplies and $10.3 million and $1.4 million of hydrocarbons as of June 30, 2019 and December 31, 2018 , 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. Leases (Policy applicable beginning January 1, 2019) In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842).” ASU 2016-02 was issued to increase transparency and comparability across organizations by recognizing substantially all leases on the balance sheet through the concept of right-of-use lease assets and liabilities. Under prior accounting guidance, lessees did not recognize lease assets or liabilities for leases classified as operating leases. The ASU was effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years with early adoption permitted. In July 2018, the FASB issued ASU 2018-11, which added a transition option permitting entities to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the consolidated financial statements. Under this transition option, comparative reporting would not be required, and the provisions of the standard would be applied prospectively to leases in effect at the date of adoption. The Company adopted the guidance prospectively during the first quarter of 2019. As part of our adoption, we elected not to reassess historical lease classification, recognize short-term leases on our balance sheet, nor separate lease and non-lease components for our real estate leases. The adoption and implementation of this ASU resulted in a $21.7 million increase in assets and liabilities related to our leasing activities, which primarily consists of office leases. Our adoption of ASU 2016-02 did not impact retained earnings or other components of equity as of December 31, 2018. We account for leases in accordance with ASC Topic 842, Leases, (“ASC 842”). We determine if an arrangement is a lease at contract inception. A lease exists when a contract conveys to the customer the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. The definition of a lease embodies two conditions: (1) there is an identified asset in the contract that is land or a depreciable asset (i.e., property, plant, and equipment), and (2) the customer has the right to control the use of the identified asset. In the normal course of business, the Company enters into various lease agreements for real estate and equipment related to its exploration, development and production activities that are currently accounted for as operating leases. Operating Leases are included in Other assets, Accrued liabilities, and Other long-term liabilities on our Consolidated Balance Sheets. The lease liabilities are initially and subsequently measured at the present value of the unpaid lease payments at the lease commencement date. Key estimates and judgments include how we determined: (1) the discount rate we use to discount the unpaid lease payments to present value; (2) lease term; and (3) lease payments. 1. ASC 842 requires a lessee to discount its unpaid lease payments using the interest rate implicit in the lease or, if that rate cannot be readily determined, its incremental borrowing rate. As most of our leases where we are the lessee do not provide an implicit rate, we use our incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. Our incremental borrowing rate for a lease is the rate of interest we would have to pay on a collateralized basis to borrow an amount equal to the lease payments under similar terms. 2. The lease term for all of our leases includes the non-cancellable period of the lease plus any additional periods covered by either an option to extend (or not to terminate) the lease that we are reasonably certain to exercise, or an option to extend (or not to terminate) the lease controlled by the lessor. 3. Lease payments included in the measurement of the lease asset or liability comprise the following: fixed payments (including in-substance fixed payments), variable payments that depend on index or rate, and the exercise price of a lessee option to purchase the underlying asset if we are reasonably certain to exercise. Amounts expected to be payable under residual value guarantee are also lease payments included in the measurement of the lease liability. The Right-of-use ("ROU") asset is initially measured at cost, which comprises the initial amount of the lease liability adjusted for lease payments made at or before the lease commencement date, plus any initial direct costs incurred less any lease incentives received. For operating leases, the ROU asset is subsequently measured throughout the lease term at the carrying amount of the lease liability, plus initial direct costs, plus (minus) any prepaid (accrued) lease payments, less the unamortized balance of lease incentives received. Lease expense for lease payments is recognized on a straight-line basis over the lease term. We monitor for events or changes in circumstances that require a reassessment of a lease. When a reassessment results in the re-measurement of a lease liability, a corresponding adjustment is made to the carrying amount of the corresponding ROU asset unless doing so would reduce the carrying amount of the ROU asset to an amount less than zero. In that case, the amount of the adjustment that would result in a negative ROU asset balance is recorded in profit or loss. We have lease agreements which include lease and non-lease components. We have elected to combine lease and non-lease components for all lease contracts. We have elected not to recognize ROU assets and lease liabilities for all short-term leases that have a lease term of 12 months or less. We recognize the lease payments associated with our short-term leases as an expense on a straight-line basis over the lease term. We adopted ASU 2016-02 using a modified retrospective transition approach as of the effective date as permitted by the amendments in ASU 2018-11, which provides an alternative modified retrospective transition method. As a result, we were not required to adjust our comparative period financial information for effects of the standard or make the new required lease disclosures for periods before the date of adoption (i.e. January 1, 2019). We have elected to adopt the package of transition practical expedients and, therefore, have not reassessed (1) whether existing or expired contracts contain a lease, (2) lease classification for existing or expired leases or (3) the accounting for initial direct costs that were previously capitalized. We did not elect the practical expedient to use hindsight for leases existing at the adoption date. Further, we do not expect the amendments in ASU 2018-01: Land Easement Practical Expedient to have an effect on us because we do not enter into land easement arrangements. Revenue Recognition We recognize revenues on the volumes of hydrocarbons sold to a purchaser. The volumes sold may be more or less than the volumes to which we are entitled based on our ownership interest in the property. These differences result in a condition known in the industry as a production imbalance. A receivable or liability is recognized only to the extent that we have an imbalance on a specific property greater than the expected remaining proved reserves on such property. As of June 30, 2019 and December 31, 2018 , we had no oil and gas imbalances recorded in our consolidated financial statements. Our oil and gas revenues are recognized when hydrocarbons have been sold to a purchaser at a fixed or determinable price, title has transferred and collection is probable. Certain revenues are based on 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 June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In thousands) Revenues from contract with customer - Equatorial Guinea $ 63,165 $ — $ 152,279 $ — Revenues from contract with customer - Ghana 209,469 213,841 328,800 341,878 Revenues from contract with customers - U.S. Gulf of Mexico 129,364 — 214,431 — Provisional oil sales contracts (6,065 ) 1,350 (2,787 ) 509 Oil and gas revenue $ 395,933 $ 215,191 $ 692,723 $ 342,387 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 readily 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 international operations. For our U.S. Gulf of Mexico operations, crude oil and natural gas are transported to customers using third-party pipelines. For the three and six months ended June 30, 2019 , revenue from Phillips 66 Company made up approximately 22% of our total consolidated revenue and was included in our U.S. Gulf of Mexico segment. Recent Accounting Standards |
Acquisitions and Divestitures
Acquisitions and Divestitures | 6 Months Ended |
Jun. 30, 2019 | |
Business Combinations [Abstract] | |
Acquisitions and Divestitures | Acquisitions and Divestitures 2019 Transactions During the first quarter of 2019, we entered into a petroleum contract covering offshore Marine XXI block with the Republic of the Congo, subject to customary governmental approvals. Upon approval, we will hold an 85% participating interest and are the operator. The Congolese national oil company, SNPC, has a 15% carried participating interest during the exploration period. Should a commercial discovery be made, SNPC's 15% carried interest will convert to a participating interest of at least 15% . The petroleum contract covers approximately 2,350 square kilometers, with a first exploration period of four years and includes a work program to acquire and interpret 2,200 square kilometers of 3D seismic. There are two optional exploration phases, each for a period of three years , which are subject to additional work program commitments. During the first quarter of 2019, Kosmos farmed-in to 18 BP-owned blocks in the Garden Banks area of the deepwater U.S. Gulf of Mexico. In addition, Kosmos can earn an interest in three BP blocks in other areas of the deepwater U.S. Gulf of Mexico. Kosmos is the designated operator and plans to commence drilling operations on the first well in Garden Banks block 492, the Resolution prospect, in late 2019. During the first quarter of 2019, Kosmos executed a farm-in agreement with Chevron covering the right to earn an interest in a deepwater block in the U.S. Gulf of Mexico. Kosmos has been designated operator and plans to commence drilling operations in 2019. During the first quarter of 2019, Kosmos was one of the most active participants in the U.S. Gulf of Mexico Federal Lease Sale 252 and was ultimately awarded nine deepwater blocks. During the first quarter of 2019, we executed a farm-in agreement with OK Energy to acquire a 45% non-operated interest in the Northern Cape Ultra Deep block offshore the Republic of South Africa, subject to customary governmental approvals. The petroleum contract covers approximately 6,930 square kilometers at water depths ranging from 2,500 to 3,100 meters and has an initial exploration phase of two years In May of 2019, we entered into a farm-out agreement with Shell Sao Tome and Principe B.V. to farm-out a 20% participating interest in Block 6 and a 30% participating interest in Block 11, offshore Sao Tome and Principe, subject to customary governmental approvals. 2018 Transactions In March 2018, as part of our alliance with BP, we entered into petroleum contracts covering Blocks 10 and 13 with the Democratic Republic of Sao Tome and Principe and BP. We have a 35% participating interest in the blocks and the operator, BP, holds a 50% participating interest. The national petroleum agency, ANP-STP has a 15% carried interest in the blocks through exploration. The petroleum contracts cover approximately 13,600 square kilometers, with a first exploration period of four years from the effective date (March 2018). The exploration periods can be extended an additional four years at our election subject to fulfilling specific work obligations. The first exploration period work programs include a 13,500 square kilometer 3D seismic acquisition across the two blocks. In June 2018, we completed a farm-in agreement with a subsidiary of Ophir for Block EG-24, offshore Equatorial Guinea, whereby we acquired a 40% non-operated participating interest. As part of the agreement, we reimbursed a portion of Ophir's previously incurred exploration costs and agreed to carry Ophir's share of the future costs. The petroleum contract covers approximately 3,500 square kilometers, with a first exploration period of three years from the effective date (March 2018), which can be extended up to four additional years at our election subject to fulfilling specific work obligations. The first exploration period work program includes a 3,000 square kilometer 3D seismic acquisition requirement which was completed in November 2018. In March 2019, we acquired Ophir's remaining interest in the block, which resulted in Kosmos owning an 80% participating interest in Block EG-24 and we are the operator. The Equatorial Guinean national oil company, GEPetrol, has a 20% carried participating interest during the exploration period. Should a commercial discovery be made, GEPetrol's 20% carried participating interest will convert to a 20% participating interest. In August 2018, we closed a farm-out agreement with Trident, whereby they acquired a 40% participating interest in blocks EG-21, S, and W, offshore Equatorial Guinea, resulting in a $7.7 million gain. After giving effect to the farm-out agreement, we hold a 40% participating interest and are the operator in all three blocks. The Equatorial Guinean national oil company, GEPetrol, has a 20% carried participating interest during the exploration period. Should a commercial discovery be made, GEPetrol's 20% carried participating interest will convert to a 20% participating interest. The petroleum contracts cover approximately 6,000 square kilometers, with a first exploration period of five years from the effective date (March 2018). The first exploration period consists of two sub-periods of three and two years , respectively. The first exploration sub-period work program includes a 6,000 square kilometer 3D seismic acquisition requirement across the three blocks, which was completed in 2018. In September 2018, we completed the acquisition of DGE, a deepwater company operating in the U.S. Gulf of Mexico, from First Reserve Corporation and other shareholders for a total consideration of $1.275 billion , comprised of $952.6 million in cash, $307.9 million in Kosmos common stock, and $14.9 million of transaction related costs. We funded the cash portion of the purchase price using cash on hand and drawings under our existing credit facilities. The DGE acquisition was accounted as an asset acquisition. In October 2018, Kosmos entered into a strategic exploration alliance with Shell to jointly explore in Southern West Africa. Initially the alliance will focus on Namibia where Kosmos has completed a farm-in to Shell's acreage in PEL 39, and Sao Tome and Principe where, in May 2019, we have entered into a farm-out agreement for Shell to take an interest in a portion of Kosmos’ acreage in Blocks 6 and 11. As part of the alliance, the two |
Joint Interest Billings and Rel
Joint Interest Billings and Related Party Receivables | 6 Months Ended |
Jun. 30, 2019 | |
Joint Interest Billings | |
Joint Interest Billings and Related Party 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 face of the consolidated balance sheets as current and long-term receivables based on when collection is expected to occur. In 2014, GNPC notified us and our block partners of its request for the contractor group to pay GNPC’s 5% share of the Tweneboa, Enyenra and Ntomme (“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 June 30, 2019 and December 31, 2018 , the current portions of the joint interest billing receivables due from GNPC for the TEN fields development costs were $14.0 million and $14.0 million , respectively, and the long-term portions were $22.2 million and $14.0 million , respectively. Related Party Receivables The Company's related party receivables consists primarily of receivables from Trident which, until January 2019, we shared a 50% interest in KTIPI. As of December 31, 2018 the balance due from Trident consists of $ 5.6 million related to joint interest billings for the exploration blocks and Kosmos' support of KTIPI operations. Subsequent to the unwind of KTIPI, Trident is no longer considered a related party. 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 for Greater Tortue Ahmeyim Phase 1, currently projected in the first half of 2022. Kosmos’ total 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 June 30, 2019 , the balance due from the national oil companies was $6.0 million , which is classified as Long-term receivables in our consolidated balance sheets. |
Property and Equipment
Property and Equipment | 6 Months Ended |
Jun. 30, 2019 | |
Property, Plant and Equipment [Abstract] | |
Property and Equipment | Property and Equipment Property and equipment is stated at cost and consisted of the following: June 30, December 31, (In thousands) Oil and gas properties: Proved properties $ 4,773,104 $ 4,236,489 Unproved properties 865,529 759,472 Total oil and gas properties 5,638,633 4,995,961 Accumulated depletion (1,806,108 ) (1,551,097 ) Oil and gas properties, net 3,832,525 3,444,864 Other property 55,107 51,987 Accumulated depreciation (40,059 ) (37,150 ) Other property, net 15,048 14,837 Property and equipment, net $ 3,847,573 $ 3,459,701 We recorded depletion expense of $144.0 million and $71.3 million for the three months ended June 30, 2019 and 2018 , respectively, and $255.0 million and $122.9 million for the six months ended June 30, 2019 and 2018 |
Suspended Well Costs
Suspended Well Costs | 6 Months Ended |
Jun. 30, 2019 | |
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 six months ended June 30, 2019 . The table excludes $1.4 million in costs that were capitalized and subsequently expensed during the same period. June 30, (In thousands) Beginning balance $ 367,665 Additions to capitalized exploratory well costs pending the determination of proved reserves 15,439 Reclassification due to determination of proved reserves (10,711 ) Capitalized exploratory well costs charged to expense — Ending balance $ 372,393 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: June 30, 2019 December 31, 2018 (In thousands, except well counts) Exploratory well costs capitalized for a period of one year or less $ — $ — Exploratory well costs capitalized for a period of one to two years 70,486 299,253 Exploratory well costs capitalized for a period of three years or greater 301,907 68,412 Ending balance $ 372,393 $ 367,665 Number of projects that have exploratory well costs that have been capitalized for a period greater than one year 3 3 As of June 30, 2019 , the projects with exploratory well costs capitalized for more than one year since the completion of drilling are related to the Greater Tortue Ahmeyim Unit, which crosses the Mauritania and Senegal maritime border, the Bir Allah 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. Greater Tortue Ahmeyim Unit — In May 2015, we completed the Tortue-1 exploration well in Block C8 offshore Mauritania, which encountered hydrocarbon pay. Three additional wells have been drilled in the Greater Tortue Discovery area, Ahmeyim-2 in Mauritania and Guembeul-1 and Greater Tortue Ahmeyim-1 in Senegal. We completed a drill stem test on the Tortue‑1 well in August 2017, which confirmed the production capabilities of the Greater Tortue Ahmeyim Unit. In December 2018, we made a final investment decision to develop Phase 1 of the Greater Tortue Ahmeyim Unit. Bir Allah Discovery — In November 2015, we completed the Marsouin-1 exploration well (renamed Bir Allah) 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. An exploration well is planned for the nearby Orca prospect during 2019, which will help delineate the available resource in the region to refine the development plans for the Bir Allah discovery. |
Equity Method Investments
Equity Method Investments | 6 Months Ended |
Jun. 30, 2019 | |
Equity Method Investments and Joint Ventures [Abstract] | |
Equity Method Investments | Equity Method Investments Equatorial Guinea As part of our acquisition of KTIPI in 2017, a corporate joint venture entity in which we owned a 50% interest, we acquired an indirect participating interest in Block G offshore Equatorial Guinea. The objective of this transaction was to acquire the Ceiba Field and Okume Complex with the intent to optimize production and increase reserves. Below is a summary of financial information for KTIPI presented on a 100% basis for 2018 and the results of operations for 2019 are presented based on our direct 40.4% ownership in the Ceiba Field and Okume Complex. December 31, 2018 (In thousands) Assets Total current assets $ 149,950 Property and equipment, net 271,627 Other assets 21 Total assets $ 421,598 Liabilities and stockholders' equity Total current liabilities $ 226,311 Total long-term liabilities 536,178 Shareholders' equity: Total shareholders' equity (340,891 ) Total liabilities and shareholders' equity $ 421,598 Three Months Ended Six Months Ended (In thousands) Revenues and other income: Oil and gas revenue $ 138,395 $ 384,749 Other income (170 ) 117 Total revenues and other income 138,225 384,866 Costs and expenses: Oil and gas production 23,332 75,033 Depletion, depreciation and amortization 21,881 75,951 Other expenses, net (73 ) (152 ) Total costs and expenses 45,140 150,832 Income before income taxes 93,085 234,034 Income tax expense 33,620 83,251 Net income $ 59,465 $ 150,783 Kosmos' share of net income $ 29,733 $ 75,392 Basis difference amortization(1) 13,633 40,596 Equity in earnings - KTIPI $ 16,100 $ 34,796 ______________________________________ (1) The basis difference, which is associated with oil and gas properties and subject to amortization, has been allocated to the Ceiba Field and Okume Complex. We amortize the basis difference using the unit-of-production method. With an effective date of January 1, 2019, our outstanding shares in KTIPI were transferred to Trident in exchange for a 40.375% undivided participating interest in the Ceiba Field and Okume Complex. As a result, our interest in the Ceiba Field and Okume Complex is accounted for under the proportionate consolidation method of accounting going forward. This transaction was accounted for as an asset acquisition. The carrying value of the equity method investment was allocated to the undivided interest acquired and net working capital based on the estimated relative fair value of the acquired assets. The estimated fair value measurements of oil and gas assets acquired and liabilities assumed are based on inputs that are not observable in the market and therefore represent Level 3 inputs. The fair value of oil and gas properties and asset retirement obligations were measured using the discounted cash flow technique of valuation. Significant inputs to the valuation of oil and gas properties include estimates of: (i) reserves, (ii) future operating and development costs, (iii) future commodity prices, (iv) future plugging and abandonment costs, (v) estimated future cash flows, and (vi) a market-based weighted average cost of capital rate. These fair value estimates were used to allocate the carrying value of the equity method investment to our balance sheet on a relative fair value basis. Carrying Value Allocation (in thousands) Assets acquired: Proved oil and gas properties $ 372,144 Unproved oil and gas properties 103,909 Prepaids and other 7,273 Total assets acquired $ 483,326 Liabilities assumed: Asset retirement obligations $ 114,395 Deferred tax liabilities 247,636 Accrued liabilities and other 69,399 Total liabilities assumed $ 431,430 Carrying value: Equity method investment carrying value at December 31, 2018 $ 51,896 |
Debt
Debt | 6 Months Ended |
Jun. 30, 2019 | |
Debt Disclosure [Abstract] | |
Debt | Debt June 30, December 31, (In thousands) Outstanding debt principal balances: Facility $ 1,500,000 $ 1,325,000 Corporate Revolver 25,000 325,000 Senior Notes 650,000 — Senior Secured Notes — 525,000 Total 2,175,000 2,175,000 Unamortized deferred financing costs and discounts(1) (45,660 ) (54,453 ) Long-term debt, net $ 2,129,340 $ 2,120,547 __________________________________ (1) Includes $35.9 million and $40.5 million of unamortized deferred financing costs related to the Facility as of June 30, 2019 and December 31, 2018 , respectively; $9.7 million of unamortized deferred financing costs and discounts related to the Senior Notes as of June 30, 2019 ; and $14.0 million of unamortized deferred financing costs and discounts related to the Senior Secured Notes as of December 31, 2018 , respectively. Facility In February 2018, the Company amended and restated the Facility with a total commitment of $1.5 billion from a number of financial institutions with additional commitments up to $0.5 billion being available if the existing financial institutions increase their commitments or if commitments from new financial institutions are added. The borrowing base calculation includes value related to the Jubilee, TEN, Ceiba and Okume fields. In March 2019, following the lender's annual redetermination, the available borrowing base under our Facility was limited to the Facility size of $1.7 billion . The Facility supports our oil and gas exploration, appraisal and development programs and corporate activities. As part of the debt refinancing in February 2018, the repayment of borrowings under the existing facility attributable to financial institutions that did not participate in the amended Facility was accounted for as an extinguishment of debt, and $4.1 million of existing unamortized debt issuance costs and deferred interest attributable to those participants was expensed in interest and other financing costs, net in the first quarter of 2018. As of June 30, 2019 , we have $35.9 million of unamortized issuance costs related to the Facility, which will be amortized over the remaining term of the Facility. As of June 30, 2019 , borrowings under the Facility totaled $1.5 billion and the undrawn availability under the Facility was $100.0 million . The commitments were reduced by $100 million to $1.6 billion following the Senior Notes issuance in April 2019. 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 June 30, 2019 , we had no letters of credit issued under the Facility. We were in compliance with the financial covenants contained in the Facility as of March 31, 2019 (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 100 basis points 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 June 30, 2019 , borrowings under the Corporate Revolver totaled $25.0 million and the undrawn availability under the Corporate Revolver was $375.0 million . As of June 30, 2019 , we have $7.6 million of net deferred financing costs related to the Corporate Revolver, which will be amortized over its remaining term. We were in compliance with the financial covenants contained in the Corporate Revolver as of March 31, 2019 (the most recent assessment date). The Corporate Revolver contains customary cross default provisions. Revolving Letter of Credit Facility Our revolving letter of credit facility agreement (“LC Facility”) expired in July 2019 . In December 2018, the LC Facility size was voluntarily reduced to $20.0 million based on the expiration of several large outstanding letters of credit. As of June 30, 2019 , there were six outstanding letters of credit totaling $9.4 million under the LC Facility, which will remain outstanding until the respective letters of credit expire. The LC Facility contains customary cross default provisions. In June 2019, we issued a $17.0 million letter of credit under a new letter of credit arrangement, which does not currently require cash collateral. 7.875% Senior Secured Notes due 2021 During August 2014, the Company issued $300.0 million of 7.875% Senior Secured Notes due 2021 (the "Senior Secured Notes") and received net proceeds of approximately $292.5 million after deducting discounts, commissions and debt issue costs. The Company used the net proceeds to repay a portion of the outstanding indebtedness under the Facility and for general corporate purposes. During April 2015, we issued an additional $225.0 million of Senior Secured Notes and received net proceeds of $206.8 million after deducting discounts, commissions and other expenses. We used the net proceeds to repay a portion of the outstanding indebtedness under the Facility and for general corporate purposes. The additional $225.0 million of Senior Secured Notes had identical terms to the initial $300.0 million of Senior Secured Notes, other than the date of issue, the initial price, the first interest payment date and the first date from which interest accrued. In April 2019, all of the Senior Secured Notes were redeemed for $543.8 million , including accrued interest and the early redemption premium. The redemption resulted in a $22.9 million loss on extinguishment of debt, which is included in Interest and other financing costs, net on the Consolidated Statement of Operations during the second quarter. 7.125% Senior Notes due 2026 In April 2019, the Company issued $650.0 million of 7.125% Senior Notes (the "Senior Notes") and received net proceeds of approximately $640.0 million after deducting commissions and other expenses. We used the net proceeds to redeem all of the 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. We will pay interest in arrears on the Senior Notes 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. At any time prior to April 4, 2022, and subject to certain conditions, the Company may, on one or more occasions, redeem up to 40% of the original principal amount of the Senior Notes with an amount not to exceed the net cash proceeds of certain equity offerings at a redemption price of 107.1% of the outstanding principal amount of the Senior Notes, together with accrued and unpaid interest and premium, if any, to, but excluding, the date of redemption. Additionally, at any time prior to April 4, 2022 the Company may, on any one or more occasions, redeem all or a part of the Senior Notes at a redemption price equal to 100% , plus any accrued and unpaid interest, and plus a “make-whole” premium. On or after April 4, 2022, the Company may redeem all or a part of the Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest: Year Percentage On or after April 4, 2022, but before April 4, 2023 103.6 % On or after April 4, 2023, but before April 4, 2024 101.8 % On or after April 4, 2024 and thereafter 100.0 % We may also redeem the Senior Notes in whole, but not in part, at any time if changes in tax laws impose certain withholding taxes on amounts payable on the Senior Notes at a price equal to the principal amount of the Senior Notes plus accrued interest and additional amounts, if any, as may be necessary so that the net amount received by each holder after any withholding or deduction on payments of the Senior Notes will not be less than the amount such holder would have received if such taxes had not been withheld or deducted. Upon the occurrence of a change of control triggering event as defined under the Senior Notes indenture, the Company will be required to make an offer to repurchase the Senior Notes at a repurchase price equal to 101% of the principal amount, plus accrued and unpaid interest to, but excluding, the date of repurchase. If we sell assets, under certain circumstances outlined in the Senior Notes indenture, we will be required to use the net proceeds to make an offer to purchase the Senior Notes at an offer price in cash in an amount equal to 100% of the principal amount of the Senior Notes, plus accrued and unpaid interest to, but excluding, the repurchase date. The Senior Notes indenture restricts our ability and the ability of our restricted subsidiaries to, among other things: incur or guarantee additional indebtedness, create liens, pay dividends or make distributions in respect of capital stock, purchase or redeem capital stock, make investments or certain other restricted payments, sell assets, enter into agreements that restrict the ability of our subsidiaries to make dividends or other payments to us, enter into transactions with affiliates, or effect certain consolidations, mergers or amalgamations. These covenants are subject to a number of important qualifications and exceptions. Certain of these covenants will be terminated if the Senior Notes are assigned an investment grade rating by both Standard & Poor’s Rating Services and Fitch Ratings Inc. and no default or event of default has occurred and is continuing. At June 30, 2019 , the estimated repayments of debt during the five fiscal year periods and thereafter are as follows: Payments Due by Year Total 2019(2) 2020 2021 2022 2023 Thereafter (In thousands) Principal debt repayments(1) $ 2,175,000 $ — $ — $ 274,800 $ 309,200 $ 271,600 $ 1,319,400 __________________________________ (1) Includes the scheduled principal maturities for the $650.0 million aggregate principal amount of Senior Notes issued in April 2019, borrowings under the Facility and borrowings under the Corporate Revolver. The scheduled maturities of debt related to the Facility are based on, as of June 30, 2019 , 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 July 1, 2019 through December 31, 2019 . Interest and other financing costs, net Interest and other financing costs, net incurred during the periods is comprised of the following: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In thousands) Interest expense $ 38,450 $ 24,912 $ 76,622 $ 49,804 Amortization—deferred financing costs 2,302 2,283 4,689 4,723 Loss on extinguishment of debt 24,794 — 24,794 4,056 Capitalized interest (7,002 ) (9,292 ) (14,253 ) (14,112 ) Deferred interest 433 166 1,270 (1,090 ) Interest income (591 ) (843 ) (1,243 ) (1,791 ) Other, net 1,417 1,644 2,965 2,974 Interest and other financing costs, net $ 59,803 $ 18,870 $ 94,844 $ 44,564 |
Derivative Financial Instrument
Derivative Financial Instruments | 6 Months Ended |
Jun. 30, 2019 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivative Financial Instruments | Derivative Financial Instruments We use financial derivative contracts to manage exposures to commodity price and interest rate fluctuations. We do not hold or issue derivative financial instruments for trading purposes. We manage market and counterparty credit risk in accordance with our policies and guidelines. In accordance with these policies and guidelines, our management determines the appropriate timing and extent of derivative transactions. We have included an estimate of non-performance risk in the fair value measurement of our derivative contracts as required by ASC 820 — Fair Value Measurements and Disclosures. Oil Derivative Contracts The following table sets forth the volumes in barrels underlying the Company’s outstanding oil derivative contracts and the weighted average prices per Bbl for those contracts as of June 30, 2019 . Volumes and weighted average prices are net of any offsetting derivative contracts entered into. Weighted Average Price per Bbl Net Deferred Premium Term Type of Contract Index MBbl Payable/(Receivable) Swap Sold Put Floor Ceiling 2019: Jul — Dec Three-way collars Dated Brent 5,256 $ 1.17 $ — $ 43.81 $ 53.33 $ 73.57 Jul — Dec Sold calls(1) Dated Brent 460 — — — — 80.00 Jul — Dec Swaps NYMEX WTI 730 — 52.01 — — — Jul — Dec Collars Argus LLS 500 — — — 60.00 88.75 2020: Jan — Dec Three-way collars Dated Brent 6,000 $ 0.45 $ — $ 45.00 $ 57.50 $ 80.18 Jan — Dec Sold calls(1)(2) Dated Brent 8,000 $ 1.17 $ — $ — $ — $ 85.00 __________________________________ (1) Represents call option contracts sold to counterparties to enhance other derivative positions. (2) Deferred premium payable to be paid July 1, 2019 — December 31, 2019. In July 2019, we entered into put option contracts for 2.0 MMBbl from January 2020 through December 2020 with a floor price of $60.00 per barrel and a sold put price of $50.00 per barrel. In addition, we sold 1.0 MMBbl of calls from January 2021 through December 2021 with a strike price of $75.00 per barrel. The contracts are indexed to Dated Brent prices. The following tables disclose the Company’s derivative instruments as of June 30, 2019 and December 31, 2018 , and gain/(loss) from derivatives during the three and six months ended June 30, 2019 and 2018 , respectively: Estimated Fair Value Asset (Liability) Type of Contract Balance Sheet Location June 30, December 31, (In thousands) Derivatives not designated as hedging instruments: Derivative assets: Commodity(1) Derivatives assets—current $ 11,511 $ 38,785 Commodity(2) Derivatives assets—long-term 7,264 14,312 Derivative liabilities: Commodity(3) Derivatives liabilities—current (26,897 ) (12,172 ) Commodity(4) Derivatives liabilities—long-term (5,776 ) (10,181 ) Total derivatives not designated as hedging instruments $ (13,898 ) $ 30,744 __________________________________ (1) Includes zero and $0.4 million as of June 30, 2019 and December 31, 2018 , respectively which represents our provisional oil sales contract. Also, includes net deferred premiums payable of $4.0 million and $1.6 million related to commodity derivative contracts as of June 30, 2019 and December 31, 2018 , respectively. (2) Includes net deferred premiums payable of $0.8 million and $1.3 million related to commodity derivative contracts as of June 30, 2019 and December 31, 2018 , respectively. (3) Includes net deferred premiums payable of $7.8 million and $18.0 million related to commodity derivative contracts as of June 30, 2019 and December 31, 2018 , respectively. (4) Includes net deferred premiums payable of $0.8 million and $0.5 million related to commodity derivative contracts as of June 30, 2019 and December 31, 2018 , respectively. Amount of Gain/(Loss) Amount of Gain/(Loss) Three Months Ended Six Months Ended June 30, June 30, Type of Contract Location of Gain/(Loss) 2019 2018 2019 2018 (In thousands) Derivatives not designated as hedging instruments: Commodity(1) Oil and gas revenue $ (6,064 ) $ 1,350 $ (2,786 ) $ 509 Commodity Derivatives, net 14,185 (140,272 ) (62,900 ) (178,750 ) Interest rate Interest expense — 98 — 451 Total derivatives not designated as hedging instruments $ 8,121 $ (138,824 ) $ (65,686 ) $ (177,790 ) __________________________________ (1) Amounts represent the change in fair value of our provisional oil sales contracts. 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 June 30, 2019 and December 31, 2018 , 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 | 6 Months Ended |
Jun. 30, 2019 | |
Fair Value Disclosures [Abstract] | |
Fair Value Measurements | Fair Value Measurements In accordance with ASC Topic 820 — Fair Value Measurements and Disclosures, 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 June 30, 2019 and December 31, 2018 , 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) June 30, 2019 Assets: Commodity derivatives $ — $ 18,775 $ — $ 18,775 Liabilities: Commodity derivatives — (32,673 ) — (32,673 ) Total $ — $ (13,898 ) $ — $ (13,898 ) December 31, 2018 Assets: Commodity derivatives $ — $ 53,097 $ — $ 53,097 Liabilities: Commodity derivatives — (22,353 ) — (22,353 ) Total $ — $ 30,744 $ — $ 30,744 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 respective index. The volatility estimate was provided by certain independent brokers who are active in buying and selling oil options and was corroborated by market-quoted volatility factors. The deferred premium is included in the fair market value of the commodity derivatives. See Note 9 — Derivative Financial Instruments for additional information regarding the Company’s derivative instruments. Provisional Oil Sales The value attributable to provisional oil sales 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 June 30, 2019 and December 31, 2018 : June 30, 2019 December 31, 2018 Carrying Value Fair Value Carrying Value Fair Value (In thousands) Senior Notes $ 642,089 $ 656,422 $ — $ — Senior Secured Notes — — 511,873 525,026 Corporate Revolver 25,000 25,000 325,000 325,000 Facility 1,500,000 1,500,000 1,325,000 1,325,000 Total $ 2,167,089 $ 2,181,422 $ 2,161,873 $ 2,175,026 The carrying value of our Senior Notes and Senior Secured Notes represents the principal amounts outstanding less unamortized discounts. The fair value of our Senior Notes and Senior Secured Notes is based on quoted market prices, which results in a Level 1 fair value measurement. The carrying value of the Facility approximates fair value since it is subject to short-term floating interest rates that approximate the rates available to us for those periods. |
Equity-based Compensation
Equity-based Compensation | 6 Months Ended |
Jun. 30, 2019 | |
Disclosure of Compensation Related Costs, Share-based Payments [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 Long Term Incentive Plan (“LTIP”) awards. We recorded compensation expense from awards granted under our LTIP of $9.5 million and $9.1 million during the three months ended June 30, 2019 and 2018 , respectively, and $17.9 million and $17.1 million during the six months ended June 30, 2019 and 2018 , respectively. The total tax benefit for the three months ended was $1.5 million and $1.8 million , respectively, and $2.8 million and $3.4 million during the six months ended June 30, 2019 and 2018 , respectively. Additionally, we recorded a net tax shortfall (windfall) related to equity-based compensation of nil and $0.4 million for the three months ended June 30, 2019 and 2018 , respectively, and $1.2 million and $(0.3) million during the six months ended June 30, 2019 and 2018 , respectively. The fair value of awards vested during the three months ended June 30, 2019 and 2018 was approximately $0.8 million and $25.4 million , respectively, and $14.0 million and $82.0 million during the six months ended June 30, 2019 and 2018 , 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 June 30, 2019 : 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, 2018 4,115 $ 6.42 6,716 $ 9.02 Granted(1) 2,965 4.91 3,109 6.02 Forfeited(1) (85 ) 6.33 (285 ) 9.92 Vested (1,909 ) 5.87 (1,271 ) 6.36 Outstanding at June 30, 2019 5,086 5.74 8,269 8.39 __________________________________ (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 June 30, 2019 , total equity-based compensation to be recognized on unvested restricted stock units is $47.0 million over a weighted average period of 2.14 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 June 30, 2019 , the Company had approximately 9.9 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 $4.83 to $12.96 per award. The Monte Carlo simulation model utilizes multiple input variables that determine the probability of satisfying the market condition stipulated in the award grant and calculates the fair value of the award. The expected volatility utilized in the model was estimated using our historical volatility and the historical volatilities of our peer companies and ranged from 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% . |
Income Taxes
Income Taxes | 6 Months Ended |
Jun. 30, 2019 | |
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 company was not subject to taxation at the parent company level for the three and six months ended June 30, 2018. For 2019, the income tax provision consists of United States, Ghanaian, and Equatorial Guinean income taxes, and Texas margin taxes. For 2018, results from operations in Equatorial Guinea are reported, net of tax, as Gain on equity method investments, net in our Consolidated Statement of Operations, and were not included in our 2018 income tax provision. 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 countries and have full valuation allowances against the corresponding net deferred tax assets. Income (loss) before income taxes is composed of the following: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In thousands) United States $ (18,499 ) $ 1,682 $ (74,240 ) $ 3,315 Bermuda — (15,890 ) — (31,961 ) Foreign—other 67,938 (134,410 ) 62,099 (194,546 ) Income (loss) before income taxes $ 49,439 $ (148,618 ) $ (12,141 ) $ (223,192 ) For the three months ended , June 30, 2019 , and 2018 , our effective tax rate was 66% and 31% , respectively. For the six months ended , June 30, 2019 , and 2018 , our effective tax rate was 197% and 31% , respectively. For the three and six months ended June 30, 2019 our overall effective tax rate was 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, 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 expenses or losses. For the three and six months ended June 30, 2018, our overall effective tax rate was impacted by non-deductible and non-taxable items associated with our U.S. and Ghanaian 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 expenses or losses. 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 United States, for federal income tax return years 2015 through 2018, in Ghana to federal income tax return examinations for tax years 2014 through 2018, and in Equatorial Guinea to federal income tax return examination for 2018. As of June 30, 2019 , 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 | 6 Months Ended |
Jun. 30, 2019 | |
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 Six Months Ended June 30, June 30, 2019 2018 2019 2018 (In thousands, except per share data) Numerator: Net income (loss) allocable to common stockholders $ 16,837 $ (103,273 ) $ (36,069 ) $ (153,499 ) Denominator: Weighted average number of shares outstanding: Basic 401,323 396,826 401,244 396,218 Restricted stock units(1) 6,907 — — — Diluted 408,230 396,826 401,244 396,218 Net income (loss) per share: Basic $ 0.04 $ (0.26 ) $ (0.09 ) $ (0.39 ) Diluted $ 0.04 $ (0.26 ) $ (0.09 ) $ (0.39 ) __________________________________ (1) We excluded outstanding restricted stock awards and units of 1.1 million and 11.4 million for the three months ended June 30, 2019 and 2018, respectively, and 12.9 million and 11.9 million for the six months ended June 30, 2019 and 2018 , 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 | 6 Months Ended |
Jun. 30, 2019 | |
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 each of Sao Tome and Principe and Namibia and two exploration wells in each of Mauritania and Senegal. In Mauritania and Senegal, BP is obligated to fund our share of the cost of the exploration wells, subject to the remaining exploration and appraisal carry covering our Mauritania and Senegal blocks. In Sao Tome and Principe, we also have 3D seismic acquisition requirements of approximately 13,500 square kilometers. In South Africa, subject to customary governmental approvals, we have 2D seismic acquisition requirements of approximately 500 line kilometers. 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 six months ended June 30, 2019 are as follows: Three months ended June 30, 2019 Six Months Ended (In thousands) Operating lease cost $ 1,602 $ 3,009 Short-term lease cost 582 587 Total lease cost $ 2,184 $ 3,596 Other information related to operating leases at June 30, 2019 , is as follows: June 30, 2019 (In thousands, except lease term and discount rate) Balance sheet classifications Other assets (right-of-use assets) $ 21,432 Accrued liabilities (current maturities of leases) 3,018 Other long-term liabilities (non-current maturities of leases) 20,653 Weighted average remaining lease term 9.1 years Weighted average discount rate 9.9 % The table below presents supplemental cash flow information related to leases during the six months ended June 30, 2019 : Six Months Ended (In thousands) Operating cash flows for operating leases $ 1,750 Future minimum rental commitments under our leases at June 30, 2019 , are as follows: Operating Leases(1) (In thousands) 2019(2) $ 1,100 2020 4,699 2021 3,895 2022 3,918 2023 3,907 Thereafter 19,520 Total undiscounted lease payments $ 37,039 Less: Imputed interest (13,368 ) Total lease liabilities $ 23,671 __________________________________ (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 July 1, 2019 through December 31, 2019 . Performance Obligations As of June 30, 2019 and December 31, 2018 , the Company had secured performance bonds totaling $201.4 million and $200.9 million , respectively, for our supplemental bonding requirements stipulated by the BOEM and $3.7 million and $3.7 million , respectively, to another operator 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 June 30, 2019 and December 31, 2018 , we had zero and $0.6 million , respectively, of cash collateral against these secured performance bonds which is classified as Other long term assets in our consolidated balance sheets. Dividends On August 2, 2019, we declared our quarterly cash dividend of $0.0452 |
Additional Financial Informatio
Additional Financial Information | 6 Months Ended |
Jun. 30, 2019 | |
Additional Financial Information | |
Additional Financial Information | Additional Financial Information Accrued Liabilities Accrued liabilities consisted of the following: June 30, December 31, (In thousands) Accrued liabilities: Exploration, development and production $ 109,176 $ 92,613 Revenue payable 37,030 24,379 Current asset retirement obligations 6,967 6,617 Operating lease liabilities 3,018 — General and administrative expenses 23,949 39,373 Interest 12,635 18,152 Income taxes 56,358 8,958 Taxes other than income 5,012 4,613 Derivatives 2,665 441 Other 1,569 450 $ 258,379 $ 195,596 Asset Retirement Obligations The following table summarizes the changes in the Company's asset retirement obligations: June 30, (In thousands) Asset retirement obligations: Beginning asset retirement obligations $ 151,953 Additions associated with Equatorial Guinea - Ceiba Field and Okume Complex 114,395 Liabilities incurred during period 5,762 Liabilities settled during period (1,228 ) Revisions in estimated retirement obligations 1,164 Accretion expense 11,613 Ending asset retirement obligations $ 283,659 With an effective date of January 1, 2019, our outstanding shares in KTIPI were transferred to Trident in exchange for a 40.375% undivided interest in the Ceiba Field and Okume Complex. As a result, our interest in the Ceiba Field and Okume Complex is accounted for under the proportionate consolidation method of accounting going forward, which includes additions to our asset retirement obligations. 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 any insurance reimbursements. During the three months ended June 30, 2019 and 2018 , we incurred approximately $11.2 million and $9.5 million , respectively in expenditures offset by approximately $8.9 million and $8.4 million , respectively in insurance recoveries. During the six months ended June 30, 2019 and 2018 , we incurred approximately $22.2 million and $19.2 million , respectively in expenditures offset by approximately $39.9 million and $9.7 million , respectively in insurance recoveries. Other Expenses, Net Other expenses, net incurred during the period is comprised of the following: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In thousands) Income (loss) on disposal of inventory $ — $ (24 ) $ 187 $ (24 ) Income (loss) on ARO liability settlements (5 ) — 1,913 — Disputed charges and related costs, net of recoveries — 626 (14 ) 2,961 Other, net (1,788 ) 336 (1,760 ) 1,706 Other expenses, net $ (1,793 ) $ 938 $ 326 $ 4,643 The disputed charges and related costs, net of recoveries arise from the final award issued by the International Chamber of Commerce ("ICC") in favor of Kosmos in its arbitration against Tullow Ghana Limited, related to expenditures arising from Tullow's contract with Seadrill for use of the West Leo drilling rig. |
Business Segment Information
Business Segment Information | 6 Months Ended |
Jun. 30, 2019 | |
Segment Reporting [Abstract] | |
Business Segment Information | Business Segment Information Kosmos is engaged in a single line of business, which is the exploration, development and production of oil and gas. At June 30, 2019 , substantially all of our long-lived assets and all of our product sales are related to operations in four geographic reporting segments: Ghana, Equatorial Guinea, Mauritania/Senegal and the U.S. Gulf of Mexico. In addition, we have exploration activities in other countries in the Atlantic Margins. To assess performance of the reporting segments, the Chief Operating Decision Maker ("CODM") 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 June 30, 2019 Revenues and other income: Oil and gas revenue $ 202,085 $ 64,484 $ — $ 129,364 $ — $ — $ 395,933 Other income, net 1 — — 124 19,079 (19,203 ) 1 Total revenues and other income 202,086 64,484 — 129,488 19,079 (19,203 ) 395,934 Costs and expenses: Oil and gas production 44,954 16,670 — 29,353 — — 90,977 Facilities insurance modifications, net 2,278 — — — — — 2,278 Exploration expenses 56 2,472 2,043 11,015 14,319 — 29,905 General and administrative 6,002 1,539 1,540 4,893 44,313 (30,215 ) 28,072 Depletion, depreciation and amortization 75,898 16,287 15 58,215 1,023 — 151,438 Interest and other financing costs, net(1) 19,026 — (6,524 ) 5,642 43,443 (1,784 ) 59,803 Derivatives, net — — — (1,390 ) (12,795 ) — (14,185 ) Other expenses, net (12,982 ) (2,583 ) 412 553 11 12,796 (1,793 ) Total costs and expenses 135,232 34,385 (2,514 ) 108,281 90,314 (19,203 ) 346,495 Income (loss) before income taxes 66,854 30,099 2,514 21,207 (71,235 ) — 49,439 Income tax expense (benefit) 24,683 11,762 — 4,439 (8,282 ) — 32,602 Net income (loss) $ 42,171 $ 18,337 $ 2,514 $ 16,768 $ (62,953 ) $ — $ 16,837 Consolidated capital expenditures $ 33,496 $ 6,115 $ 4,039 $ 41,177 $ 15,858 $ — $ 100,685 Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Six months ended June 30, 2019 Revenues and other income: Oil and gas revenue $ 325,003 $ 153,289 $ — $ 214,431 $ — $ — $ 692,723 Other income, net 1 — — 259 91,888 (92,147 ) 1 Total revenues and other income 325,004 153,289 — 214,690 91,888 (92,147 ) 692,724 Costs and expenses: — Oil and gas production 75,010 39,276 — 56,490 — — 170,776 Facilities insurance modifications, net (17,743 ) — — — — — (17,743 ) Exploration expenses 107 5,643 8,485 22,209 23,805 — 60,249 General and administrative 11,958 3,584 3,827 12,286 88,519 (56,194 ) 63,980 Depletion, depreciation and amortization 130,761 39,304 31 97,409 2,028 — 269,533 Interest and other financing costs, net(1) 39,679 — (13,317 ) 11,571 60,478 (3,567 ) 94,844 Derivatives, net — — — 30,513 32,387 — 62,900 Other expenses, net 32,118 (2,243 ) 641 2,145 51 (32,386 ) 326 Total costs and expenses 271,890 85,564 (333 ) 232,623 207,268 (92,147 ) 704,865 Income (loss) before income taxes 53,114 67,725 333 (17,933 ) (115,380 ) — (12,141 ) Income tax expense (benefit) 19,700 27,293 — (3,766 ) (19,299 ) — 23,928 Net income (loss) $ 33,414 $ 40,432 $ 333 $ (14,167 ) $ (96,081 ) $ — $ (36,069 ) Consolidated capital expenditures $ 68,463 $ 21,051 $ 6,290 $ 87,059 $ 28,050 $ — $ 210,913 As of June 30, 2019 Property and equipment, net $ 1,643,410 $ 460,679 $ 422,539 $ 1,281,439 $ 39,506 $ — $ 3,847,573 Total assets $ 1,872,202 $ 498,195 $ 546,454 $ 3,343,917 $ 12,051,009 $ (13,846,043 ) $ 4,465,734 ______________________________________ (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(1) Mauritania/Senegal U.S. Gulf of Mexico(2) Corporate & Other Eliminations(3) Total (In thousands) Three months ended June 30, 2018 Revenues and other income: Oil and gas revenue $ 215,192 $ 69,198 $ — $ — $ (1 ) $ (69,198 ) $ 215,191 Other income, net 1 197 — — 172,546 (172,462 ) 282 Total revenues and other income 215,193 69,395 — — 172,545 (241,660 ) 215,473 Costs and expenses: Oil and gas production 49,274 11,666 — — 541 (11,666 ) 49,815 Facilities insurance modifications, net 1,029 — — — — — 1,029 Exploration expenses 34 16,211 2,202 — 59,034 — 77,481 General and administrative 4,612 1,022 941 — 41,376 (30,454 ) 17,497 Depletion, depreciation and amortization 73,110 24,574 15 — 1,164 (24,574 ) 74,289 Interest and other financing costs, net(4) 22,114 (4 ) (8,341 ) — 6,885 (1,784 ) 18,870 Derivatives, net — — — — 140,272 — 140,272 (Gain) loss on equity method investments, net — — — — — (16,100 ) (16,100 ) Other expenses, net 140,901 (283 ) (1 ) — 594 (140,273 ) 938 Total costs and expenses 291,074 53,186 (5,184 ) — 249,866 (224,851 ) 364,091 Income (loss) before income taxes (75,881 ) 16,209 5,184 — (77,321 ) (16,809 ) (148,618 ) Income tax expense (benefit) (46,603 ) 16,810 — — 1,258 (16,810 ) (45,345 ) Net income (loss) $ (29,278 ) $ (601 ) $ 5,184 $ — $ (78,579 ) $ 1 $ (103,273 ) Consolidated capital expenditures $ 20,727 $ 18,086 $ 3,058 $ — $ 55,302 $ — $ 97,173 Ghana Equatorial Guinea(1) Mauritania/Senegal U.S. Gulf of Mexico(2) Corporate & Other Eliminations(3) Total (In thousands) Six months ended June 30, 2018 Revenues and other income: Oil and gas revenue $ 342,387 $ 192,375 $ — $ — $ — $ (192,375 ) $ 342,387 Other income, net (18 ) 340 — — 237,606 (237,665 ) 263 Total revenues and other income 342,369 192,715 — — 237,606 (430,040 ) 342,650 Costs and expenses: Oil and gas production 94,579 37,516 — — 2,004 (37,516 ) 96,583 Facilities insurance modifications, net 9,478 — — — — — 9,478 Exploration expenses 258 17,080 5,400 — 75,936 — 98,674 General and administrative 9,865 2,007 2,232 — 80,486 (55,210 ) 39,380 Depletion, depreciation and amortization 126,461 78,572 31 — 2,074 (78,572 ) 128,566 Interest and other financing costs, net(4) 43,368 (5 ) (12,263 ) — 17,031 (3,567 ) 44,564 Derivatives, net — — — — 178,750 — 178,750 (Gain) loss on equity method investments, net — — — — — (34,796 ) (34,796 ) Other expenses, net 181,709 (162 ) — — 1,849 (178,753 ) 4,643 Total costs and expenses 465,718 135,008 (4,600 ) — 358,130 (388,414 ) 565,842 Income (loss) before income taxes (123,349 ) 57,707 4,600 — (120,524 ) (41,626 ) (223,192 ) Income tax expense (benefit) (71,011 ) 41,626 — — 1,318 (41,626 ) (69,693 ) Net income (loss) $ (52,338 ) $ 16,081 $ 4,600 $ — $ (121,842 ) $ — $ (153,499 ) Consolidated capital expenditures $ 38,829 $ 24,978 $ 6,314 $ — $ 84,681 $ — $ 154,802 As of June 30, 2018 Property and equipment, net $ 1,818,613 $ 9,806 $ 394,569 $ — $ 40,076 $ — $ 2,263,064 Total assets $ 2,110,848 $ 165,284 $ 461,536 $ — $ 8,741,413 $ (8,575,638 ) $ 2,903,443 ______________________________________ (1) Includes our proportionate share of our equity method investment in KTIPI, including our basis difference which is reflected in depletion, depreciation and amortization for the three and six months ended June 30, 2018 , except for capital expenditures. See Note 7 - Equity Method Investments for additional information regarding our equity method investments. (2) No activity prior to September 14, 2018, the DGE acquisition date. (3) Includes elimination of proportionate consolidation amounts recorded for KTIPI to reconcile to (Gain) loss on equity method investments, net as reported in the consolidated statements of operations. (4) 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. Six Months Ended June 30, 2019 2018 (In thousands) Consolidated capital expenditures: Consolidated Statements of Cash Flows - Investing activities: Oil and gas assets $ 153,268 $ 92,650 Other property 5,230 2,815 Adjustments: Changes in capital accruals 13,684 19,317 Exploration expense, excluding unsuccessful well costs(1) 53,150 54,020 Capitalized interest (14,253 ) (14,112 ) Other (166 ) 112 Total consolidated capital expenditures $ 210,913 $ 154,802 ______________________________________ (1) Unsuccessful well costs are included in oil and gas assets when incurred. |
Accounting Policies (Policies)
Accounting Policies (Policies) | 6 Months Ended |
Jun. 30, 2019 | |
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 Securities and Exchange Commission (“SEC”) for interim reporting. As permitted under those rules, certain notes or other financial information that are normally required by Generally Accepted Accounting Principles in the United States of America (“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, 2018 , included in our annual report on Form 10-K. |
Reclassifications | 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. Additionally, as a result of our outstanding shares in KTIPI being transferred for an undivided interest in the Ceiba Field and Okume Complex (effective January 1, 2019), our previously reported equity method investment in KTIPI has been allocated to the respective assets and liabilities on a relative fair value basis. See Note 7 — Equity Method Investments for additional information. |
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. In accordance with certain of our petroleum contracts, we have posted letters of credit related to performance guarantees for our minimum work obligations. 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 | 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. Inventories |
Leases (Policy applicable beginning January 1, 2019) | Leases (Policy applicable beginning January 1, 2019) In February 2016, the FASB issued ASU 2016-02, “Leases (Topic 842).” ASU 2016-02 was issued to increase transparency and comparability across organizations by recognizing substantially all leases on the balance sheet through the concept of right-of-use lease assets and liabilities. Under prior accounting guidance, lessees did not recognize lease assets or liabilities for leases classified as operating leases. The ASU was effective for fiscal years beginning after December 15, 2018, including interim periods within those fiscal years with early adoption permitted. In July 2018, the FASB issued ASU 2018-11, which added a transition option permitting entities to apply the provisions of the new standard at its adoption date instead of the earliest comparative period presented in the consolidated financial statements. Under this transition option, comparative reporting would not be required, and the provisions of the standard would be applied prospectively to leases in effect at the date of adoption. The Company adopted the guidance prospectively during the first quarter of 2019. As part of our adoption, we elected not to reassess historical lease classification, recognize short-term leases on our balance sheet, nor separate lease and non-lease components for our real estate leases. The adoption and implementation of this ASU resulted in a $21.7 million increase in assets and liabilities related to our leasing activities, which primarily consists of office leases. Our adoption of ASU 2016-02 did not impact retained earnings or other components of equity as of December 31, 2018. We account for leases in accordance with ASC Topic 842, Leases, (“ASC 842”). We determine if an arrangement is a lease at contract inception. A lease exists when a contract conveys to the customer the right to control the use of identified property, plant, or equipment for a period of time in exchange for consideration. The definition of a lease embodies two conditions: (1) there is an identified asset in the contract that is land or a depreciable asset (i.e., property, plant, and equipment), and (2) the customer has the right to control the use of the identified asset. In the normal course of business, the Company enters into various lease agreements for real estate and equipment related to its exploration, development and production activities that are currently accounted for as operating leases. Operating Leases are included in Other assets, Accrued liabilities, and Other long-term liabilities on our Consolidated Balance Sheets. The lease liabilities are initially and subsequently measured at the present value of the unpaid lease payments at the lease commencement date. Key estimates and judgments include how we determined: (1) the discount rate we use to discount the unpaid lease payments to present value; (2) lease term; and (3) lease payments. 1. ASC 842 requires a lessee to discount its unpaid lease payments using the interest rate implicit in the lease or, if that rate cannot be readily determined, its incremental borrowing rate. As most of our leases where we are the lessee do not provide an implicit rate, we use our incremental borrowing rate based on the information available at commencement date in determining the present value of lease payments. Our incremental borrowing rate for a lease is the rate of interest we would have to pay on a collateralized basis to borrow an amount equal to the lease payments under similar terms. 2. The lease term for all of our leases includes the non-cancellable period of the lease plus any additional periods covered by either an option to extend (or not to terminate) the lease that we are reasonably certain to exercise, or an option to extend (or not to terminate) the lease controlled by the lessor. 3. Lease payments included in the measurement of the lease asset or liability comprise the following: fixed payments (including in-substance fixed payments), variable payments that depend on index or rate, and the exercise price of a lessee option to purchase the underlying asset if we are reasonably certain to exercise. Amounts expected to be payable under residual value guarantee are also lease payments included in the measurement of the lease liability. The Right-of-use ("ROU") asset is initially measured at cost, which comprises the initial amount of the lease liability adjusted for lease payments made at or before the lease commencement date, plus any initial direct costs incurred less any lease incentives received. For operating leases, the ROU asset is subsequently measured throughout the lease term at the carrying amount of the lease liability, plus initial direct costs, plus (minus) any prepaid (accrued) lease payments, less the unamortized balance of lease incentives received. Lease expense for lease payments is recognized on a straight-line basis over the lease term. We monitor for events or changes in circumstances that require a reassessment of a lease. When a reassessment results in the re-measurement of a lease liability, a corresponding adjustment is made to the carrying amount of the corresponding ROU asset unless doing so would reduce the carrying amount of the ROU asset to an amount less than zero. In that case, the amount of the adjustment that would result in a negative ROU asset balance is recorded in profit or loss. We have lease agreements which include lease and non-lease components. We have elected to combine lease and non-lease components for all lease contracts. We have elected not to recognize ROU assets and lease liabilities for all short-term leases that have a lease term of 12 months or less. We recognize the lease payments associated with our short-term leases as an expense on a straight-line basis over the lease term. We adopted ASU 2016-02 using a modified retrospective transition approach as of the effective date as permitted by the amendments in ASU 2018-11, which provides an alternative modified retrospective transition method. As a result, we were not required to adjust our comparative period financial information for effects of the standard or make the new required lease disclosures for periods before the date of adoption (i.e. January 1, 2019). We have elected to adopt the package of transition practical expedients and, therefore, have not reassessed (1) whether existing or expired contracts contain a lease, (2) lease classification for existing or expired leases or (3) the accounting for initial direct costs that were previously capitalized. We did not elect the practical expedient to use hindsight for leases existing at the adoption date. Further, we do not expect the amendments in ASU 2018-01: Land Easement Practical Expedient to have an effect on us because we do not enter into land easement arrangements. |
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. Revenue Recognition |
Concentration of Credit Risk | Concentration of Credit Risk |
Recent Accounting Standards | Recent Accounting Standards |
Accounting Policies (Tables)
Accounting Policies (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
Accounting Policies [Abstract] | |
Schedule of cash and cash equivalents | June 30, December 31, (In thousands) Cash and cash equivalents $ 176,908 $ 173,515 Restricted cash - current 327 4,527 Restricted cash - long-term 7,574 7,574 Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows $ 184,809 $ 185,616 |
Schedule of oil and gas revenue | Oil and gas revenue is composed of the following: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In thousands) Revenues from contract with customer - Equatorial Guinea $ 63,165 $ — $ 152,279 $ — Revenues from contract with customer - Ghana 209,469 213,841 328,800 341,878 Revenues from contract with customers - U.S. Gulf of Mexico 129,364 — 214,431 — Provisional oil sales contracts (6,065 ) 1,350 (2,787 ) 509 Oil and gas revenue $ 395,933 $ 215,191 $ 692,723 $ 342,387 |
Property and Equipment (Tables)
Property and Equipment (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
Property, Plant and Equipment [Abstract] | |
Schedule of property and equipment | Property and equipment is stated at cost and consisted of the following: June 30, December 31, (In thousands) Oil and gas properties: Proved properties $ 4,773,104 $ 4,236,489 Unproved properties 865,529 759,472 Total oil and gas properties 5,638,633 4,995,961 Accumulated depletion (1,806,108 ) (1,551,097 ) Oil and gas properties, net 3,832,525 3,444,864 Other property 55,107 51,987 Accumulated depreciation (40,059 ) (37,150 ) Other property, net 15,048 14,837 Property and equipment, net $ 3,847,573 $ 3,459,701 |
Suspended Well Costs (Tables)
Suspended Well Costs (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
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 six months ended June 30, 2019 . The table excludes $1.4 million in costs that were capitalized and subsequently expensed during the same period. June 30, (In thousands) Beginning balance $ 367,665 Additions to capitalized exploratory well costs pending the determination of proved reserves 15,439 Reclassification due to determination of proved reserves (10,711 ) Capitalized exploratory well costs charged to expense — Ending balance $ 372,393 |
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: June 30, 2019 December 31, 2018 (In thousands, except well counts) Exploratory well costs capitalized for a period of one year or less $ — $ — Exploratory well costs capitalized for a period of one to two years 70,486 299,253 Exploratory well costs capitalized for a period of three years or greater 301,907 68,412 Ending balance $ 372,393 $ 367,665 Number of projects that have exploratory well costs that have been capitalized for a period greater than one year 3 3 |
Equity Method Investments (Tabl
Equity Method Investments (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
Equity Method Investments and Joint Ventures [Abstract] | |
Summary of financial information of KTIPI | Below is a summary of financial information for KTIPI presented on a 100% basis for 2018 and the results of operations for 2019 are presented based on our direct 40.4% ownership in the Ceiba Field and Okume Complex. December 31, 2018 (In thousands) Assets Total current assets $ 149,950 Property and equipment, net 271,627 Other assets 21 Total assets $ 421,598 Liabilities and stockholders' equity Total current liabilities $ 226,311 Total long-term liabilities 536,178 Shareholders' equity: Total shareholders' equity (340,891 ) Total liabilities and shareholders' equity $ 421,598 Three Months Ended Six Months Ended (In thousands) Revenues and other income: Oil and gas revenue $ 138,395 $ 384,749 Other income (170 ) 117 Total revenues and other income 138,225 384,866 Costs and expenses: Oil and gas production 23,332 75,033 Depletion, depreciation and amortization 21,881 75,951 Other expenses, net (73 ) (152 ) Total costs and expenses 45,140 150,832 Income before income taxes 93,085 234,034 Income tax expense 33,620 83,251 Net income $ 59,465 $ 150,783 Kosmos' share of net income $ 29,733 $ 75,392 Basis difference amortization(1) 13,633 40,596 Equity in earnings - KTIPI $ 16,100 $ 34,796 ______________________________________ (1) The basis difference, which is associated with oil and gas properties and subject to amortization, has been allocated to the Ceiba Field and Okume Complex. We amortize the basis difference using the unit-of-production method. |
Schedule of asset acquisition | These fair value estimates were used to allocate the carrying value of the equity method investment to our balance sheet on a relative fair value basis. Carrying Value Allocation (in thousands) Assets acquired: Proved oil and gas properties $ 372,144 Unproved oil and gas properties 103,909 Prepaids and other 7,273 Total assets acquired $ 483,326 Liabilities assumed: Asset retirement obligations $ 114,395 Deferred tax liabilities 247,636 Accrued liabilities and other 69,399 Total liabilities assumed $ 431,430 Carrying value: Equity method investment carrying value at December 31, 2018 $ 51,896 |
Debt (Tables)
Debt (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
Debt Disclosure [Abstract] | |
Schedule of debt | June 30, December 31, (In thousands) Outstanding debt principal balances: Facility $ 1,500,000 $ 1,325,000 Corporate Revolver 25,000 325,000 Senior Notes 650,000 — Senior Secured Notes — 525,000 Total 2,175,000 2,175,000 Unamortized deferred financing costs and discounts(1) (45,660 ) (54,453 ) Long-term debt, net $ 2,129,340 $ 2,120,547 __________________________________ (1) Includes $35.9 million and $40.5 million of unamortized deferred financing costs related to the Facility as of June 30, 2019 and December 31, 2018 , respectively; $9.7 million of unamortized deferred financing costs and discounts related to the Senior Notes as of June 30, 2019 ; and $14.0 million of unamortized deferred financing costs and discounts related to the Senior Secured Notes as of December 31, 2018 , respectively. |
Schedule of redemption prices (expressed as percentages of principal amount) of all or a part of the Senior Notes | On or after April 4, 2022, the Company may redeem all or a part of the Senior Notes at the redemption prices (expressed as percentages of principal amount) set forth below plus accrued and unpaid interest: Year Percentage On or after April 4, 2022, but before April 4, 2023 103.6 % On or after April 4, 2023, but before April 4, 2024 101.8 % On or after April 4, 2024 and thereafter 100.0 % |
Schedule of estimated repayments of debt | At June 30, 2019 , the estimated repayments of debt during the five fiscal year periods and thereafter are as follows: Payments Due by Year Total 2019(2) 2020 2021 2022 2023 Thereafter (In thousands) Principal debt repayments(1) $ 2,175,000 $ — $ — $ 274,800 $ 309,200 $ 271,600 $ 1,319,400 __________________________________ (1) Includes the scheduled principal maturities for the $650.0 million aggregate principal amount of Senior Notes issued in April 2019, borrowings under the Facility and borrowings under the Corporate Revolver. The scheduled maturities of debt related to the Facility are based on, as of June 30, 2019 , 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 July 1, 2019 through December 31, 2019 . |
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 June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In thousands) Interest expense $ 38,450 $ 24,912 $ 76,622 $ 49,804 Amortization—deferred financing costs 2,302 2,283 4,689 4,723 Loss on extinguishment of debt 24,794 — 24,794 4,056 Capitalized interest (7,002 ) (9,292 ) (14,253 ) (14,112 ) Deferred interest 433 166 1,270 (1,090 ) Interest income (591 ) (843 ) (1,243 ) (1,791 ) Other, net 1,417 1,644 2,965 2,974 Interest and other financing costs, net $ 59,803 $ 18,870 $ 94,844 $ 44,564 |
Derivative Financial Instrume_2
Derivative Financial Instruments (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
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 June 30, 2019 . Volumes and weighted average prices are net of any offsetting derivative contracts entered into. Weighted Average Price per Bbl Net Deferred Premium Term Type of Contract Index MBbl Payable/(Receivable) Swap Sold Put Floor Ceiling 2019: Jul — Dec Three-way collars Dated Brent 5,256 $ 1.17 $ — $ 43.81 $ 53.33 $ 73.57 Jul — Dec Sold calls(1) Dated Brent 460 — — — — 80.00 Jul — Dec Swaps NYMEX WTI 730 — 52.01 — — — Jul — Dec Collars Argus LLS 500 — — — 60.00 88.75 2020: Jan — Dec Three-way collars Dated Brent 6,000 $ 0.45 $ — $ 45.00 $ 57.50 $ 80.18 Jan — Dec Sold calls(1)(2) Dated Brent 8,000 $ 1.17 $ — $ — $ — $ 85.00 __________________________________ (1) Represents call option contracts sold to counterparties to enhance other derivative positions. (2) Deferred premium payable to be paid July 1, 2019 — December 31, 2019. |
Schedule of derivative instruments by balance sheet location | The following tables disclose the Company’s derivative instruments as of June 30, 2019 and December 31, 2018 , and gain/(loss) from derivatives during the three and six months ended June 30, 2019 and 2018 , respectively: Estimated Fair Value Asset (Liability) Type of Contract Balance Sheet Location June 30, December 31, (In thousands) Derivatives not designated as hedging instruments: Derivative assets: Commodity(1) Derivatives assets—current $ 11,511 $ 38,785 Commodity(2) Derivatives assets—long-term 7,264 14,312 Derivative liabilities: Commodity(3) Derivatives liabilities—current (26,897 ) (12,172 ) Commodity(4) Derivatives liabilities—long-term (5,776 ) (10,181 ) Total derivatives not designated as hedging instruments $ (13,898 ) $ 30,744 __________________________________ (1) Includes zero and $0.4 million as of June 30, 2019 and December 31, 2018 , respectively which represents our provisional oil sales contract. Also, includes net deferred premiums payable of $4.0 million and $1.6 million related to commodity derivative contracts as of June 30, 2019 and December 31, 2018 , respectively. (2) Includes net deferred premiums payable of $0.8 million and $1.3 million related to commodity derivative contracts as of June 30, 2019 and December 31, 2018 , respectively. (3) Includes net deferred premiums payable of $7.8 million and $18.0 million related to commodity derivative contracts as of June 30, 2019 and December 31, 2018 , respectively. (4) Includes net deferred premiums payable of $0.8 million and $0.5 million related to commodity derivative contracts as of June 30, 2019 and December 31, 2018 , respectively. |
Schedule of derivative instruments by location of gain/(loss) | Amount of Gain/(Loss) Amount of Gain/(Loss) Three Months Ended Six Months Ended June 30, June 30, Type of Contract Location of Gain/(Loss) 2019 2018 2019 2018 (In thousands) Derivatives not designated as hedging instruments: Commodity(1) Oil and gas revenue $ (6,064 ) $ 1,350 $ (2,786 ) $ 509 Commodity Derivatives, net 14,185 (140,272 ) (62,900 ) (178,750 ) Interest rate Interest expense — 98 — 451 Total derivatives not designated as hedging instruments $ 8,121 $ (138,824 ) $ (65,686 ) $ (177,790 ) __________________________________ (1) Amounts represent the change in fair value of our provisional oil sales contracts. |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
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 June 30, 2019 and December 31, 2018 , 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) June 30, 2019 Assets: Commodity derivatives $ — $ 18,775 $ — $ 18,775 Liabilities: Commodity derivatives — (32,673 ) — (32,673 ) Total $ — $ (13,898 ) $ — $ (13,898 ) December 31, 2018 Assets: Commodity derivatives $ — $ 53,097 $ — $ 53,097 Liabilities: Commodity derivatives — (22,353 ) — (22,353 ) Total $ — $ 30,744 $ — $ 30,744 |
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 June 30, 2019 and December 31, 2018 : June 30, 2019 December 31, 2018 Carrying Value Fair Value Carrying Value Fair Value (In thousands) Senior Notes $ 642,089 $ 656,422 $ — $ — Senior Secured Notes — — 511,873 525,026 Corporate Revolver 25,000 25,000 325,000 325,000 Facility 1,500,000 1,500,000 1,325,000 1,325,000 Total $ 2,167,089 $ 2,181,422 $ 2,161,873 $ 2,175,026 |
Equity-based Compensation (Tabl
Equity-based Compensation (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
Disclosure of Compensation Related Costs, Share-based Payments [Abstract] | |
Schedule of plan activity | The following table reflects the outstanding restricted stock units as of June 30, 2019 : 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, 2018 4,115 $ 6.42 6,716 $ 9.02 Granted(1) 2,965 4.91 3,109 6.02 Forfeited(1) (85 ) 6.33 (285 ) 9.92 Vested (1,909 ) 5.87 (1,271 ) 6.36 Outstanding at June 30, 2019 5,086 5.74 8,269 8.39 __________________________________ (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) | 6 Months Ended |
Jun. 30, 2019 | |
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 June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In thousands) United States $ (18,499 ) $ 1,682 $ (74,240 ) $ 3,315 Bermuda — (15,890 ) — (31,961 ) Foreign—other 67,938 (134,410 ) 62,099 (194,546 ) Income (loss) before income taxes $ 49,439 $ (148,618 ) $ (12,141 ) $ (223,192 ) |
Net Income (Loss) Per Share (Ta
Net Income (Loss) Per Share (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
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 Six Months Ended June 30, June 30, 2019 2018 2019 2018 (In thousands, except per share data) Numerator: Net income (loss) allocable to common stockholders $ 16,837 $ (103,273 ) $ (36,069 ) $ (153,499 ) Denominator: Weighted average number of shares outstanding: Basic 401,323 396,826 401,244 396,218 Restricted stock units(1) 6,907 — — — Diluted 408,230 396,826 401,244 396,218 Net income (loss) per share: Basic $ 0.04 $ (0.26 ) $ (0.09 ) $ (0.39 ) Diluted $ 0.04 $ (0.26 ) $ (0.09 ) $ (0.39 ) __________________________________ (1) We excluded outstanding restricted stock awards and units of 1.1 million and 11.4 million for the three months ended June 30, 2019 and 2018, respectively, and 12.9 million and 11.9 million for the six months ended June 30, 2019 and 2018 , 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 (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
Commitments and Contingencies Disclosure [Abstract] | |
Schedule of Components of Lease Costs and Cash Flow Information | The components of lease cost for the three and six months ended June 30, 2019 are as follows: Three months ended June 30, 2019 Six Months Ended (In thousands) Operating lease cost $ 1,602 $ 3,009 Short-term lease cost 582 587 Total lease cost $ 2,184 $ 3,596 The table below presents supplemental cash flow information related to leases during the six months ended June 30, 2019 : Six Months Ended (In thousands) Operating cash flows for operating leases $ 1,750 |
Schedule of Other Information on Leases | Other information related to operating leases at June 30, 2019 , is as follows: June 30, 2019 (In thousands, except lease term and discount rate) Balance sheet classifications Other assets (right-of-use assets) $ 21,432 Accrued liabilities (current maturities of leases) 3,018 Other long-term liabilities (non-current maturities of leases) 20,653 Weighted average remaining lease term 9.1 years Weighted average discount rate 9.9 % |
Schedule of Future Minimum Rental Commitments | Future minimum rental commitments under our leases at June 30, 2019 , are as follows: Operating Leases(1) (In thousands) 2019(2) $ 1,100 2020 4,699 2021 3,895 2022 3,918 2023 3,907 Thereafter 19,520 Total undiscounted lease payments $ 37,039 Less: Imputed interest (13,368 ) Total lease liabilities $ 23,671 __________________________________ (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 July 1, 2019 through December 31, 2019 . |
Additional Financial Informat_2
Additional Financial Information (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
Additional Financial Information | |
Schedule of accrued liabilities | Accrued liabilities consisted of the following: June 30, December 31, (In thousands) Accrued liabilities: Exploration, development and production $ 109,176 $ 92,613 Revenue payable 37,030 24,379 Current asset retirement obligations 6,967 6,617 Operating lease liabilities 3,018 — General and administrative expenses 23,949 39,373 Interest 12,635 18,152 Income taxes 56,358 8,958 Taxes other than income 5,012 4,613 Derivatives 2,665 441 Other 1,569 450 $ 258,379 $ 195,596 |
Schedule of changes in asset retirement obligations | The following table summarizes the changes in the Company's asset retirement obligations: June 30, (In thousands) Asset retirement obligations: Beginning asset retirement obligations $ 151,953 Additions associated with Equatorial Guinea - Ceiba Field and Okume Complex 114,395 Liabilities incurred during period 5,762 Liabilities settled during period (1,228 ) Revisions in estimated retirement obligations 1,164 Accretion expense 11,613 Ending asset retirement obligations $ 283,659 |
Schedule of other expenses, net incurred | Other expenses, net incurred during the period is comprised of the following: Three Months Ended June 30, Six Months Ended June 30, 2019 2018 2019 2018 (In thousands) Income (loss) on disposal of inventory $ — $ (24 ) $ 187 $ (24 ) Income (loss) on ARO liability settlements (5 ) — 1,913 — Disputed charges and related costs, net of recoveries — 626 (14 ) 2,961 Other, net (1,788 ) 336 (1,760 ) 1,706 Other expenses, net $ (1,793 ) $ 938 $ 326 $ 4,643 |
Business Segment Information (T
Business Segment Information (Tables) | 6 Months Ended |
Jun. 30, 2019 | |
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 June 30, 2019 Revenues and other income: Oil and gas revenue $ 202,085 $ 64,484 $ — $ 129,364 $ — $ — $ 395,933 Other income, net 1 — — 124 19,079 (19,203 ) 1 Total revenues and other income 202,086 64,484 — 129,488 19,079 (19,203 ) 395,934 Costs and expenses: Oil and gas production 44,954 16,670 — 29,353 — — 90,977 Facilities insurance modifications, net 2,278 — — — — — 2,278 Exploration expenses 56 2,472 2,043 11,015 14,319 — 29,905 General and administrative 6,002 1,539 1,540 4,893 44,313 (30,215 ) 28,072 Depletion, depreciation and amortization 75,898 16,287 15 58,215 1,023 — 151,438 Interest and other financing costs, net(1) 19,026 — (6,524 ) 5,642 43,443 (1,784 ) 59,803 Derivatives, net — — — (1,390 ) (12,795 ) — (14,185 ) Other expenses, net (12,982 ) (2,583 ) 412 553 11 12,796 (1,793 ) Total costs and expenses 135,232 34,385 (2,514 ) 108,281 90,314 (19,203 ) 346,495 Income (loss) before income taxes 66,854 30,099 2,514 21,207 (71,235 ) — 49,439 Income tax expense (benefit) 24,683 11,762 — 4,439 (8,282 ) — 32,602 Net income (loss) $ 42,171 $ 18,337 $ 2,514 $ 16,768 $ (62,953 ) $ — $ 16,837 Consolidated capital expenditures $ 33,496 $ 6,115 $ 4,039 $ 41,177 $ 15,858 $ — $ 100,685 Ghana Equatorial Guinea Mauritania/Senegal U.S. Gulf of Mexico Corporate & Other Eliminations Total (In thousands) Six months ended June 30, 2019 Revenues and other income: Oil and gas revenue $ 325,003 $ 153,289 $ — $ 214,431 $ — $ — $ 692,723 Other income, net 1 — — 259 91,888 (92,147 ) 1 Total revenues and other income 325,004 153,289 — 214,690 91,888 (92,147 ) 692,724 Costs and expenses: — Oil and gas production 75,010 39,276 — 56,490 — — 170,776 Facilities insurance modifications, net (17,743 ) — — — — — (17,743 ) Exploration expenses 107 5,643 8,485 22,209 23,805 — 60,249 General and administrative 11,958 3,584 3,827 12,286 88,519 (56,194 ) 63,980 Depletion, depreciation and amortization 130,761 39,304 31 97,409 2,028 — 269,533 Interest and other financing costs, net(1) 39,679 — (13,317 ) 11,571 60,478 (3,567 ) 94,844 Derivatives, net — — — 30,513 32,387 — 62,900 Other expenses, net 32,118 (2,243 ) 641 2,145 51 (32,386 ) 326 Total costs and expenses 271,890 85,564 (333 ) 232,623 207,268 (92,147 ) 704,865 Income (loss) before income taxes 53,114 67,725 333 (17,933 ) (115,380 ) — (12,141 ) Income tax expense (benefit) 19,700 27,293 — (3,766 ) (19,299 ) — 23,928 Net income (loss) $ 33,414 $ 40,432 $ 333 $ (14,167 ) $ (96,081 ) $ — $ (36,069 ) Consolidated capital expenditures $ 68,463 $ 21,051 $ 6,290 $ 87,059 $ 28,050 $ — $ 210,913 As of June 30, 2019 Property and equipment, net $ 1,643,410 $ 460,679 $ 422,539 $ 1,281,439 $ 39,506 $ — $ 3,847,573 Total assets $ 1,872,202 $ 498,195 $ 546,454 $ 3,343,917 $ 12,051,009 $ (13,846,043 ) $ 4,465,734 ______________________________________ (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(1) Mauritania/Senegal U.S. Gulf of Mexico(2) Corporate & Other Eliminations(3) Total (In thousands) Three months ended June 30, 2018 Revenues and other income: Oil and gas revenue $ 215,192 $ 69,198 $ — $ — $ (1 ) $ (69,198 ) $ 215,191 Other income, net 1 197 — — 172,546 (172,462 ) 282 Total revenues and other income 215,193 69,395 — — 172,545 (241,660 ) 215,473 Costs and expenses: Oil and gas production 49,274 11,666 — — 541 (11,666 ) 49,815 Facilities insurance modifications, net 1,029 — — — — — 1,029 Exploration expenses 34 16,211 2,202 — 59,034 — 77,481 General and administrative 4,612 1,022 941 — 41,376 (30,454 ) 17,497 Depletion, depreciation and amortization 73,110 24,574 15 — 1,164 (24,574 ) 74,289 Interest and other financing costs, net(4) 22,114 (4 ) (8,341 ) — 6,885 (1,784 ) 18,870 Derivatives, net — — — — 140,272 — 140,272 (Gain) loss on equity method investments, net — — — — — (16,100 ) (16,100 ) Other expenses, net 140,901 (283 ) (1 ) — 594 (140,273 ) 938 Total costs and expenses 291,074 53,186 (5,184 ) — 249,866 (224,851 ) 364,091 Income (loss) before income taxes (75,881 ) 16,209 5,184 — (77,321 ) (16,809 ) (148,618 ) Income tax expense (benefit) (46,603 ) 16,810 — — 1,258 (16,810 ) (45,345 ) Net income (loss) $ (29,278 ) $ (601 ) $ 5,184 $ — $ (78,579 ) $ 1 $ (103,273 ) Consolidated capital expenditures $ 20,727 $ 18,086 $ 3,058 $ — $ 55,302 $ — $ 97,173 Ghana Equatorial Guinea(1) Mauritania/Senegal U.S. Gulf of Mexico(2) Corporate & Other Eliminations(3) Total (In thousands) Six months ended June 30, 2018 Revenues and other income: Oil and gas revenue $ 342,387 $ 192,375 $ — $ — $ — $ (192,375 ) $ 342,387 Other income, net (18 ) 340 — — 237,606 (237,665 ) 263 Total revenues and other income 342,369 192,715 — — 237,606 (430,040 ) 342,650 Costs and expenses: Oil and gas production 94,579 37,516 — — 2,004 (37,516 ) 96,583 Facilities insurance modifications, net 9,478 — — — — — 9,478 Exploration expenses 258 17,080 5,400 — 75,936 — 98,674 General and administrative 9,865 2,007 2,232 — 80,486 (55,210 ) 39,380 Depletion, depreciation and amortization 126,461 78,572 31 — 2,074 (78,572 ) 128,566 Interest and other financing costs, net(4) 43,368 (5 ) (12,263 ) — 17,031 (3,567 ) 44,564 Derivatives, net — — — — 178,750 — 178,750 (Gain) loss on equity method investments, net — — — — — (34,796 ) (34,796 ) Other expenses, net 181,709 (162 ) — — 1,849 (178,753 ) 4,643 Total costs and expenses 465,718 135,008 (4,600 ) — 358,130 (388,414 ) 565,842 Income (loss) before income taxes (123,349 ) 57,707 4,600 — (120,524 ) (41,626 ) (223,192 ) Income tax expense (benefit) (71,011 ) 41,626 — — 1,318 (41,626 ) (69,693 ) Net income (loss) $ (52,338 ) $ 16,081 $ 4,600 $ — $ (121,842 ) $ — $ (153,499 ) Consolidated capital expenditures $ 38,829 $ 24,978 $ 6,314 $ — $ 84,681 $ — $ 154,802 As of June 30, 2018 Property and equipment, net $ 1,818,613 $ 9,806 $ 394,569 $ — $ 40,076 $ — $ 2,263,064 Total assets $ 2,110,848 $ 165,284 $ 461,536 $ — $ 8,741,413 $ (8,575,638 ) $ 2,903,443 ______________________________________ (1) Includes our proportionate share of our equity method investment in KTIPI, including our basis difference which is reflected in depletion, depreciation and amortization for the three and six months ended June 30, 2018 , except for capital expenditures. See Note 7 - Equity Method Investments for additional information regarding our equity method investments. (2) No activity prior to September 14, 2018, the DGE acquisition date. (3) Includes elimination of proportionate consolidation amounts recorded for KTIPI to reconcile to (Gain) loss on equity method investments, net as reported in the consolidated statements of operations. (4) 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. Six Months Ended June 30, 2019 2018 (In thousands) Consolidated capital expenditures: Consolidated Statements of Cash Flows - Investing activities: Oil and gas assets $ 153,268 $ 92,650 Other property 5,230 2,815 Adjustments: Changes in capital accruals 13,684 19,317 Exploration expense, excluding unsuccessful well costs(1) 53,150 54,020 Capitalized interest (14,253 ) (14,112 ) Other (166 ) 112 Total consolidated capital expenditures $ 210,913 $ 154,802 |
Organization (Details)
Organization (Details) | 6 Months Ended |
Jun. 30, 2019segment | |
Organization, Consolidation and Presentation of Financial Statements [Abstract] | |
Number of reportable segments | 4 |
Accounting Policies (Details)
Accounting Policies (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2018 | Jun. 30, 2019 | Jan. 01, 2019 | Dec. 31, 2018 | Dec. 31, 2017 | |
Cash, Cash Equivalents and Restricted Cash | |||||
Cash and cash equivalents | $ 176,908 | $ 173,515 | |||
Restricted cash - current | 327 | 4,527 | |||
Restricted cash - long-term | 7,574 | 7,574 | |||
Total cash, cash equivalents and restricted cash shown in the consolidated statements of cash flows | $ 146,486 | 184,809 | 185,616 | $ 304,986 | |
Inventories | |||||
Materials and supplies inventory | 98,200 | 83,400 | |||
Hydrocarbons inventory | 10,300 | $ 1,400 | |||
Leases | |||||
Other assets (right-of-use assets) | 21,432 | ||||
Total lease liabilities | $ 23,671 | ||||
Accounting Standards Update 2016-02 | |||||
Leases | |||||
Other assets (right-of-use assets) | $ 21,700 | ||||
Total lease liabilities | $ 21,700 | ||||
Sales Revenue, Net | Customer Concentration Risk | |||||
Risks and Uncertainties | |||||
Concentration risk, percentage | 22.00% | 22.00% |
Accounting Policies - Summary o
Accounting Policies - Summary of Oil and Gas Revenue (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Disaggregation of Revenue [Line Items] | ||||
Provisional oil sales contracts | $ 8,121 | $ (138,824) | $ (65,686) | $ (177,790) |
Oil and gas revenue | 395,933 | 215,191 | 692,723 | 342,387 |
Oil and gas revenue | ||||
Disaggregation of Revenue [Line Items] | ||||
Provisional oil sales contracts | (6,065) | 1,350 | (2,787) | 509 |
Oil and gas revenue | 395,933 | 215,191 | 692,723 | 342,387 |
Equatorial Guinea | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from contracts with customers | 63,165 | 0 | 152,279 | 0 |
Ghana | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from contracts with customers | 209,469 | 213,841 | 328,800 | 341,878 |
Gulf of Mexico | ||||
Disaggregation of Revenue [Line Items] | ||||
Revenue from contracts with customers | $ 129,364 | $ 0 | $ 214,431 | $ 0 |
Acquisitions and Divestitures (
Acquisitions and Divestitures (Details) $ in Millions | 1 Months Ended | 3 Months Ended | ||||||
May 31, 2019 | Mar. 31, 2019km²meter | Oct. 31, 2018company | Sep. 30, 2018USD ($) | Aug. 31, 2018USD ($)km²blocksub_period | Jun. 30, 2018km² | Mar. 31, 2018km²block | Mar. 31, 2019km²meterblocksub_period | |
Acquisitions and Divestitures | ||||||||
Number of companies in alliance | company | 2 | |||||||
Deep Gulf Energy, LP | ||||||||
Acquisitions and Divestitures | ||||||||
Total purchase price | $ | $ 1,275 | |||||||
Cash consideration | $ | 952.6 | |||||||
Transaction related costs | $ | 14.9 | |||||||
U.S. Gulf Of Mexico Lease Sale 452 Blocks | ||||||||
Acquisitions and Divestitures | ||||||||
Number of blocks | block | 9 | |||||||
Petroleum Agreement | Marine XXI Block | ||||||||
Acquisitions and Divestitures | ||||||||
Participating interests | 85.00% | |||||||
Area of petroleum exploration | 2,350 | 2,350 | ||||||
Exploration period | 4 years | |||||||
3D seismic requirements | 2,200 | |||||||
Number of sub-periods | sub_period | 2 | |||||||
First sub exploration period | 3 years | |||||||
Petroleum Agreement | Blocks 10 and 13 | ||||||||
Acquisitions and Divestitures | ||||||||
Participating interests | 35.00% | |||||||
Area of petroleum exploration | 13,600 | |||||||
Exploration period | 4 years | |||||||
3D seismic requirements | 13,500 | |||||||
First sub exploration period | 4 years | |||||||
Number of blocks | block | 2 | |||||||
Petroleum Agreement | Blocks EG-21, S and W | ||||||||
Acquisitions and Divestitures | ||||||||
Area of petroleum exploration | 6,000 | |||||||
Exploration period | 5 years | |||||||
3D seismic requirements | 6,000 | |||||||
Number of sub-periods | sub_period | 2 | |||||||
First sub exploration period | 3 years | |||||||
Number of blocks | block | 3 | |||||||
Second sub exploration period | 2 years | |||||||
Farm-in agreement | U.S. Gulf Of Mexico Garden Banks Blocks | ||||||||
Acquisitions and Divestitures | ||||||||
Number of blocks | block | 18 | |||||||
Farm-in agreement | U.S. Gulf Of Mexico Blocks | ||||||||
Acquisitions and Divestitures | ||||||||
Number of blocks | block | 3 | |||||||
Farm-in agreement | Northern Cape Ultra Deep Block | ||||||||
Acquisitions and Divestitures | ||||||||
Area of petroleum exploration | 6,930 | 6,930 | ||||||
Exploration period | 2 years | |||||||
Participation interest acquired | 45.00% | |||||||
Farm-in agreement | Block EG-24 | ||||||||
Acquisitions and Divestitures | ||||||||
Area of petroleum exploration | 3,500 | |||||||
Exploration period | 3 years | |||||||
3D seismic requirements | 3,000 | |||||||
First sub exploration period | 4 years | |||||||
Participation interest acquired | 80.00% | 40.00% | ||||||
Farm out agreement | Blocks EG-21, S and W | ||||||||
Acquisitions and Divestitures | ||||||||
Participating interests | 40.00% | |||||||
Gain on sale of assets | $ | $ 7.7 | |||||||
SNPC | Petroleum Agreement | Marine XXI Block | ||||||||
Acquisitions and Divestitures | ||||||||
Carried participating interest percentage | 15.00% | 15.00% | ||||||
Percentage converted from carried to participating | 15.00% | 15.00% | ||||||
BP | Petroleum Agreement | Blocks 10 and 13 | ||||||||
Acquisitions and Divestitures | ||||||||
Participating interests | 50.00% | |||||||
ANP STP | Petroleum Agreement | Blocks 10 and 13 | ||||||||
Acquisitions and Divestitures | ||||||||
Carried participating interest percentage | 15.00% | |||||||
GEPetrol | Petroleum Agreement | Blocks EG-21, S and W | ||||||||
Acquisitions and Divestitures | ||||||||
Carried participating interest percentage | 20.00% | |||||||
Percentage converted from carried to participating | 20.00% | |||||||
GEPetrol | Farm-in agreement | Block EG-24 | ||||||||
Acquisitions and Divestitures | ||||||||
Carried participating interest percentage | 20.00% | |||||||
Percentage converted from carried to participating | 20.00% | |||||||
Trident | Farm out agreement | Blocks EG-21, S and W | ||||||||
Acquisitions and Divestitures | ||||||||
Participation interest acquired | 40.00% | |||||||
Shell Sao Tome and Principe B.V. | Farm out agreement | Block 6 | ||||||||
Acquisitions and Divestitures | ||||||||
Participation interest acquired | 20.00% | |||||||
Shell Sao Tome and Principe B.V. | Farm out agreement | Block 11 | ||||||||
Acquisitions and Divestitures | ||||||||
Participation interest acquired | 30.00% | |||||||
Common Shares | Deep Gulf Energy, LP | ||||||||
Acquisitions and Divestitures | ||||||||
Equity consideration | $ | $ 307.9 | |||||||
Minimum | Farm-in agreement | Northern Cape Ultra Deep Block | ||||||||
Acquisitions and Divestitures | ||||||||
Water depths | meter | 2,500 | 2,500 | ||||||
Maximum | Farm-in agreement | Northern Cape Ultra Deep Block | ||||||||
Acquisitions and Divestitures | ||||||||
Water depths | meter | 3,100 | 3,100 |
Joint Interest Billings and R_2
Joint Interest Billings and Related Party Receivables (Details) $ in Thousands | 1 Months Ended | 12 Months Ended | ||
Feb. 28, 2019USD ($)Agreement | Dec. 31, 2014 | Jun. 30, 2019USD ($) | Dec. 31, 2018USD ($) | |
Joint interest billings | ||||
Joint interest billings, net | $ 55,360 | $ 64,572 | ||
Long-term receivables | 28,140 | 19,002 | ||
Related party receivable | 0 | 5,580 | ||
TEN Discoveries | GNPC | ||||
Joint interest billings | ||||
Joint interest billings, net | 14,000 | 14,000 | ||
Long-term receivables | 22,200 | 14,000 | ||
TEN Discoveries | GNPC | ||||
Joint interest billings | ||||
GNPC's paying interest | 5.00% | |||
Kosmos-Trident International Petroleum Inc. | ||||
Joint interest billings | ||||
Related party receivable | $ 5,600 | |||
Kosmos-Trident International Petroleum Inc. | Trident | ||||
Joint interest billings | ||||
Ownership percentage | 50.00% | |||
Carry Advance Agreements | National Oil Companies Of Mauritania And Senegal | ||||
Joint interest billings | ||||
Long-term receivables | $ 6,000 | |||
Number of agreements | Agreement | 2 | |||
Share of development costs to be financed, up to | $ 239,700 |
Property and Equipment (Details
Property and Equipment (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Dec. 31, 2018 | |
Oil and gas properties: | |||||
Proved properties | $ 4,773,104 | $ 4,773,104 | $ 4,236,489 | ||
Unproved properties | 865,529 | 865,529 | 759,472 | ||
Total oil and gas properties | 5,638,633 | 5,638,633 | 4,995,961 | ||
Accumulated depletion | (1,806,108) | (1,806,108) | (1,551,097) | ||
Oil and gas properties, net | 3,832,525 | 3,832,525 | 3,444,864 | ||
Other property | 55,107 | 55,107 | 51,987 | ||
Accumulated depreciation | (40,059) | (40,059) | (37,150) | ||
Other property, net | 15,048 | 15,048 | 14,837 | ||
Property and equipment, net | 3,847,573 | $ 2,263,064 | 3,847,573 | $ 2,263,064 | $ 3,459,701 |
Depletion expense | $ 144,000 | $ 71,300 | $ 255,000 | $ 122,900 |
Suspended Well Costs - Summary
Suspended Well Costs - Summary of Suspended Well Costs (Details) | 6 Months Ended | ||
Jun. 30, 2019USD ($) | Jun. 30, 2019USD ($)project | Dec. 31, 2018USD ($)project | |
Oil and Gas Exploration and Production Industries Disclosures [Abstract] | |||
Capitalized exploratory well costs subsequently expensed in the same period | $ 1,400,000 | ||
Reconciliation of capitalized exploratory well costs on completed wells | |||
Beginning balance | 367,665,000 | ||
Additions to capitalized exploratory well costs pending the determination of proved reserves | 15,439,000 | ||
Reclassification due to determination of proved reserves | (10,711,000) | ||
Capitalized exploratory well costs charged to expense | 0 | ||
Ending balance | 372,393,000 | ||
Aging of capitalized exploratory well costs and number of projects for which exploratory well costs were capitalized for more than one year | |||
Exploratory well costs capitalized for a period of one year or less | $ 0 | $ 0 | |
Exploratory well costs capitalized for a period of one to two years | 70,486,000 | 299,253,000 | |
Exploratory well costs capitalized for a period of three years or greater | 301,907,000 | 68,412,000 | |
Ending balance | $ 372,393,000 | $ 372,393,000 | $ 367,665,000 |
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year | project | 3 | 3 |
Suspended Well Costs - Narrativ
Suspended Well Costs - Narrative (Details) | May 31, 2015project |
Greater Tortue Discovery | |
Capitalized Contract Cost [Line Items] | |
Number of additional appraisal wells drilled | 3 |
Equity Method Investments - Nar
Equity Method Investments - Narrative (Details) - Kosmos-Trident International Petroleum Inc. | Jan. 01, 2019 | Dec. 31, 2018 |
Schedule of Equity Method Investments [Line Items] | ||
Ownership percentage | 50.00% | |
Basis presented | 100.00% | |
Ceiba Field And Okume Complex | ||
Schedule of Equity Method Investments [Line Items] | ||
Direct interest acquired due to transfer | 40.375% |
Equity Method Investments - Sum
Equity Method Investments - Summary of Financial Information (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | |||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Dec. 31, 2018 | |
Costs and expenses: | |||||
Equity in earnings - KTIPI | $ 0 | $ 16,100 | $ 0 | $ 34,796 | |
Kosmos-Trident International Petroleum Inc. | |||||
Assets | |||||
Total current assets | $ 149,950 | ||||
Property and equipment, net | 271,627 | ||||
Other assets | 21 | ||||
Total assets | 421,598 | ||||
Liabilities and stockholders' equity | |||||
Total current liabilities | 226,311 | ||||
Total long-term liabilities | 536,178 | ||||
Shareholders' equity: | |||||
Total shareholders' equity | (340,891) | ||||
Total liabilities and shareholders' equity | $ 421,598 | ||||
Revenues and other income: | |||||
Oil and gas revenue | 138,395 | 384,749 | |||
Other income | (170) | 117 | |||
Total revenues and other income | 138,225 | 384,866 | |||
Costs and expenses: | |||||
Oil and gas production | 23,332 | 75,033 | |||
Depletion, depreciation and amortization | 21,881 | 75,951 | |||
Other expenses, net | (73) | (152) | |||
Total costs and expenses | 45,140 | 150,832 | |||
Income before income taxes | 93,085 | 234,034 | |||
Income tax expense | 33,620 | 83,251 | |||
Net income | 59,465 | 150,783 | |||
Kosmos' share of net income | 29,733 | 75,392 | |||
Basis difference amortization | 13,633 | 40,596 | |||
Equity in earnings - KTIPI | $ 16,100 | $ 34,796 |
Equity Method Investments - Ass
Equity Method Investments - Asset Acquisition (Details) - USD ($) $ in Thousands | Jan. 01, 2019 | Jun. 30, 2019 | Dec. 31, 2018 |
Liabilities assumed: | |||
Asset retirement obligations | $ 5,762 | ||
Carrying value: | |||
Equity method investment carrying value at December 31, 2018 | $ 0 | $ 51,896 | |
Ceiba Field And Okume Complex Acquisition | |||
Assets acquired: | |||
Proved oil and gas properties | $ 372,144 | ||
Unproved oil and gas properties | 103,909 | ||
Prepaids and other | 7,273 | ||
Total assets acquired | 483,326 | ||
Liabilities assumed: | |||
Asset retirement obligations | 114,395 | ||
Deferred tax liabilities | 247,636 | ||
Accrued liabilities and other | 69,399 | ||
Total liabilities assumed | $ 431,430 |
Debt - Schedule of Instruments
Debt - Schedule of Instruments (Details) - USD ($) $ in Thousands | Jun. 30, 2019 | Dec. 31, 2018 |
Debt | ||
Outstanding debt principal | $ 2,175,000 | $ 2,175,000 |
Unamortized issuance costs and discount | (45,660) | (54,453) |
Long-term debt, net | 2,129,340 | 2,120,547 |
The Facility | Revolving Credit Facility | ||
Debt | ||
Outstanding debt principal | 1,500,000 | 1,325,000 |
Unamortized issuance costs and discount | (35,900) | (40,500) |
Corporate Revolver | Revolving Credit Facility | ||
Debt | ||
Outstanding debt principal | 25,000 | 325,000 |
7.125% Senior Notes due 2026 | Senior Notes | ||
Debt | ||
Outstanding debt principal | 650,000 | 0 |
Unamortized issuance costs and discount | (9,700) | |
7.875% senior notes due 2021 | Senior Notes | ||
Debt | ||
Outstanding debt principal | $ 0 | 525,000 |
Unamortized issuance costs and discount | $ (14,000) |
Debt - Facility (Details)
Debt - Facility (Details) - USD ($) | 1 Months Ended | 3 Months Ended | 6 Months Ended | ||||
Apr. 30, 2019 | Feb. 28, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Mar. 31, 2019 | |
Debt Instrument [Line Items] | |||||||
Loss on extinguishment of debt | $ 24,794,000 | $ 0 | $ 24,794,000 | $ 4,056,000 | |||
The Facility | Revolving Credit Facility | |||||||
Debt Instrument [Line Items] | |||||||
Total commitment | $ 1,600,000,000 | $ 1,500,000,000 | $ 1,700,000,000 | ||||
Additional commitments | 500,000,000 | ||||||
Loss on extinguishment of debt | $ 4,100,000 | ||||||
Net deferred financing costs | 35,900,000 | 35,900,000 | |||||
Amount outstanding | 1,500,000,000 | 1,500,000,000 | |||||
Undrawn availability | 100,000,000 | 100,000,000 | |||||
Commitment reduction | $ 100,000,000 | ||||||
Availability period of revolving-credit | 1 month | ||||||
Amount outstanding under letters of credit | $ 0 | $ 0 |
Debt - Corporate Revolver (Deta
Debt - Corporate Revolver (Details) - USD ($) | 1 Months Ended | ||
Aug. 31, 2018 | Jun. 30, 2019 | Dec. 31, 2018 | |
Debt Instrument [Line Items] | |||
Net deferred financing costs | $ 7,629,000 | $ 8,937,000 | |
Corporate Revolver | Revolving Credit Facility | |||
Debt Instrument [Line Items] | |||
Maximum borrowing capacity | $ 400,000,000 | ||
Change in basis points | 1.00% | ||
Applicable margin | 5.00% | ||
Commitment fee percentage | 30.00% | ||
Amount outstanding | 25,000,000 | ||
Undrawn availability | 375,000,000 | ||
Net deferred financing costs | $ 7,600,000 |
Debt - Revolving Letter of Cred
Debt - Revolving Letter of Credit Facility (Details) | Jun. 30, 2019USD ($)letter_of_credit | Dec. 31, 2018USD ($) |
Revolving Letter of Credit Facility | ||
Debt Instrument [Line Items] | ||
Maximum borrowing capacity | $ 20,000,000 | |
Number of letters of credit | letter_of_credit | 6 | |
Amount outstanding | $ 9,400,000 | |
Letter of Credit Arrangement | ||
Debt Instrument [Line Items] | ||
Amount outstanding | $ 17,000,000 |
Debt - 7.875% Senior Secured No
Debt - 7.875% Senior Secured Notes due 2021 (Details) - USD ($) | 1 Months Ended | 3 Months Ended | 6 Months Ended | ||||
Apr. 30, 2019 | Apr. 30, 2015 | Aug. 31, 2014 | Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Debt Instrument [Line Items] | |||||||
Loss on extinguishment of debt | $ 24,794,000 | $ 0 | $ 24,794,000 | $ 4,056,000 | |||
Senior Notes | 7.875% senior notes due 2021 | |||||||
Debt Instrument [Line Items] | |||||||
Interest rate | 7.875% | ||||||
Senior notes offering face amount | $ 225,000,000 | $ 300,000,000 | |||||
Proceeds, net of offering discounts and deferred financing costs | $ 206,800,000 | $ 292,500,000 | |||||
Debt redeemed | $ 543,800,000 | ||||||
Loss on extinguishment of debt | $ 22,900,000 |
Debt - 7.125% Senior Notes due
Debt - 7.125% Senior Notes due 2026 (Details) - Senior Notes - USD ($) | 1 Months Ended | 6 Months Ended | ||
Apr. 30, 2019 | Apr. 30, 2015 | Aug. 31, 2014 | Jun. 30, 2019 | |
7.125% Senior Notes due 2026 | ||||
Debt Instrument [Line Items] | ||||
Interest rate | 7.125% | |||
Senior notes offering face amount | $ 650,000,000 | |||
Net proceeds from debt | $ 640,000,000 | |||
Redemption price percentage following change of control | 101.00% | |||
Redemption price percentage following sell of certain assets | 100.00% | |||
7.875% senior notes due 2021 | ||||
Debt Instrument [Line Items] | ||||
Interest rate | 7.875% | |||
Senior notes offering face amount | $ 225,000,000 | $ 300,000,000 | ||
Net proceeds from debt | $ 206,800,000 | $ 292,500,000 | ||
Any time prior to April 4, 2022 | 7.125% Senior Notes due 2026 | ||||
Debt Instrument [Line Items] | ||||
Maximum percentage of principal amount available to be redeemed with proceeds from equity offerings | 40.00% | |||
Debt Instrument Redemption Price Percentage With Proceeds From Equity Offerings | 107.10% | |||
Any time prior to April 4, 2022 with make-whole premium | 7.125% Senior Notes due 2026 | ||||
Debt Instrument [Line Items] | ||||
Redemption price, as percent of the principal amount | 100.00% | |||
On or after April 4, 2022, but before April 4, 2023 | 7.125% Senior Notes due 2026 | ||||
Debt Instrument [Line Items] | ||||
Redemption price, as percent of the principal amount | 103.60% | |||
On or after April 4, 2023, but before April 4, 2024 | 7.125% Senior Notes due 2026 | ||||
Debt Instrument [Line Items] | ||||
Redemption price, as percent of the principal amount | 101.80% | |||
On or after April 4, 2024 and thereafter | 7.125% Senior Notes due 2026 | ||||
Debt Instrument [Line Items] | ||||
Redemption price, as percent of the principal amount | 100.00% |
Debt - Maturities (Details)
Debt - Maturities (Details) - USD ($) | Jun. 30, 2019 | Apr. 30, 2019 | Dec. 31, 2018 |
Scheduled maturities of debt during the five year period and thereafter | |||
Total | $ 2,175,000,000 | $ 2,175,000,000 | |
2019 | 0 | ||
2020 | 0 | ||
2021 | 274,800,000 | ||
2022 | 309,200,000 | ||
2023 | 271,600,000 | ||
Thereafter | 1,319,400,000 | ||
Senior Notes | 7.125% Senior Notes due 2026 | |||
Scheduled maturities of debt during the five year period and thereafter | |||
Total | $ 650,000,000 | $ 0 | |
Senior notes offering face amount | $ 650,000,000 |
Debt - Interest and other finan
Debt - Interest and other financing costs, net (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Debt Disclosure [Abstract] | ||||
Interest expense | $ 38,450 | $ 24,912 | $ 76,622 | $ 49,804 |
Amortization—deferred financing costs | 2,302 | 2,283 | 4,689 | 4,723 |
Loss on extinguishment of debt | 24,794 | 0 | 24,794 | 4,056 |
Capitalized interest | (7,002) | (9,292) | (14,253) | (14,112) |
Deferred interest | 433 | 166 | 1,270 | (1,090) |
Interest income | (591) | (843) | (1,243) | (1,791) |
Other, net | 1,417 | 1,644 | 2,965 | 2,974 |
Interest and other financing costs, net | $ 59,803 | $ 18,870 | $ 94,844 | $ 44,564 |
Derivative Financial Instrume_3
Derivative Financial Instruments - Schedule of oil derivative contracts (Details) | 1 Months Ended | 6 Months Ended |
Jul. 31, 2019$ / bblMBbls | Jun. 30, 2019$ / bblMBbls | |
Dated Brent | Term July 2019 To December 2019 | Three-way collars | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 5,256 | |
Weighted Average Price Per Bbl [Abstract] | ||
Net Deferred Premium Payable/ (Receivable) (usd per bbl) | 1.17 | |
Swap (usd per bbl) | 0 | |
Sold Put (usd per bbl) | 43.81 | |
Floor (usd per bbl) | 53.33 | |
Ceiling (usd per bbl) | 73.57 | |
Dated Brent | Term July 2019 To December 2019 | Sold calls | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 460 | |
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) | 80 | |
Dated Brent | Term January 2020 To December 2020 | Three-way collars | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 6,000 | |
Weighted Average Price Per Bbl [Abstract] | ||
Net Deferred Premium Payable/ (Receivable) (usd per bbl) | 0.45 | |
Swap (usd per bbl) | 0 | |
Sold Put (usd per bbl) | 45 | |
Floor (usd per bbl) | 57.50 | |
Ceiling (usd per bbl) | 80.18 | |
Dated Brent | Term January 2020 To December 2020 | Sold calls | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 8,000 | |
Weighted Average Price Per Bbl [Abstract] | ||
Net Deferred Premium Payable/ (Receivable) (usd per bbl) | 1.17 | |
Swap (usd per bbl) | 0 | |
Sold Put (usd per bbl) | 0 | |
Floor (usd per bbl) | 0 | |
Ceiling (usd per bbl) | 85 | |
NYMEX WTI | Term July 2019 To December 2019 | Swaps | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 730 | |
Weighted Average Price Per Bbl [Abstract] | ||
Net Deferred Premium Payable/ (Receivable) (usd per bbl) | 0 | |
Swap (usd per bbl) | 52.01 | |
Sold Put (usd per bbl) | 0 | |
Floor (usd per bbl) | 0 | |
Ceiling (usd per bbl) | 0 | |
Argus LLS | Term July 2019 To December 2019 | 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) | 0 | |
Floor (usd per bbl) | 60 | |
Ceiling (usd per bbl) | 88.75 | |
Subsequent Event | Dated Brent | Term January 2020 To December 2020 | Put Option | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 2,000 | |
Weighted Average Price Per Bbl [Abstract] | ||
Sold Put (usd per bbl) | 50 | |
Floor (usd per bbl) | 60 |
Derivative Financial Instrume_4
Derivative Financial Instruments - Narrative (Details) - Dated Brent | 1 Months Ended | 6 Months Ended |
Jul. 31, 2019$ / bblMBbls | Jun. 30, 2019$ / bblMBbls | |
Sold calls | Term January 2020 To December 2020 | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 8,000 | |
Floor (usd per bbl) | 0 | |
Sold Put (usd per bbl) | 0 | |
Derivative Weighted Average Deferred Premium Per Barrel | 1.17 | |
Ceiling (usd per bbl) | 85 | |
Subsequent Event | Sold calls | Term January 2021 To December 2021 | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 1,000 | |
Ceiling (usd per bbl) | 75 | |
Subsequent Event | Put Option | Term January 2020 To December 2020 | ||
Derivative Financial Instruments | ||
Volume (mbbls) | MBbls | 2,000 | |
Floor (usd per bbl) | 60 | |
Sold Put (usd per bbl) | 50 |
Derivative Financial Instrume_5
Derivative Financial Instruments - Derivatives instrument and gain/loss from derivatives (Details) - USD ($) | Jun. 30, 2019 | Dec. 31, 2018 |
Derivative instruments, Balance Sheet Location | ||
Derivatives assets—current | $ 11,511,000 | $ 38,785,000 |
Derivatives assets—long-term | 7,264,000 | 14,312,000 |
Derivatives liabilities—current | (26,897,000) | (12,172,000) |
Derivatives liabilities—long-term | (5,776,000) | (10,181,000) |
Derivatives not designated as hedging instruments: | ||
Derivative instruments, Balance Sheet Location | ||
Total derivatives not designated as hedging instruments | (13,898,000) | 30,744,000 |
Derivatives not designated as hedging instruments: | Commodity | ||
Derivative instruments, Balance Sheet Location | ||
Derivatives assets—current | 11,511,000 | 38,785,000 |
Derivatives assets—long-term | 7,264,000 | 14,312,000 |
Derivatives liabilities—current | (26,897,000) | (12,172,000) |
Derivatives liabilities—long-term | (5,776,000) | (10,181,000) |
Net deferred premiums payable related to commodity derivative contracts - current assets | 4,000,000 | 1,600,000 |
Net deferred premiums payable related to commodity derivative contracts - non-current assets | 800,000 | 1,300,000 |
Net deferred premiums payable related to commodity derivative contracts - current liabilities | 7,800,000 | 18,000,000 |
Net deferred premiums payable related to commodity derivative contracts - non-current liabilities | 800,000 | 500,000 |
Oil and gas revenue | Derivatives not designated as hedging instruments: | Commodity | ||
Derivative instruments, Balance Sheet Location | ||
Derivatives assets—current | $ 0 | $ 400,000 |
Derivative Financial Instrume_6
Derivative Financial Instruments - Schedule of derivative instruments by location of gain/(loss) (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Derivative instruments, Location of Gain/(Loss) | ||||
Amount of Gain/(Loss) | $ 8,121 | $ (138,824) | $ (65,686) | $ (177,790) |
Commodity | Oil and gas revenue | ||||
Derivative instruments, Location of Gain/(Loss) | ||||
Amount of Gain/(Loss) | (6,064) | 1,350 | (2,786) | 509 |
Commodity | Derivatives, net | ||||
Derivative instruments, Location of Gain/(Loss) | ||||
Amount of Gain/(Loss) | 14,185 | (140,272) | (62,900) | (178,750) |
Interest rate | Interest expense | ||||
Derivative instruments, Location of Gain/(Loss) | ||||
Amount of Gain/(Loss) | $ 0 | $ 98 | $ 0 | $ 451 |
Fair Value Measurements (Detail
Fair Value Measurements (Details) - USD ($) $ in Thousands | Jun. 30, 2019 | Dec. 31, 2018 |
Carrying Value | ||
Liabilities: | ||
Long-term debt | $ 2,167,089 | $ 2,161,873 |
Fair Value | ||
Liabilities: | ||
Long-term debt | 2,181,422 | 2,175,026 |
7.125% Senior Notes due 2026 | Senior Notes | Carrying Value | ||
Liabilities: | ||
Long-term debt | 642,089 | 0 |
7.125% Senior Notes due 2026 | Senior Notes | Fair Value | ||
Liabilities: | ||
Long-term debt | 656,422 | 0 |
7.875% senior notes due 2021 | Senior Notes | Carrying Value | ||
Liabilities: | ||
Long-term debt | 0 | 511,873 |
7.875% senior notes due 2021 | Senior Notes | Fair Value | ||
Liabilities: | ||
Long-term debt | 0 | 525,026 |
Corporate Revolver | Facility | Carrying Value | ||
Liabilities: | ||
Long-term debt | 25,000 | 325,000 |
Corporate Revolver | Facility | Fair Value | ||
Liabilities: | ||
Long-term debt | 25,000 | 325,000 |
The Facility | Facility | Carrying Value | ||
Liabilities: | ||
Long-term debt | 1,500,000 | 1,325,000 |
The Facility | Facility | Fair Value | ||
Liabilities: | ||
Long-term debt | 1,500,000 | 1,325,000 |
Recurring basis | ||
Liabilities: | ||
Total fair value, net | (13,898) | 30,744 |
Recurring basis | Commodity | ||
Assets: | ||
Derivative asset, fair value | 18,775 | 53,097 |
Liabilities: | ||
Derivative liability, fair value | (32,673) | (22,353) |
Recurring basis | Quoted Prices in Active Markets for Identical Assets (Level 1) | ||
Liabilities: | ||
Total fair value, net | 0 | 0 |
Recurring basis | Quoted Prices in Active Markets for Identical Assets (Level 1) | Commodity | ||
Assets: | ||
Derivative asset, fair value | 0 | 0 |
Liabilities: | ||
Derivative liability, fair value | 0 | 0 |
Recurring basis | Significant Other Observable Inputs (Level 2) | ||
Liabilities: | ||
Total fair value, net | (13,898) | 30,744 |
Recurring basis | Significant Other Observable Inputs (Level 2) | Commodity | ||
Assets: | ||
Derivative asset, fair value | 18,775 | 53,097 |
Liabilities: | ||
Derivative liability, fair value | (32,673) | (22,353) |
Recurring basis | Significant Unobservable Inputs (Level 3) | ||
Liabilities: | ||
Total fair value, net | 0 | 0 |
Recurring basis | Significant Unobservable Inputs (Level 3) | Commodity | ||
Assets: | ||
Derivative asset, fair value | 0 | 0 |
Liabilities: | ||
Derivative liability, fair value | $ 0 | $ 0 |
Equity-based Compensation - Add
Equity-based Compensation - Additional Information (Details) - LTIP - USD ($) $ / shares in Units, $ in Millions | 1 Months Ended | 3 Months Ended | 6 Months Ended | ||
Mar. 31, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Compensation expense recognized | $ 9.5 | $ 9.1 | $ 17.9 | $ 17.1 | |
Tax benefit | 1.5 | 1.8 | 2.8 | 3.4 | |
Net tax shortfall (windfall) related to equity-based compensation | 0 | 0.4 | 1.2 | (0.3) | |
Fair value of awards vested | $ 0.8 | $ 25.4 | $ 14 | $ 82 | |
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) | 9,900,000 | 9,900,000 | |||
Restricted Stock Units (RSUs) | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Compensation expense not yet recognized | $ 47 | $ 47 | |||
Weighted average period over which compensation expense is to be recognized | 2 years 1 month 20 days | ||||
Market/Service Vesting Restricted Stock Units | |||||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | |||||
Grant date fair value of awards granted (in dollars per share) | $ 6.02 | ||||
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) | $ 4.83 | ||||
Expected volatility | 44.00% | ||||
Risk-free interest rate | 0.80% | ||||
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% |
Equity-based Compensation - Sch
Equity-based Compensation - Schedule of awards (Details) - LTIP shares in Thousands | 6 Months Ended |
Jun. 30, 2019$ / sharesshares | |
Service Vesting Restricted Stock Units | |
Outstanding unvested awards activity | |
Outstanding at the beginning of the period (in shares) | shares | 4,115 |
Granted (in shares) | shares | 2,965 |
Forfeited (in shares) | shares | (85) |
Vested (in shares) | shares | (1,909) |
Outstanding at the end of the period (in shares) | shares | 5,086 |
Weighted-Average Grant-Date Fair Value | |
Outstanding at beginning of the period (in dollars per share) | $ 6.42 |
Granted (in dollars per share) | 4.91 |
Forfeited (in dollars per share) | 6.33 |
Vested (in dollars per share) | 5.87 |
Outstanding at the end of the period (in dollars per share) | $ 5.74 |
Market/Service Vesting Restricted Stock Units | |
Outstanding unvested awards activity | |
Outstanding at the beginning of the period (in shares) | shares | 6,716 |
Granted (in shares) | shares | 3,109 |
Forfeited (in shares) | shares | (285) |
Vested (in shares) | shares | (1,271) |
Outstanding at the end of the period (in shares) | shares | 8,269 |
Weighted-Average Grant-Date Fair Value | |
Outstanding at beginning of the period (in dollars per share) | $ 9.02 |
Granted (in dollars per share) | 6.02 |
Forfeited (in dollars per share) | 9.92 |
Vested (in dollars per share) | 6.36 |
Outstanding at the end of the period (in dollars per share) | 8.39 |
Minimum | Market/Service Vesting Restricted Stock Units | |
Weighted-Average Grant-Date Fair Value | |
Granted (in dollars per share) | $ 4.83 |
Vesting percentage of the awards granted | 0.00% |
Maximum | Market/Service Vesting Restricted Stock Units | |
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 | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Income Taxes | ||||
Effective tax rate (as a percent) | 66.00% | 31.00% | 197.00% | 31.00% |
Income (loss) before income taxes | $ 49,439,000 | $ (148,618,000) | $ (12,141,000) | $ (223,192,000) |
Uncertain tax positions | 0 | 0 | ||
United States | ||||
Income Taxes | ||||
Income (loss) before income taxes | (18,499,000) | 1,682,000 | (74,240,000) | 3,315,000 |
Bermuda | ||||
Income Taxes | ||||
Income (loss) before income taxes | 0 | (15,890,000) | $ 0 | (31,961,000) |
Foreign—other | ||||
Income Taxes | ||||
Effective tax rate (as a percent) | 0.00% | |||
Statutory tax rate (as a percent) | 0.00% | |||
Income (loss) before income taxes | $ 67,938,000 | $ (134,410,000) | $ 62,099,000 | $ (194,546,000) |
Net Income (Loss) Per Share (De
Net Income (Loss) Per Share (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands | 3 Months Ended | 6 Months Ended | ||||
Jun. 30, 2019 | Mar. 31, 2019 | Jun. 30, 2018 | Mar. 31, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Numerator: | ||||||
Net income (loss) | $ 16,837 | $ (52,906) | $ (103,273) | $ (50,226) | $ (36,069) | $ (153,499) |
Weighted average number of shares outstanding: | ||||||
Basic (in shares) | 401,323 | 396,826 | 401,244 | 396,218 | ||
Restricted stock units (in shares) | 6,907 | 0 | 0 | 0 | ||
Diluted (in shares) | 408,230 | 396,826 | 401,244 | 396,218 | ||
Net income (loss) per share: | ||||||
Basic (in dollars per share) | $ 0.04 | $ (0.26) | $ (0.09) | $ (0.39) | ||
Diluted (in dollars per share) | $ 0.04 | $ (0.26) | $ (0.09) | $ (0.39) | ||
Outstanding restricted stock awards and units excluded from the computations of diluted net income per share (in shares) | 1,100 | 11,400 | 12,900 | 11,900 |
Commitments and Contingencies_2
Commitments and Contingencies (Details) | Aug. 02, 2019$ / shares | Jun. 30, 2019USD ($)$ / shares | Mar. 31, 2019$ / shares | Jun. 30, 2018$ / shares | Jun. 30, 2019USD ($)km²meterexploration_well$ / shares | Jun. 30, 2018$ / shares | Dec. 31, 2018USD ($) |
Commitments and contingencies | |||||||
Dividends declared per common stock (in dollars per share) | $ / shares | $ 0.0452 | $ 0.0452 | $ 0 | $ 0.0904 | $ 0 | ||
Sao Tome and Principe | |||||||
Commitments and contingencies | |||||||
Number of exploration wells | 1 | ||||||
3D seismic requirements | km² | 13,500 | ||||||
SENEGAL | |||||||
Commitments and contingencies | |||||||
Number of exploration wells | 2 | ||||||
Namibia | |||||||
Commitments and contingencies | |||||||
Number of exploration wells | 1 | ||||||
Mauritania | |||||||
Commitments and contingencies | |||||||
Number of exploration wells | 2 | ||||||
SOUTH AFRICA | |||||||
Commitments and contingencies | |||||||
2D seismic requirements | meter | 500,000 | ||||||
Surety Bond | Gulf of Mexico | |||||||
Commitments and contingencies | |||||||
Cash collateral | $ | $ 0 | $ 0 | $ 600,000 | ||||
Bureau Of Ocean Energy Management | Surety Bond | Gulf of Mexico | |||||||
Commitments and contingencies | |||||||
Required performance bonds | $ | 201,400,000 | 201,400,000 | 200,900,000 | ||||
Third Party | Surety Bond | Gulf of Mexico | |||||||
Commitments and contingencies | |||||||
Required performance bonds | $ | $ 3,700,000 | $ 3,700,000 | $ 3,700,000 | ||||
Subsequent Event | |||||||
Commitments and contingencies | |||||||
Dividends declared per common stock (in dollars per share) | $ / shares | $ 0.0452 |
Commitments and Contingencies -
Commitments and Contingencies - Leases (Details) $ in Thousands | 3 Months Ended | 6 Months Ended |
Jun. 30, 2019USD ($) | Jun. 30, 2019USD ($) | |
Lease, Cost [Abstract] | ||
Operating lease cost | $ 1,602 | $ 3,009 |
Short-term lease cost | 582 | 587 |
Total lease cost | 2,184 | 3,596 |
Balance sheet classifications | ||
Other assets (right-of-use assets) | 21,432 | 21,432 |
Accrued liabilities (current maturities of leases) | 3,018 | 3,018 |
Other long-term liabilities (non-current maturities of leases) | $ 20,653 | $ 20,653 |
Weighted average remaining lease term | 9 years 1 month 6 days | 9 years 1 month 6 days |
Weighted average discount rate | 9.90% | 9.90% |
Operating cash flows for operating leases | $ 1,750 | |
Operating Lease Liabilities, Payments Due [Abstract] | ||
2019 | $ 1,100 | 1,100 |
2020 | 4,699 | 4,699 |
2021 | 3,895 | 3,895 |
2022 | 3,918 | 3,918 |
2023 | 3,907 | 3,907 |
Thereafter | 19,520 | 19,520 |
Total undiscounted lease payments | 37,039 | 37,039 |
Less: Imputed interest | (13,368) | (13,368) |
Total lease liabilities | $ 23,671 | $ 23,671 |
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 |
Additional Financial Informat_3
Additional Financial Information (Details) - USD ($) $ in Thousands | Jan. 01, 2019 | Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | Dec. 31, 2018 |
Accrued liabilities: | ||||||
Exploration, development and production | $ 109,176 | $ 109,176 | $ 92,613 | |||
Revenue payable | 37,030 | 37,030 | 24,379 | |||
Current asset retirement obligations | 6,967 | 6,967 | 6,617 | |||
Operating lease liabilities | 3,018 | 3,018 | ||||
General and administrative expenses | 23,949 | 23,949 | 39,373 | |||
Interest | 12,635 | 12,635 | 18,152 | |||
Income taxes | 56,358 | 56,358 | 8,958 | |||
Taxes other than income | 5,012 | 5,012 | 4,613 | |||
Derivatives | 2,665 | 2,665 | 441 | |||
Other | 1,569 | 1,569 | 450 | |||
Accrued liabilities | 258,379 | 258,379 | $ 195,596 | |||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||||||
Beginning asset retirement obligations | 283,659 | 283,659 | ||||
Additions associated with Equatorial Guinea - Ceiba Field and Okume Complex | 114,395 | |||||
Liabilities incurred during period | 5,762 | |||||
Liabilities settled during period | (1,228) | |||||
Revisions in estimated retirement obligations | 1,164 | |||||
Accretion expense | 11,613 | |||||
Ending asset retirement obligations | $ 151,953 | 151,953 | ||||
Facilities insurance modifications, expenditures | 11,200 | $ 9,500 | 22,200 | $ 19,200 | ||
Facilities insurance modifications, insurance recoveries | 8,900 | 8,400 | 39,900 | 9,700 | ||
Other Expenses, Net | ||||||
Income (loss) on disposal of inventory | 0 | (24) | 187 | (24) | ||
Income (loss) on ARO liability settlements | (5) | 0 | 1,913 | 0 | ||
Disputed charges and related costs, net of recoveries | 0 | 626 | (14) | 2,961 | ||
Other, net | (1,788) | 336 | (1,760) | 1,706 | ||
Other expenses, net | $ (1,793) | $ 938 | $ 326 | $ 4,643 | ||
Kosmos-Trident International Petroleum Inc. | Ceiba Field And Okume Complex | ||||||
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward] | ||||||
Direct interest acquired due to transfer | 40.375% |
Business Segment Information (D
Business Segment Information (Details) $ in Thousands | 3 Months Ended | 6 Months Ended | |||||
Jun. 30, 2019USD ($) | Mar. 31, 2019USD ($) | Jun. 30, 2018USD ($) | Mar. 31, 2018USD ($) | Jun. 30, 2019USD ($)segment | Jun. 30, 2018USD ($) | Dec. 31, 2018USD ($) | |
Segment Reporting Information [Line Items] | |||||||
Number of reportable segments | segment | 4 | ||||||
Oil and gas revenue | $ 395,933 | $ 215,191 | $ 692,723 | $ 342,387 | |||
Other income, net | 1 | 282 | 1 | 263 | |||
Total revenues and other income | 395,934 | 215,473 | 692,724 | 342,650 | |||
Oil and gas production | 90,977 | 49,815 | 170,776 | 96,583 | |||
Facilities insurance modifications, net | 2,278 | 1,029 | (17,743) | 9,478 | |||
Exploration expenses | 29,905 | 77,481 | 60,249 | 98,674 | |||
General and administrative | 28,072 | 17,497 | 63,980 | 39,380 | |||
Depletion, depreciation and amortization | 151,438 | 74,289 | 269,533 | 128,566 | |||
Interest and other financing costs, net | 59,803 | 18,870 | 94,844 | 44,564 | |||
Derivatives, net | (14,185) | 140,272 | 62,900 | 178,750 | |||
(Gain) loss on equity method investments, net | 0 | (16,100) | 0 | (34,796) | |||
Other expenses, net | (1,793) | 938 | 326 | 4,643 | |||
Total costs and expenses | 346,495 | 364,091 | 704,865 | 565,842 | |||
Income (loss) before income taxes | 49,439 | (148,618) | (12,141) | (223,192) | |||
Income tax expense (benefit) | 32,602 | (45,345) | 23,928 | (69,693) | |||
Net income (loss) | 16,837 | $ (52,906) | (103,273) | $ (50,226) | (36,069) | (153,499) | |
Consolidated capital expenditures | 100,685 | 97,173 | 210,913 | 154,802 | |||
Property and equipment, net | 3,847,573 | 2,263,064 | 3,847,573 | 2,263,064 | $ 3,459,701 | ||
Total assets | 4,465,734 | 2,903,443 | 4,465,734 | 2,903,443 | $ 4,088,189 | ||
Corporate & Other | |||||||
Segment Reporting Information [Line Items] | |||||||
Oil and gas revenue | 0 | (1) | 0 | 0 | |||
Other income, net | 19,079 | 172,546 | 91,888 | 237,606 | |||
Total revenues and other income | 19,079 | 172,545 | 91,888 | 237,606 | |||
Oil and gas production | 0 | 541 | 0 | 2,004 | |||
Facilities insurance modifications, net | 0 | 0 | 0 | 0 | |||
Exploration expenses | 14,319 | 59,034 | 23,805 | 75,936 | |||
General and administrative | 44,313 | 41,376 | 88,519 | 80,486 | |||
Depletion, depreciation and amortization | 1,023 | 1,164 | 2,028 | 2,074 | |||
Interest and other financing costs, net | 43,443 | 6,885 | 60,478 | 17,031 | |||
Derivatives, net | (12,795) | 140,272 | 32,387 | 178,750 | |||
(Gain) loss on equity method investments, net | 0 | 0 | |||||
Other expenses, net | 11 | 594 | 51 | 1,849 | |||
Total costs and expenses | 90,314 | 249,866 | 207,268 | 358,130 | |||
Income (loss) before income taxes | (71,235) | (77,321) | (115,380) | (120,524) | |||
Income tax expense (benefit) | (8,282) | 1,258 | (19,299) | 1,318 | |||
Net income (loss) | (62,953) | (78,579) | (96,081) | (121,842) | |||
Consolidated capital expenditures | 15,858 | 55,302 | 28,050 | 84,681 | |||
Property and equipment, net | 39,506 | 40,076 | 39,506 | 40,076 | |||
Total assets | 12,051,009 | 8,741,413 | 12,051,009 | 8,741,413 | |||
Eliminations | |||||||
Segment Reporting Information [Line Items] | |||||||
Oil and gas revenue | 0 | (69,198) | 0 | (192,375) | |||
Other income, net | (19,203) | (172,462) | (92,147) | (237,665) | |||
Total revenues and other income | (19,203) | (241,660) | (92,147) | (430,040) | |||
Oil and gas production | 0 | (11,666) | 0 | (37,516) | |||
Facilities insurance modifications, net | 0 | 0 | 0 | 0 | |||
Exploration expenses | 0 | 0 | 0 | 0 | |||
General and administrative | (30,215) | (30,454) | (56,194) | (55,210) | |||
Depletion, depreciation and amortization | 0 | (24,574) | 0 | (78,572) | |||
Interest and other financing costs, net | (1,784) | (1,784) | (3,567) | (3,567) | |||
Derivatives, net | 0 | 0 | 0 | 0 | |||
(Gain) loss on equity method investments, net | (16,100) | (34,796) | |||||
Other expenses, net | 12,796 | (140,273) | (32,386) | (178,753) | |||
Total costs and expenses | (19,203) | (224,851) | (92,147) | (388,414) | |||
Income (loss) before income taxes | 0 | (16,809) | 0 | (41,626) | |||
Income tax expense (benefit) | 0 | (16,810) | 0 | (41,626) | |||
Net income (loss) | 0 | 1 | 0 | 0 | |||
Consolidated capital expenditures | 0 | 0 | 0 | 0 | |||
Property and equipment, net | 0 | 0 | 0 | 0 | |||
Total assets | (13,846,043) | (8,575,638) | (13,846,043) | (8,575,638) | |||
Ghana | Operating Segments | |||||||
Segment Reporting Information [Line Items] | |||||||
Oil and gas revenue | 202,085 | 215,192 | 325,003 | 342,387 | |||
Other income, net | 1 | 1 | 1 | (18) | |||
Total revenues and other income | 202,086 | 215,193 | 325,004 | 342,369 | |||
Oil and gas production | 44,954 | 49,274 | 75,010 | 94,579 | |||
Facilities insurance modifications, net | 2,278 | 1,029 | (17,743) | 9,478 | |||
Exploration expenses | 56 | 34 | 107 | 258 | |||
General and administrative | 6,002 | 4,612 | 11,958 | 9,865 | |||
Depletion, depreciation and amortization | 75,898 | 73,110 | 130,761 | 126,461 | |||
Interest and other financing costs, net | 19,026 | 22,114 | 39,679 | 43,368 | |||
Derivatives, net | 0 | 0 | 0 | 0 | |||
(Gain) loss on equity method investments, net | 0 | 0 | |||||
Other expenses, net | (12,982) | 140,901 | 32,118 | 181,709 | |||
Total costs and expenses | 135,232 | 291,074 | 271,890 | 465,718 | |||
Income (loss) before income taxes | 66,854 | (75,881) | 53,114 | (123,349) | |||
Income tax expense (benefit) | 24,683 | (46,603) | 19,700 | (71,011) | |||
Net income (loss) | 42,171 | (29,278) | 33,414 | (52,338) | |||
Consolidated capital expenditures | 33,496 | 20,727 | 68,463 | 38,829 | |||
Property and equipment, net | 1,643,410 | 1,818,613 | 1,643,410 | 1,818,613 | |||
Total assets | 1,872,202 | 2,110,848 | 1,872,202 | 2,110,848 | |||
Equatorial Guinea | Operating Segments | |||||||
Segment Reporting Information [Line Items] | |||||||
Oil and gas revenue | 64,484 | 69,198 | 153,289 | 192,375 | |||
Other income, net | 0 | 197 | 0 | 340 | |||
Total revenues and other income | 64,484 | 69,395 | 153,289 | 192,715 | |||
Oil and gas production | 16,670 | 11,666 | 39,276 | 37,516 | |||
Facilities insurance modifications, net | 0 | 0 | 0 | 0 | |||
Exploration expenses | 2,472 | 16,211 | 5,643 | 17,080 | |||
General and administrative | 1,539 | 1,022 | 3,584 | 2,007 | |||
Depletion, depreciation and amortization | 16,287 | 24,574 | 39,304 | 78,572 | |||
Interest and other financing costs, net | 0 | (4) | 0 | (5) | |||
Derivatives, net | 0 | 0 | 0 | 0 | |||
(Gain) loss on equity method investments, net | 0 | 0 | |||||
Other expenses, net | (2,583) | (283) | (2,243) | (162) | |||
Total costs and expenses | 34,385 | 53,186 | 85,564 | 135,008 | |||
Income (loss) before income taxes | 30,099 | 16,209 | 67,725 | 57,707 | |||
Income tax expense (benefit) | 11,762 | 16,810 | 27,293 | 41,626 | |||
Net income (loss) | 18,337 | (601) | 40,432 | 16,081 | |||
Consolidated capital expenditures | 6,115 | 18,086 | 21,051 | 24,978 | |||
Property and equipment, net | 460,679 | 9,806 | 460,679 | 9,806 | |||
Total assets | 498,195 | 165,284 | 498,195 | 165,284 | |||
Mauritania And 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 | 2,043 | 2,202 | 8,485 | 5,400 | |||
General and administrative | 1,540 | 941 | 3,827 | 2,232 | |||
Depletion, depreciation and amortization | 15 | 15 | 31 | 31 | |||
Interest and other financing costs, net | (6,524) | (8,341) | (13,317) | (12,263) | |||
Derivatives, net | 0 | 0 | 0 | 0 | |||
(Gain) loss on equity method investments, net | 0 | 0 | |||||
Other expenses, net | 412 | (1) | 641 | 0 | |||
Total costs and expenses | (2,514) | (5,184) | (333) | (4,600) | |||
Income (loss) before income taxes | 2,514 | 5,184 | 333 | 4,600 | |||
Income tax expense (benefit) | 0 | 0 | 0 | 0 | |||
Net income (loss) | 2,514 | 5,184 | 333 | 4,600 | |||
Consolidated capital expenditures | 4,039 | 3,058 | 6,290 | 6,314 | |||
Property and equipment, net | 422,539 | 394,569 | 422,539 | 394,569 | |||
Total assets | 546,454 | 461,536 | 546,454 | 461,536 | |||
U.S. Gulf of Mexico | Operating Segments | |||||||
Segment Reporting Information [Line Items] | |||||||
Oil and gas revenue | 129,364 | 0 | 214,431 | 0 | |||
Other income, net | 124 | 0 | 259 | 0 | |||
Total revenues and other income | 129,488 | 0 | 214,690 | 0 | |||
Oil and gas production | 29,353 | 0 | 56,490 | 0 | |||
Facilities insurance modifications, net | 0 | 0 | 0 | 0 | |||
Exploration expenses | 11,015 | 0 | 22,209 | 0 | |||
General and administrative | 4,893 | 0 | 12,286 | 0 | |||
Depletion, depreciation and amortization | 58,215 | 0 | 97,409 | 0 | |||
Interest and other financing costs, net | 5,642 | 0 | 11,571 | 0 | |||
Derivatives, net | (1,390) | 0 | 30,513 | 0 | |||
(Gain) loss on equity method investments, net | 0 | 0 | |||||
Other expenses, net | 553 | 0 | 2,145 | 0 | |||
Total costs and expenses | 108,281 | 0 | 232,623 | 0 | |||
Income (loss) before income taxes | 21,207 | 0 | (17,933) | 0 | |||
Income tax expense (benefit) | 4,439 | 0 | (3,766) | 0 | |||
Net income (loss) | 16,768 | 0 | (14,167) | 0 | |||
Consolidated capital expenditures | 41,177 | 0 | 87,059 | 0 | |||
Property and equipment, net | 1,281,439 | 0 | 1,281,439 | 0 | |||
Total assets | $ 3,343,917 | $ 0 | $ 3,343,917 | $ 0 |
Business Segment Information -
Business Segment Information - Consolidated Capital Expenditures (Details) - USD ($) $ in Thousands | 3 Months Ended | 6 Months Ended | ||
Jun. 30, 2019 | Jun. 30, 2018 | Jun. 30, 2019 | Jun. 30, 2018 | |
Segment Reporting [Abstract] | ||||
Oil and gas assets | $ 153,268 | $ 92,650 | ||
Other property | 5,230 | 2,815 | ||
Changes in capital accruals | 13,684 | 19,317 | ||
Exploration expense, excluding unsuccessful well costs | 53,150 | 54,020 | ||
Capitalized interest | (14,253) | (14,112) | ||
Other | (166) | 112 | ||
Consolidated capital expenditures | $ 100,685 | $ 97,173 | $ 210,913 | $ 154,802 |