Document and Entity Information
Document and Entity Information - shares | 9 Months Ended | |
Sep. 30, 2016 | Oct. 20, 2016 | |
Document And Entity Information [Abstract] | ||
Trading Symbol | APC | |
Entity Registrant Name | ANADARKO PETROLEUM CORP | |
Entity Central Index Key | 773,910 | |
Document Type | 10-Q | |
Document Period End Date | Sep. 30, 2016 | |
Amendment Flag | false | |
Document Fiscal Year Focus | 2,016 | |
Document Fiscal Period Focus | Q3 | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Large Accelerated Filer | |
Entity Common Stock, Shares Outstanding | 558,900,897 |
CONSOLIDATED STATEMENTS OF INCO
CONSOLIDATED STATEMENTS OF INCOME - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Revenues and Other | ||||
Oil and condensate sales | $ 1,239 | $ 1,229 | $ 3,214 | $ 4,264 |
Natural-gas sales | 435 | 484 | 1,121 | 1,612 |
Natural-gas liquids sales | 227 | 183 | 640 | 644 |
Gathering, processing, and marketing sales | 350 | 334 | 895 | 932 |
Gains (losses) on divestitures and other, net | (358) | (542) | (388) | (807) |
Total | 1,893 | 1,688 | 5,482 | 6,645 |
Costs and Expenses | ||||
Oil and gas operating | 198 | 262 | 608 | 784 |
Oil and gas transportation | 256 | 265 | 744 | 853 |
Exploration | 304 | 1,074 | 506 | 2,260 |
Gathering, processing, and marketing | 291 | 289 | 758 | 798 |
General and administrative | 362 | 303 | 1,116 | 888 |
Depreciation, depletion, and amortization | 1,069 | 1,111 | 3,202 | 3,581 |
Other taxes | 148 | 127 | 422 | 460 |
Impairments | 27 | 758 | 61 | 3,571 |
Other operating expense | 31 | 48 | 54 | 117 |
Total | 2,686 | 4,237 | 7,471 | 13,312 |
Operating Income (Loss) | (793) | (2,549) | (1,989) | (6,667) |
Other (Income) Expense | ||||
Interest expense | 220 | 199 | 657 | 616 |
Loss on early extinguishment of debt | 0 | 0 | 124 | 0 |
(Gains) losses on derivatives, net | 24 | 281 | 634 | 123 |
Other (income) expense, net | (31) | 47 | (86) | 109 |
Total | 214 | 528 | 1,324 | 853 |
Income (Loss) Before Income Taxes | (1,007) | (3,077) | (3,313) | (7,520) |
Income tax expense (benefit) | (260) | (917) | (957) | (2,232) |
Net Income (Loss) | (747) | (2,160) | (2,356) | (5,288) |
Net income (loss) attributable to noncontrolling interests | 83 | 75 | 200 | 154 |
Net Income (Loss) Attributable to Common Stockholders | $ (830) | $ (2,235) | $ (2,556) | $ (5,442) |
Per Common Share | ||||
Net income (loss) attributable to common stockholders—basic | $ (1.61) | $ (4.41) | $ (5) | $ (10.73) |
Net income (loss) attributable to common stockholders—diluted | $ (1.61) | $ (4.41) | $ (5) | $ (10.73) |
Average Number of Common Shares Outstanding—Basic | 517 | 508 | 512 | 508 |
Average Number of Common Shares Outstanding—Diluted | 517 | 508 | 512 | 508 |
Dividends (per common share) | $ 0.05 | $ 0.27 | $ 0.15 | $ 0.81 |
Tronox Litigation [Member] | Judicial Ruling [Member] | ||||
Other (Income) Expense | ||||
Tronox-related contingent loss | $ 0 | $ 0 | $ 0 | $ 5 |
Commodity Contract and Interest Rate Swap [Member] | ||||
Other (Income) Expense | ||||
(Gains) losses on derivatives, net | $ 25 | $ 282 | $ 629 | $ 123 |
CONSOLIDATED STATEMENTS OF COMP
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Statement of Comprehensive Income [Abstract] | ||||
Net Income (Loss) | $ (747) | $ (2,160) | $ (2,356) | $ (5,288) |
Adjustments for derivative instruments | ||||
Reclassification of previously deferred derivative losses to (gains) losses on derivatives, net | 2 | 2 | 7 | 7 |
Income taxes on reclassification of previously deferred derivative losses to (gains) losses on derivatives, net | (1) | (1) | (3) | (3) |
Total adjustments for derivative instruments, net of taxes | 1 | 1 | 4 | 4 |
Adjustments for pension and other postretirement plans | ||||
Net gain (loss) incurred during period | (157) | 0 | (347) | 0 |
Income taxes on net gain (loss) incurred during period | 58 | 0 | 128 | 0 |
Prior service credit (cost) incurred during period | 0 | 0 | (1) | 0 |
Income taxes on prior service credit (cost) incurred during period | 0 | 0 | 1 | 0 |
Amortization of net actuarial (gain) loss to general and administrative expense | 114 | 13 | 156 | 39 |
Income taxes on amortization of net actuarial (gain) loss to general and administrative expense | (43) | (5) | (59) | (14) |
Amortization of net prior service (credit) cost to general and administrative expense | (6) | 1 | (27) | 2 |
Income taxes on amortization of net prior service (credit) cost to general and administrative expense | 2 | (1) | 10 | (1) |
Total adjustments for pension and other postretirement plans, net of taxes | (32) | 8 | (139) | 26 |
Total | (31) | 9 | (135) | 30 |
Comprehensive Income (Loss) | (778) | (2,151) | (2,491) | (5,258) |
Comprehensive income (loss) attributable to noncontrolling interests | 83 | 75 | 200 | 154 |
Comprehensive Income (Loss) Attributable to Common Stockholders | $ (861) | $ (2,226) | $ (2,691) | $ (5,412) |
CONSOLIDATED BALANCE SHEETS
CONSOLIDATED BALANCE SHEETS - USD ($) $ in Millions | Sep. 30, 2016 | Dec. 31, 2015 | |
Current Assets | |||
Cash and cash equivalents ($146 and $100 related to VIEs) | $ 3,980 | $ 939 | |
Accounts receivable (net of allowance of $12 and $11) | |||
Customers ($56 and $81 related to VIEs) | 848 | 652 | |
Others ($68 and $84 related to VIEs) | 743 | 1,817 | |
Other current assets | 347 | 573 | |
Total | 5,918 | 3,981 | |
Properties and Equipment | |||
Cost | 69,089 | 70,683 | |
Less accumulated depreciation, depletion, and amortization | 37,990 | 36,932 | |
Net properties and equipment ($5,037 and $4,859 related to VIEs) | 31,099 | 33,751 | |
Other Assets ($614 and $644 related to VIEs) | 2,203 | 2,268 | |
Goodwill and Other Intangible Assets ($1,230 and $1,220 related to VIEs) | 6,197 | 6,331 | |
Total Assets | 45,417 | 46,331 | |
Current Liabilities | |||
Accounts payable ($185 and $179 related to VIEs) | 1,983 | 2,850 | |
Current asset retirement obligations | 232 | 309 | |
Interest payable | 145 | 247 | |
Other taxes payable ($32 and $18 related to VIEs) | 313 | 318 | |
Accrued expenses | 301 | 424 | |
Short-term debt | 788 | [1] | 32 |
Total | 3,762 | 4,180 | |
Long-term Debt | 15,090 | 15,636 | |
Other Long-term Liabilities | |||
Deferred income taxes | 4,343 | 5,400 | |
Asset retirement obligations ($137 and $127 related to VIEs) | 1,744 | 1,750 | |
Other | 4,566 | 3,908 | |
Total | 10,653 | 11,058 | |
Stockholders' equity | |||
Common stock, par value $0.10 per share (1.0 billion shares authorized, 571.7 million and 528.3 million shares issued) | 57 | 52 | |
Paid-in capital | 11,842 | 9,265 | |
Retained earnings | 2,246 | 4,880 | |
Treasury stock (20.7 million and 20.0 million shares) | (1,027) | (995) | |
Accumulated other comprehensive income (loss) | (518) | (383) | |
Total Stockholders’ Equity | 12,600 | 12,819 | |
Noncontrolling interests | 3,312 | 2,638 | |
Total Equity | 15,912 | 15,457 | |
Total Liabilities and Equity | $ 45,417 | $ 46,331 | |
[1] | Short-term debt includes $750 million of 6.375% Senior Notes due September 2017. In October 2016, the Company provided notice of its intent to redeem the notes prior to year end. |
CONSOLIDATED BALANCE SHEETS (Pa
CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Millions | Sep. 30, 2016 | Dec. 31, 2015 |
Cash and cash equivalents ($146 and $100 related to VIEs) | $ 3,980 | $ 939 |
Allowance for uncollectible accounts | 12 | 11 |
Customers ($56 and $81 related to VIEs) | 848 | 652 |
Others ($68 and $84 related to VIEs) | 743 | 1,817 |
Net properties and equipment ($5,037 and $4,859 related to VIEs) | 31,099 | 33,751 |
Other Assets ($614 and $644 related to VIEs) | 2,203 | 2,268 |
Goodwill and Other Intangible Assets ($1,230 and $1,220 related to VIEs) | 6,197 | 6,331 |
Accounts payable ($185 and $179 related to VIEs) | 1,983 | 2,850 |
Other taxes payable ($32 and $18 related to VIEs) | 313 | 318 |
Asset retirement obligations ($137 and $127 related to VIEs) | $ 1,744 | $ 1,750 |
Common stock, par value per share | $ 0.10 | $ 0.10 |
Common stock, shares authorized | 1,000,000,000 | 1,000,000,000 |
Common stock, shares issued | 571,700,000 | 528,300,000 |
Treasury stock, shares | 20,700,000 | 20,000,000 |
Variable Interest Entity, Primary Beneficiary [Member] | ||
Cash and cash equivalents ($146 and $100 related to VIEs) | $ 146 | $ 100 |
Customers ($56 and $81 related to VIEs) | 56 | 81 |
Others ($68 and $84 related to VIEs) | 68 | 84 |
Net properties and equipment ($5,037 and $4,859 related to VIEs) | 5,037 | 4,859 |
Other Assets ($614 and $644 related to VIEs) | 614 | 644 |
Goodwill and Other Intangible Assets ($1,230 and $1,220 related to VIEs) | 1,230 | 1,220 |
Accounts payable ($185 and $179 related to VIEs) | 185 | 179 |
Other taxes payable ($32 and $18 related to VIEs) | 32 | 18 |
Asset retirement obligations ($137 and $127 related to VIEs) | $ 137 | $ 127 |
CONSOLIDATED STATEMENT OF EQUIT
CONSOLIDATED STATEMENT OF EQUITY - 9 months ended Sep. 30, 2016 - USD ($) $ in Millions | Total | Subsidiary Equity Transactions [Member] | Common Stock [Member] | Paid-in Capital [Member] | Paid-in Capital [Member]Subsidiary Equity Transactions [Member] | Retained Earnings [Member] | Treasury Stock [Member] | Accumulated Other Comprehensive Income (Loss) [Member] | Noncontrolling Interests [Member] | Noncontrolling Interests [Member]Subsidiary Equity Transactions [Member] |
Balance at Dec. 31, 2015 | $ 15,457 | $ 52 | $ 9,265 | $ 4,880 | $ (995) | $ (383) | $ 2,638 | |||
Net income (loss) | (2,356) | (2,556) | 200 | |||||||
Common stock issued | 2,312 | 5 | 2,307 | |||||||
Dividends—common stock | (78) | (78) | ||||||||
Repurchase of common stock | (32) | (32) | ||||||||
Subsidiary equity transactions | $ 1,004 | $ 270 | $ 734 | |||||||
Distributions to noncontrolling interest owners | (260) | (260) | ||||||||
Reclassification of previously deferred derivative losses to (gains) losses on derivatives, net | 4 | 4 | ||||||||
Adjustments for pension and other postretirement plans | (139) | (139) | ||||||||
Balance at Sep. 30, 2016 | $ 15,912 | $ 57 | $ 11,842 | $ 2,246 | $ (1,027) | $ (518) | $ 3,312 |
CONSOLIDATED STATEMENTS OF CASH
CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2016 | Sep. 30, 2015 | |
Cash Flows from Operating Activities | ||
Net income (loss) | $ (2,356) | $ (5,288) |
Adjustments to reconcile net income (loss) to net cash provided by (used in) operating activities | ||
Depreciation, depletion, and amortization | 3,202 | 3,581 |
Deferred income taxes | (1,121) | (2,627) |
Dry hole expense and impairments of unproved properties | 300 | 1,993 |
Impairments | 61 | 3,571 |
(Gains) losses on divestitures, net | 516 | 1,003 |
Loss on early extinguishment of debt | 124 | 0 |
Total (gains) losses on derivatives, net | 634 | 123 |
Operating portion of net cash received (paid) in settlement of derivative instruments | 229 | 251 |
Other | 256 | 219 |
Changes in assets and liabilities | ||
(Increase) decrease in accounts receivable | 810 | 23 |
Increase (decrease) in accounts payable and accrued expenses | (833) | (573) |
Other items, net | 55 | 800 |
Net cash provided by (used in) operating activities | 1,877 | (2,134) |
Cash Flows from Investing Activities | ||
Additions to properties and equipment | (2,618) | (4,861) |
Divestitures of properties and equipment and other assets | 1,281 | 1,248 |
Other, net | 81 | (83) |
Net cash provided by (used in) investing activities | (1,256) | (3,696) |
Cash Flows from Financing Activities | ||
Borrowings, net of issuance costs | 5,840 | 4,810 |
Repayments of debt | (6,023) | (4,024) |
Financing portion of net cash received (paid) for derivative instruments | (639) | (44) |
Increase (decrease) in outstanding checks | (126) | (103) |
Dividends paid | (78) | (415) |
Repurchase of common stock | (32) | (38) |
Issuance of common stock, including tax benefit on share-based compensation awards | 2,188 | 21 |
Distributions to noncontrolling interest owners | (260) | (208) |
Proceeds from conveyance of future hard minerals royalty revenues, net of transaction costs | 413 | 0 |
Payments of future hard minerals royalty revenues conveyed | (25) | 0 |
Net cash provided by (used in) financing activities | 2,421 | 534 |
Effect of Exchange Rate Changes on Cash | (1) | (1) |
Net Increase (Decrease) in Cash and Cash Equivalents | 3,041 | (5,297) |
Cash and Cash Equivalents at Beginning of Period | 939 | 7,369 |
Cash and Cash Equivalents at End of Period | 3,980 | 2,072 |
Subsidiary Equity Transactions [Member] | ||
Cash Flows from Financing Activities | ||
Sale of subsidiary units | 1,163 | 187 |
Equity Component of 7.50% Tangible Equity Units [Member] | ||
Cash Flows from Financing Activities | ||
Sale of subsidiary units | 0 | 348 |
Tronox Litigation [Member] | Judicial Ruling [Member] | ||
Changes in assets and liabilities | ||
Tronox-related contingent liability | $ 0 | $ (5,210) |
Summary of Significant Accounti
Summary of Significant Accounting Policies | 9 Months Ended |
Sep. 30, 2016 | |
Accounting Policies [Abstract] | |
Summary of Significant Accounting Policies | 1. Summary of Significant Accounting Policies General Anadarko Petroleum Corporation is engaged in the exploration, development, production, and marketing of oil, condensate, natural gas, and natural gas liquids (NGLs), and in the marketing of anticipated production of liquefied natural gas (LNG). In addition, the Company engages in the gathering, processing, treating, and transporting of oil, condensate, natural gas, and NGLs. The Company also participates in the hard-minerals business through royalty arrangements. Unless the context otherwise requires, the terms “Anadarko” and “Company” refer to Anadarko Petroleum Corporation and its consolidated subsidiaries. Basis of Presentation The Consolidated Financial Statements have been prepared in conformity with generally accepted accounting principles in the United States. Certain prior-period amounts have been reclassified to conform to the current-year presentation. These Consolidated Financial Statements should be read in conjunction with the Consolidated Financial Statements and accompanying notes included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015 . The Consolidated Financial Statements include the accounts of Anadarko and subsidiaries in which Anadarko holds, directly or indirectly, more than 50% of the voting rights and variable interest entities (VIEs) for which Anadarko is the primary beneficiary. All intercompany transactions have been eliminated. Undivided interests in oil and natural-gas exploration and production joint ventures are consolidated on a proportionate basis. Investments in noncontrolled entities over which Anadarko has the ability to exercise significant influence over operating and financial policies and VIEs for which Anadarko is not the primary beneficiary are accounted for using the equity method. In applying the equity method of accounting, the investments are initially recognized at cost, and subsequently adjusted for the Company’s proportionate share of earnings, losses, and distributions. Other investments are carried at original cost. Investments accounted for using the equity method and cost method are reported as a component of other assets. Recently Adopted Accounting Standards The Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Interest—Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements . These ASUs require capitalized debt issuance costs, except for those related to revolving credit facilities, to be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability, rather than as an asset. The Company adopted these ASUs on January 1, 2016, using a retrospective approach. The adoption resulted in a reclassification that reduced other current assets and short-term debt by $1 million and reduced other assets and long-term debt by $82 million on the Company’s Consolidated Balance Sheet at December 31, 2015. The FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis. The Company adopted this ASU on January 1, 2016. In accordance with the new ASU, Western Gas Equity Partners, LP (WGP) and Western Gas Partners, LP (WES), publicly traded consolidated subsidiaries of the Company, are considered VIEs for which the Company is the primary beneficiary. Prior to adoption of the ASU, WGP and WES were consolidated by the Company under the voting interest model. After adoption, WGP and WES were consolidated by the Company under the variable interest model. While this ASU requires additional financial statement disclosure, it has no impact on the Company’s consolidated results of operations, cash flows, or financial position. See Note 17—Variable Interest Entities . New Accounting Standards Issued But Not Yet Adopted The FASB issued ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory . This ASU requires an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs and eliminates the exception for an intra-entity transfer of an asset other than inventory. This ASU is effective for annual and interim periods beginning in 2018 and is required to be adopted using a modified retrospective approach, with early adoption permitted. The Company is evaluating the impact of the adoption of this ASU on its consolidated financial statements. 1. Summary of Significant Accounting Policies (Continued) The FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments . This ASU provides clarification on how certain cash receipts and cash payments are presented and classified on the statement of cash flows. This ASU is effective for annual and interim periods beginning in 2018 and is required to be adopted using a retrospective approach if practicable, with early adoption permitted. The Company does not expect the adoption of this ASU to have a material impact on its Consolidated Statement of Cash Flows. The FASB issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. This ASU simplifies the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, classification on the statement of cash flows, and accounting for forfeitures. This ASU is effective for annual and interim periods beginning in 2017 with early adoption permitted. The Company will adopt this ASU beginning on January 1, 2017, and does not expect the adoption to have a material impact on its consolidated financial statements. The FASB issued ASU 2016-02, Leases (Topic 842). This ASU requires the lessees to recognize a lease liability and a right-of-use asset for all leases, including operating leases, with a term greater than 12 months on the balance sheet and disclose key information about their leasing transactions. This ASU is effective for annual and interim periods beginning in 2019. The Company is evaluating the impact of the adoption of this ASU on its consolidated financial statements. The FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , which supersedes current revenue recognition requirements and industry-specific guidance. The codification was amended through additional ASUs and, as amended, requires an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration the entity expects to be entitled to in exchange for those goods or services. The Company is required to adopt the new standard in the first quarter of 2018 using one of two retrospective application methods. The Company is continuing to evaluate the provisions of this ASU and has not determined the impact this standard may have on its consolidated financial statements and related disclosures or decided upon the method of adoption. |
Inventories
Inventories | 9 Months Ended |
Sep. 30, 2016 | |
Energy Related Inventory [Abstract] | |
Inventories | 2. Inventories The following summarizes the major classes of inventories included in other current assets: millions September 30, December 31, Oil $ 136 $ 116 Natural gas 35 36 NGLs 83 64 Total inventories $ 254 $ 216 |
Acquisitions, Divestitures, and
Acquisitions, Divestitures, and Assets Held for Sale | 9 Months Ended |
Sep. 30, 2016 | |
Property, Plant and Equipment [Abstract] | |
Acquisitions, Divestitures, and Assets Held for Sale | 3. Acquisitions, Divestitures, and Assets Held for Sale Acquisition In September 2016, the Company entered into an agreement to acquire certain oil and gas assets in the Gulf of Mexico for $2.0 billion using a portion of the net proceeds from the September 2016 issuance of 40.5 million shares of its common stock. The acquisition is expected to close in the fourth quarter of 2016 and is subject to customary closing conditions. See Note 14—Stockholders’ Equity . Divestitures and Assets Held for Sale For the nine months ended September 30, 2016 , the Company received $1.3 billion in net proceeds from divestitures and recognized net losses of $516 million from divestitures and assets held for sale. Divestitures During the nine months ended September 30, 2016 , the Company divested the following U.S. onshore assets: • certain West Texas assets in the oil and gas exploration and production and midstream reporting segments for net proceeds of $223 million and a loss of $50 million • certain East Texas/Louisiana assets in the oil and gas exploration and production reporting segment for net proceeds of $199 million and a net loss of $41 million • certain Wyoming assets in the oil and gas exploration and production reporting segment for net proceeds of $588 million and a loss of $59 million Assets Held for Sale Losses on assets held for sale are included in gains (losses) on divestitures and other, net in the Company’s Consolidated Statements of Income. Certain U.S. onshore assets located primarily in East Texas included in the oil and gas exploration and production and midstream reporting segments satisfied criteria to be considered held for sale during the third quarter of 2016, at which time the Company remeasured these assets to their current fair value using a market approach and Level 2 fair-value measurement and recognized a loss of $355 million . The sale of these assets is expected to close in the fourth quarter of 2016. At September 30, 2016, the Company’s Consolidated Balance Sheet included long-term assets of $1.1 billion , which includes $184 million of goodwill, and long-term liabilities of $44 million associated with assets held for sale. |
Impairments
Impairments | 9 Months Ended |
Sep. 30, 2016 | |
Asset Impairment Charges [Abstract] | |
Impairments | 4. Impairments Impairments of Long-Lived Assets Impairments of long-lived assets are included in impairment expense in the Company’s Consolidated Statements of Income. The following summarizes impairments of long-lived assets and the related post-impairment fair values by segment: Three Months Ended Nine Months Ended millions Impairment Fair Value (1) Impairment Fair Value (1) September 30, 2016 Oil and gas exploration and production Long-lived assets held for use U.S. onshore properties $ 23 $ 32 $ 27 $ 617 Gulf of Mexico properties — — 2 — Cost-method investment (2) — — 2 32 Midstream Long-lived assets held for use 3 — 24 5 Other Long-lived assets held for use 1 — 6 — Total $ 27 $ 32 $ 61 $ 654 September 30, 2015 Oil and gas exploration and production Long-lived assets held for use U.S. onshore properties $ 641 $ 634 $ 2,944 $ 1,904 Gulf of Mexico properties 101 94 126 94 Cost-method investment (2) 1 32 2 32 Midstream Long-lived assets held for use 15 7 499 209 Total $ 758 $ 767 $ 3,571 $ 2,239 __________________________________________________________________ (1) Measured as of the impairment date using the income approach and Level 3 inputs. (2) Represents the after-tax net investment. Impairments during the three and nine months ended September 30, 2016, were primarily related to U.S. onshore oil and gas and midstream properties due to changes in development plans. Impairments during the three months ended September 30, 2015 , were primarily related to U.S. onshore oil and gas properties and an oil and gas property in the Gulf of Mexico, all of which were impaired due to lower forecasted commodity prices. Impairments during the nine months ended September 30, 2015, were primarily related to the Company’s Greater Natural Buttes oil and gas and midstream properties, certain other U.S. onshore oil and gas and midstream properties, and oil and gas properties in the Gulf of Mexico, all of which were impaired due to lower forecasted commodity prices. Impairments of Unproved Properties Impairments of unproved properties are included in exploration expense in the Company’s Consolidated Statements of Income. During the third quarter of 2015, the Company recognized a $109 million impairment of unproved Utica properties resulting from an assignment of mineral interests in settlement of a legal matter. The Company also recognized a $935 million impairment of unproved Greater Natural Buttes properties during the nine months ended September 30, 2015, as a result of lower commodity prices. 4. Impairments (Continued) Potential for Future Impairments At September 30, 2016, the Company’s estimates of undiscounted future cash flows attributable to a certain international asset group with a net book value of approximately $1.4 billion , and certain U.S. onshore asset groups with a combined net book value of approximately $1.1 billion , indicated that the carrying amounts were expected to be recovered; however, these asset groups may be at risk for impairment if the estimates of future cash flows decline. The Company estimates that a 10% decline in oil prices (with all other assumptions unchanged) could result in a non-cash impairment in excess of $600 million for the international asset group, and a 10% decline in natural-gas prices (with all other assumptions unchanged) could result in non-cash impairments in excess of $400 million for the U.S. onshore asset groups. It is also reasonably possible that prolonged low or further declines in commodity prices, further changes to the Company’s drilling plans in response to lower prices, or increases in drilling or operating costs could result in other additional impairments. |
Suspended Exploratory Well Cost
Suspended Exploratory Well Costs | 9 Months Ended |
Sep. 30, 2016 | |
Capitalized Exploratory Well Costs [Abstract] | |
Suspended Exploratory Well Costs | 5. Suspended Exploratory Well Costs The Company’s suspended exploratory well costs were $1.2 billion at September 30, 2016, and $1.1 billion at December 31, 2015 . The increase in suspended exploratory well costs during 2016 is primarily related to the capitalization of costs associated with appraisal activities in Côte d’Ivoire. Projects with suspended exploratory well costs are those identified by management as exhibiting sufficient quantities of hydrocarbons to justify potential development or where it is reasonably possible that the well can be utilized in the development of the project and when management is actively pursuing efforts to assess whether reserves can be attributed to these projects. If additional information becomes available that raises substantial doubt as to the economic or operational viability of any of these projects, the associated costs will be expensed at that time. During the nine months ended September 30, 2016 , $142 million of suspended exploratory well costs previously capitalized for greater than one year at December 31, 2015, were charged to exploration expense and primarily related to the following: • $64 million related to a Shenandoah well in the Gulf of Mexico was expensed as it was no longer reasonably possible that the wellbore would be used in the development of the project if a final investment decision is reached • $38 million related to the Orca-4 well in Mozambique was expensed after additional reservoir analysis and the determination that the well was not associated with the first three Orca wells • $33 million related to the Tubarão Tigre discovery was expensed based on the outlook for development viability, given current commodity market conditions and the complexity introduced by the depth and characteristics of the reservoir Costs of $21 million previously capitalized for less than one year at December 31, 2015, related to the Tubarão Tigre discovery discussed above, were also charged to exploration expense. |
Derivative Instruments
Derivative Instruments | 9 Months Ended |
Sep. 30, 2016 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivative Instruments | 6. Derivative Instruments Objective and Strategy The Company uses derivative instruments to manage its exposure to cash-flow variability from commodity-price and interest-rate risks. Futures, swaps, and options are used to manage exposure to commodity-price risk inherent in the Company’s oil and natural-gas production and natural-gas processing operations (Oil and Natural-Gas Production/Processing Derivative Activities). Futures contracts and commodity-price swap agreements are used to fix the price of expected future oil and natural-gas sales at major industry trading locations such as Cushing, Oklahoma or Sullom Voe, Scotland for oil and Henry Hub, Louisiana for natural gas. Basis swaps are periodically used to fix or float the price differential between product prices at one market location versus another. Options are used to establish a floor price, a ceiling price, or a floor and a ceiling price (collar) for expected future oil and natural-gas sales. Derivative instruments are also used to manage commodity-price risk inherent in customer price requirements and to fix margins on the future sale of natural gas and NGLs from the Company’s leased storage facilities (Marketing and Trading Derivative Activities). Interest-rate swaps are used to fix or float interest rates on existing or anticipated indebtedness. The purpose of these instruments is to manage the Company’s existing or anticipated exposure to interest-rate changes. The fair value of the Company’s current interest-rate swap portfolio is subject to changes in interest rates. The Company does not apply hedge accounting to any of its derivative instruments. As a result, gains and losses associated with derivative instruments are recognized currently in earnings. Net derivative losses attributable to derivatives previously subject to hedge accounting reside in accumulated other comprehensive income (loss) and are reclassified to earnings as the transactions to which the derivatives relate are recognized in earnings. See Note 15—Accumulated Other Comprehensive Income (Loss) . 6. Derivative Instruments (Continued) Oil and Natural-Gas Production/Processing Derivative Activities The oil prices listed below are a combination of New York Mercantile Exchange (NYMEX) West Texas Intermediate and Intercontinental Exchange, Inc. (ICE) Brent Blend prices. The natural-gas prices listed below are NYMEX Henry Hub prices. The NGLs prices listed below are Oil Price Information Services prices. The following is a summary of the Company’s derivative instruments related to oil and natural-gas production/processing derivative activities at September 30, 2016 : 2016 Settlement 2017 Settlement 2018 Settlement Oil Three-Way Collars (MBbls/d) 83 — — Average price per barrel Ceiling sold price (call) $ 63.82 $ — $ — Floor purchased price (put) $ 54.46 $ — $ — Floor sold price (put) $ 42.77 $ — $ — Natural Gas Three-Way Collars (thousand MMBtu/d) — 682 250 Average price per MMBtu Ceiling sold price (call) $ — $ 3.60 $ 3.54 Floor purchased price (put) $ — $ 2.75 $ 2.75 Floor sold price (put) $ — $ 2.00 $ 2.00 Fixed-Price Contracts (thousand MMBtu/d) — 37 — Average price per MMBtu $ — $ 3.14 $ — NGLs Fixed-Price Contracts (MBbls/d) — 2 — Average price per barrel $ — $ 15.84 $ — __________________________________________________________________ MBbls/d—thousand barrels per day MMBtu/d—million British thermal units per day MMBtu—million British thermal units A three-way collar is a combination of three options: a sold call, a purchased put, and a sold put. The sold call establishes the maximum price that the Company will receive for the contracted commodity volumes. The purchased put establishes the minimum price that the Company will receive for the contracted volumes unless the market price for the commodity falls below the sold put strike price, at which point the minimum price equals the reference price (e.g., NYMEX) plus the excess of the purchased put strike price over the sold put strike price. Marketing and Trading Derivative Activities The Company had financial derivative transactions with notional volumes of natural gas totaling 5 billion cubic feet (Bcf) at September 30, 2016 , and 8 Bcf at December 31, 2015 , that were entered into to mitigate commodity-price risk related to fixed-price purchase and sales contracts and storage activity. 6. Derivative Instruments (Continued) Interest-Rate Derivatives Anadarko has outstanding interest-rate swap contracts to manage interest-rate risk associated with anticipated debt issuances. The Company has locked in a fixed interest rate in exchange for a floating interest rate indexed to the three-month London Interbank Offered Rate (LIBOR). In February 2016, in exchange for amended terms with certain counterparties, the Company modified the mandatory termination dates from 2021 to 2018 and, in some cases, the related fixed interest rates on interest-rate swaps with an aggregate notional principal amount of $500 million . Additionally, an interest-rate swap agreement was settled for a cash payment of $193 million in March 2016, and interest-rate swap agreements were settled for total cash payments of $73 million in September 2016. Anadarko does not expect additional net cash outlays in 2016 related to interest-rate derivative settlements . At September 30, 2016 , the Company had outstanding interest-rate swaps with a notional amount of $1.6 billion due prior to or at September 2021 that will manage interest-rate risk associated with the potential refinancing of the Company’s $900 million Senior Notes due 2019 and the Zero-Coupon Senior Notes due 2036 (Zero Coupons), should the Zero Coupons be put to the Company prior to the swap termination dates. None of the Zero Coupons (accreted value of $839 million ) were put to the Company in October 2016 . See Note 8—Debt and Interest Expense . Depending on market conditions, liability-management actions, or other factors, the Company may enter into offsetting interest-rate swap positions or settle or amend certain or all of the currently outstanding interest-rate swaps. Derivative settlements and collateralization are classified as cash flows from operating activities unless the derivatives contain an other-than-insignificant financing element, in which case the settlements and collateralization are classified as cash flows from financing activities. As a result of prior extensions of reference-period start dates without settlement of the related interest-rate derivative obligations, the interest-rate derivatives in the Company’s portfolio contain an other-than-insignificant financing element, and therefore, any settlements or collateralization related to these extended interest-rate derivatives are classified as cash flows from financing activities. The Company had the following outstanding interest-rate swaps at September 30, 2016 : millions except percentages Mandatory Weighted-Average Notional Principal Amount Reference Period Termination Date Interest Rate $ 500 September 2016 – 2046 September 2018 6.559% $ 300 September 2016 – 2046 September 2020 6.509% $ 450 September 2017 – 2047 September 2018 6.445% $ 100 September 2017 – 2047 September 2020 6.891% $ 250 September 2017 – 2047 September 2021 6.570% 6. Derivative Instruments (Continued) Effect of Derivative Instruments — Balance Sheet The following summarizes the fair value of the Company’s derivative instruments: Gross Derivative Assets Gross Derivative Liabilities millions September 30, December 31, September 30, December 31, Balance Sheet Classification 2016 2015 2016 2015 Commodity derivatives Other current assets $ 65 $ 462 $ (8 ) $ (177 ) Other assets 29 8 (2 ) — Accrued expenses 2 — (18 ) (3 ) Other liabilities 3 — (22 ) — 99 470 (50 ) (180 ) Interest-rate derivatives Other current assets 4 2 — — Other assets 18 54 — — Accrued expenses — — (48 ) (54 ) Other liabilities — — (1,806 ) (1,488 ) 22 56 (1,854 ) (1,542 ) Total derivatives $ 121 $ 526 $ (1,904 ) $ (1,722 ) Effect of Derivative Instruments — Statement of Income The following summarizes gains and losses related to derivative instruments: millions Three Months Ended Nine Months Ended Classification of (Gain) Loss Recognized 2016 2015 2016 2015 Commodity derivatives Gathering, processing, and marketing sales (1) $ (1 ) $ (1 ) $ 5 $ — (Gains) losses on derivatives, net (59 ) (125 ) 7 (177 ) Interest-rate derivatives (Gains) losses on derivatives, net 84 407 622 300 Total (gains) losses on derivatives, net $ 24 $ 281 $ 634 $ 123 __________________________________________________________________ (1) Represents the effect of Marketing and Trading Derivative Activities. 6. Derivative Instruments (Continued) Credit-Risk Considerations The financial integrity of exchange-traded contracts, which are subject to nominal credit risk, is assured by NYMEX or ICE through systems of financial safeguards and transaction guarantees. Over-the-counter traded swaps, options, and futures contracts expose the Company to counterparty credit risk. The Company monitors the creditworthiness of its counterparties, establishes credit limits according to the Company’s credit policies and guidelines, and assesses the impact on the fair value of its counterparties’ creditworthiness. The Company has the ability to require cash collateral or letters of credit to mitigate its credit-risk exposure. The Company has netting agreements with financial institutions that permit net settlement of gross commodity derivative assets against gross commodity derivative liabilities, and routinely exercises its contractual right to offset gains and losses when settling with derivative counterparties. In addition, the Company has setoff agreements with certain financial institutions that may be exercised in the event of default and provide for contract termination and net settlement across derivative types. At September 30, 2016 , $52 million of the Company’s $1.904 billion gross derivative liability balance, and at December 31, 2015 , $347 million of the Company’s $1.722 billion gross derivative liability balance, would have been eligible for setoff against the Company’s gross derivative asset balance in the event of default. Other than in the event of default, the Company does not net settle across derivative types. The Company’s derivative instruments are subject to individually negotiated credit provisions that may require collateral of cash or letters of credit depending on the derivative’s portfolio valuation versus negotiated credit thresholds. These credit thresholds may also require full or partial collateralization or immediate settlement of the Company’s obligations if certain credit-risk-related provisions are triggered, such as if the Company’s credit rating from major credit rating agencies declines to a level that is below investment grade. In February 2016, Moody’s Investors Service (Moody’s) downgraded the Company’s long-term debt credit rating from “Baa2” to “Ba1,” which is below investment grade. The downgrade triggered credit-risk-related features with certain derivative counterparties and required the Company to post collateral under its derivative instruments. During the third quarter of 2016, Anadarko paid a fee in connection with the negotiated increase of a credit threshold for an interest-rate derivative with an other-than-insignificant financing element. As a result of the increased credit threshold, $200 million of collateral was returned to the Company. No counterparties have requested termination or full settlement of derivative positions. The aggregate fair value of derivative instruments with credit-risk-related contingent features for which a net liability position existed was $1.4 billion (net of $422 million of collateral) at September 30, 2016 , and $1.3 billion (net of $58 million of collateral) at December 31, 2015 . 6. Derivative Instruments (Continued) Fair Value Fair value of futures contracts is based on unadjusted quoted prices in active markets for identical assets or liabilities, which represent Level 1 inputs. Valuations of physical-delivery purchase and sale agreements, over-the-counter financial swaps, and commodity option collars are based on similar transactions observable in active markets and industry-standard models that primarily rely on market-observable inputs. Inputs used to estimate fair value in industry-standard models are categorized as Level 2 inputs because substantially all assumptions and inputs are observable in active markets throughout the full term of the instruments. Inputs used to estimate the fair value of swaps and options include market-price curves; contract terms and prices; credit-risk adjustments; and, for Black-Scholes option valuations, discount factors and implied market volatility. The following summarizes the fair value of the Company’s derivative assets and liabilities by input level within the fair-value hierarchy: millions September 30, 2016 Level 1 Level 2 Level 3 Netting (1) Collateral Total Assets Commodity derivatives $ — $ 99 $ — $ (14 ) $ — $ 85 Interest-rate derivatives — 22 — — — 22 Total derivative assets $ — $ 121 $ — $ (14 ) $ — $ 107 Liabilities Commodity derivatives $ (1 ) $ (49 ) $ — $ 14 $ 2 $ (34 ) Interest-rate derivatives — (1,854 ) — — 422 (1,432 ) Total derivative liabilities $ (1 ) $ (1,903 ) $ — $ 14 $ 424 $ (1,466 ) December 31, 2015 Assets Commodity derivatives $ 10 $ 460 $ — $ (178 ) $ (8 ) $ 284 Interest-rate derivatives — 56 — — — 56 Total derivative assets $ 10 $ 516 $ — $ (178 ) $ (8 ) $ 340 Liabilities Commodity derivatives $ (1 ) $ (179 ) $ — $ 178 $ — $ (2 ) Interest-rate derivatives — (1,542 ) — — 58 (1,484 ) Total derivative liabilities $ (1 ) $ (1,721 ) $ — $ 178 $ 58 $ (1,486 ) __________________________________________________________________ (1) Represents the impact of netting commodity derivative assets and liabilities with counterparties where the Company has the contractual right and intends to net settle. |
Tangible Equity Units
Tangible Equity Units | 9 Months Ended |
Sep. 30, 2016 | |
Tangible Equity Units [Abstract] | |
Tangible Equity Units | 7. Tangible Equity Units In June 2015, the Company issued 9.2 million 7.50% tangible equity units (TEUs) at a stated amount of $50.00 per TEU for net proceeds of $445 million . Each TEU is comprised of a prepaid equity purchase contract for common units of WGP and a senior amortizing note. Subsequent to issuance, each TEU may be legally separated into the two components. The prepaid equity purchase contract is considered a freestanding financial instrument, indexed to WGP common units, and meets the conditions for equity classification. The prepaid equity purchase contracts are included in noncontrolling interests, net of issuance costs, and the senior amortizing notes are included in short-term debt and long-term debt on the Company’s Consolidated Balance Sheets. Equity Component Unless settled earlier at the holder’s option, each purchase contract has a mandatory settlement date of June 7, 2018 . Anadarko has a right to elect to issue and deliver shares of Anadarko Petroleum Corporation common stock (APC shares) in lieu of delivering WGP common units at settlement. The Company will deliver not more than 0.8591 WGP common units and not less than 0.7159 WGP common units (or a computed number of APC shares) per TEU on the settlement date, subject to adjustment, at the settlement rate based upon the applicable market value of WGP common units (or APC shares). Debt Component Each senior amortizing note has an initial principal amount of $10.95 and bears interest at 1.50% per year. On September 7, 2015 , Anadarko began paying equal quarterly cash installments of $0.9375 per amortizing note (except for the September 7, 2015 installment payment, which was $0.9063 per amortizing note). The payments constitute a payment of interest and partial repayment of principal, with the aggregate per-year payments of principal and interest equating to a 7.50% cash payment with respect to each TEU. The senior amortizing notes have a final installment payment date of June 7, 2018 , and are senior unsecured obligations of the Company. |
Debt and Interest Expense
Debt and Interest Expense | 9 Months Ended |
Sep. 30, 2016 | |
Debt Disclosure [Abstract] | |
Debt and Interest Expense | 8. Debt and Interest Expense Debt Activity The following summarizes the Company’s borrowing activity, after eliminating the effect of intercompany transactions, during the nine months ended September 30, 2016 : Carrying Value millions WES WGP (1) Anadarko (2) Anadarko Consolidated Description Balance at December 31, 2015 $ 2,691 $ — $ 12,957 $ 15,648 Issuances — — 794 794 4.850% Senior Notes due 2021 — — 1,088 1,088 5.550% Senior Notes due 2026 — — 1,088 1,088 6.600% Senior Notes due 2046 495 — — 495 WES 4.650% Senior Notes due 2026 Borrowings — — 1,750 1,750 364-Day Facility 600 — — 600 WES RCF — 28 — 28 WGP RCF Repayments — — (1,749 ) (1,749 ) 5.950% Senior Notes due 2016 — — (1,245 ) (1,245 ) 6.375% Senior Notes due 2017 — — (1,750 ) (1,750 ) 364-Day Facility (880 ) — — (880 ) WES RCF — — (250 ) (250 ) Commercial paper notes, net — — (25 ) (25 ) TEUs - senior amortizing notes Other, net 1 — 40 41 Amortization of discounts, premiums, and debt issuance costs Balance at September 30, 2016 $ 2,907 $ 28 $ 12,698 $ 15,633 __________________________________________________________________ (1) Excludes WES. (2) Excludes WES and WGP. During the second quarter of 2016, the Company used proceeds from its $3.0 billion March 2016 Senior Notes issuances to purchase and retire $1.250 billion of its $2.0 billion 6.375% Senior Notes due September 2017 pursuant to a tender offer and to redeem its $1.750 billion 5.950% Senior Notes due September 2016 . The Company recognized a loss of $124 million for the early retirement and redemption of these senior notes, which included $114 million of premiums paid. 8. Debt and Interest Expense (Continued) Debt The following summarizes the Company’s outstanding debt, including capital lease obligations, after eliminating the effect of intercompany transactions: millions WES WGP (1) Anadarko (2) Anadarko Consolidated September 30, 2016 Total borrowings at face value $ 2,940 $ 28 $ 14,317 $ 17,285 Net unamortized discounts, premiums, and debt issuance costs (3) (33 ) — (1,619 ) (1,652 ) Total borrowings (4) 2,907 28 12,698 15,633 Capital lease obligations — — 245 245 Less short-term debt (5) — — 788 788 Total long-term debt $ 2,907 $ 28 $ 12,155 $ 15,090 December 31, 2015 Total borrowings at face value $ 2,720 $ — $ 14,592 $ 17,312 Net unamortized discounts, premiums, and debt issuance costs (3) (29 ) — (1,635 ) (1,664 ) Total borrowings (4) 2,691 — 12,957 15,648 Capital lease obligations — — 20 20 Less short-term debt — — 32 32 Total long-term debt $ 2,691 $ — $ 12,945 $ 15,636 __________________________________________________________________ (1) Excludes WES. (2) Excludes WES and WGP. (3) Unamortized discounts, premiums, and debt issuance costs are amortized over the term of the related debt. Debt issuance costs related to revolving credit facilities are included in other current assets and other assets on the Company’s Consolidated Balance Sheets. (4) The Company’s outstanding borrowings, except for borrowings under the WGP revolving credit facility, are senior unsecured. (5) Short-term debt includes $750 million of 6.375% Senior Notes due September 2017 . In October 2016, the Company provided notice of its intent to redeem the notes prior to year end. Anadarko’s Zero Coupons can be put to the Company in October of each year, in whole or in part, for the then-accreted value of the outstanding Zero Coupons. None of the Zero Coupons (accreted value of $839 million ) were put to the Company in October 2016 . Fair Value The Company uses a market approach to determine the fair value of its fixed-rate debt using observable market data, which results in a Level 2 fair-value measurement. The carrying amount of floating-rate debt approximates fair value as the interest rates are variable and reflective of market rates. The estimated fair value of the Company’s total borrowings was $17.6 billion at September 30, 2016, and $15.7 billion at December 31, 2015 . 8. Debt and Interest Expense (Continued) Anadarko Revolving Credit Facilities and Commercial Paper Program Anadarko has a $3.0 billion five -year senior unsecured revolving credit facility maturing in January 2021 (Five-Year Facility). In addition, the Company has a $2.0 billion 364 -day senior unsecured revolving credit facility ( 364 -Day Facility) that will mature in January 2017 . At September 30, 2016, the Company had no outstanding borrowings under the Five-Year Facility or the 364-Day Facility and was in compliance with all related covenants. In January 2015, the Company initiated a commercial paper program, which allows for a maximum of $3.0 billion of unsecured commercial paper notes and is supported by the Five-Year Facility. The maturities of the commercial paper notes may vary, but may not exceed 397 days . In February 2016, Moody’s downgraded the Company’s commercial paper program credit rating, which eliminated the Company’s access to the commercial paper market. The Company has not issued commercial paper notes since the downgrade and had no outstanding borrowings under the commercial paper program at September 30, 2016 . WES and WGP Borrowings In July 2016, WES completed a public offering of $500 million aggregate principal amount of 4.650% Senior Notes due July 2026 . Net proceeds were used to repay a portion of the amount outstanding under WES’s $1.2 billion five -year senior unsecured revolving credit facility maturing in February 2019 (WES RCF), which is expandable to $1.5 billion . At September 30, 2016, WES had outstanding borrowings under its RCF of $20 million at an interest rate of 1.82% , had outstanding letters of credit of $5 million , and had available borrowing capacity of $1.18 billion . At September 30, 2016, WES was in compliance with all related covenants. In March 2016, WGP entered into a $250 million three -year senior secured revolving credit facility maturing in March 2019 (WGP RCF), which is expandable to $500 million , subject to receiving increased or new commitments from lenders and the satisfaction of certain other conditions. Obligations under the WGP RCF are secured by a first priority lien on all of WGP’s assets (not including the consolidated assets of WES), as well as all equity interests owned by WGP. Borrowings under the WGP RCF bear interest at LIBOR (with a floor of 0% ), plus applicable margins ranging from 2.00% to 2.75% depending on WGP’s consolidated leverage ratio, or at a base rate equal to the greatest of (i) the prime rate, (ii) the federal funds rate plus 0.50% , or (iii) LIBOR plus 1.00% , in each case plus applicable margins ranging from 1.00% to 1.75% based upon WGP’s consolidated leverage ratio. At September 30, 2016, WGP had outstanding borrowings under its RCF of $28 million at an interest rate of 2.53% , had available borrowing capacity of $222 million , and was in compliance with all related covenants. In October 2016, WES completed a public offering of $200 million aggregate principal amount of 5.450% Senior Notes due April 2044 . Net proceeds were used to repay amounts outstanding under the WES RCF and the remaining proceeds will be used for general partnership purposes, including capital expenditures. 8. Debt and Interest Expense (Continued) Capital Lease Obligations Construction of a floating production, storage and offloading unit (FPSO) for the Company’s Tweneboa/Enyenra/Ntomme (TEN) field operations in Ghana commenced in 2013. The Company recognized an asset and related obligation for its approximate 19% nonoperated working interest share during the construction period. Upon completion of the construction during the third quarter of 2016, the Company reported the asset and related obligation as a capital lease of $225 million for the Company’s share of the fair value of the FPSO. The FPSO lease provides for an initial term of 10 years with annual renewal periods for an additional 10 years , annual purchase options that decrease over time, and no residual value guarantees. The capital lease asset will be depreciated over the estimated proved reserves of the TEN field using the unit-of-production method, with the associated depreciation included in depreciation, depletion, and amortization (DD&A) in the Company’s Consolidated Statement of Income. The capital lease obligation will be accreted to the present value of the minimum lease payments using the effective interest method. The Company will make the first payment under the FPSO capital lease in the fourth quarter of 2016. At September 30, 2016, future minimum lease payments due under capital leases were: millions 2016 $ 16 2017 42 2018 42 2019 42 2020 42 Remaining years 433 Total future minimum lease payments $ 617 Less portion representing imputed interest 372 Capital lease obligations $ 245 Interest Expense The following summarizes interest expense: Three Months Ended Nine Months Ended millions 2016 2015 2016 2015 Debt and other $ 251 $ 245 $ 768 $ 743 Capitalized interest (31 ) (46 ) (111 ) (127 ) Total interest expense $ 220 $ 199 $ 657 $ 616 |
Income Taxes
Income Taxes | 9 Months Ended |
Sep. 30, 2016 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | 9. Income Taxes The following summarizes income tax expense (benefit) and effective tax rates: Three Months Ended Nine Months Ended millions except percentages 2016 2015 2016 2015 Income tax expense (benefit) $ (260 ) $ (917 ) $ (957 ) $ (2,232 ) Income (loss) before income taxes (1,007 ) (3,077 ) (3,313 ) (7,520 ) Effective tax rate 26 % 30 % 29 % 30 % The Company reported a loss before income taxes for the three and nine months ended September 30, 2016 and 2015 . As a result, items that ordinarily increase or decrease the tax rate will have the opposite effect. The decrease from the 35% U.S. federal statutory rate for the three and nine months ended September 30, 2016 , was primarily attributable to the following decreases: • non-deductible Algerian exceptional profits tax for Algerian income tax purposes • tax impact from foreign operations • non-deductible goodwill related to divestitures • adjustments to deferred tax balances • net changes in uncertain tax positions These decreases were partially offset by the following increases: • state taxes, net of federal benefit • income attributable to noncontrolling interest The decrease from the 35% U.S. federal statutory rate for the three and nine months ended September 30, 2015, was primarily attributable to non-deductible Algerian exceptional profits tax for Algerian income tax purposes and the tax impact from foreign operations. |
Conveyance of Future Hard Miner
Conveyance of Future Hard Minerals Royalty Revenues | 9 Months Ended |
Sep. 30, 2016 | |
Deferred Revenue Disclosure [Abstract] | |
Conveyance Of Future Hard Minerals Royalty Revenues | 10. Conveyance of Future Hard Minerals Royalty Revenues During the first quarter of 2016, the Company conveyed a limited-term nonparticipating royalty interest in certain of its coal and trona leases to a third party for $413 million , net of transaction costs. Such conveyance entitles the third party to receive up to $553 million in future royalty revenue over a period of not less than 10 years and not greater than 15 years. Additionally, such third party is entitled to receive 3% of the aggregate royalties earned during the first 10 years between $800 million and $900 million and 4% of the aggregate royalties earned during the first 10 years that exceed $900 million . Generally, such third party relies solely on the royalty payments to recover its investment and, as such, has the risk of the royalties not being sufficient to recover its investment over the term of the conveyance. Proceeds from this transaction were accounted for as deferred revenues and are included in accrued expenses and other long-term liabilities on the Company’s Consolidated Balance Sheet. The deferred revenues will be amortized to other revenues, included in gains (losses) on divestitures and other, net on a unit-of-revenue basis over the term of the agreement. Net proceeds received from the third party were reported in financing activities on the Company’s Consolidated Statement of Cash Flows. Semi-annual payments to the third party are scheduled on March 1 and September 1 of each year through March 1, 2026. The specified future amounts that the Company expects to pay and the payment timing are subject to change based upon the actual royalties received by the Company during the term of the conveyance. Royalties received by Anadarko under this agreement are reported in operating activities on the Company’s Consolidated Statement of Cash Flows. The semi-annual payments to the third party, up to the aggregate amount of the $413 million net proceeds the Company received for the conveyance in the first quarter of 2016, are reported in financing activities on the Company’s Consolidated Statement of Cash Flows. Any additional payments to the third party are reported in operating activities on the Company’s Consolidated Statement of Cash Flows to offset the royalties received. During the nine months ended September 30, 2016 , the Company amortized $27 million of deferred revenues as a result of this agreement. The Company made the first semi-annual payment of $25 million for royalties in September 2016. The following summarizes the remaining amounts that the Company expects to pay, prior to the potential 3% to 4% of any excess described above: millions 2017 $ 50 2018 50 2019 52 2020 56 2021 57 Later years 263 Total $ 528 |
Contingencies
Contingencies | 9 Months Ended |
Sep. 30, 2016 | |
Contingencies Disclosure [Abstract] | |
Contingencies | 11. Contingencies Litigation The following is a discussion of any material developments in previously reported contingencies and any other material matters that have arisen since the filing of the Company’s Annual Report on Form 10-K for the year ended December 31, 2015 . Deepwater Horizon Events In April 2010, the Macondo well in the Gulf of Mexico blew out and an explosion occurred on the Deepwater Horizon drilling rig, resulting in an oil spill. The well was operated by BP Exploration and Production Inc. (BP) and Anadarko held a 25% nonoperated interest. In October 2011, the Company and BP entered into a settlement agreement relating to the Deepwater Horizon events (Settlement Agreement). Pursuant to the Settlement Agreement, the Company is fully indemnified by BP against all claims and damages arising under the Oil Pollution Act of 1990 (OPA), claims for natural resource damages (NRD) and assessment costs, and any claims arising under the Operating Agreement with BP. Numerous Deepwater Horizon event-related civil lawsuits were filed against BP and other parties, including the Company. Generally, the plaintiffs sought actual damages, punitive damages, declaratory judgment, and/or injunctive relief. This litigation was consolidated into a federal Multidistrict Litigation (MDL) action pending before Judge Carl Barbier in the U.S. District Court for the Eastern District of Louisiana in New Orleans, Louisiana (Louisiana District Court). BP Consent Decree In July 2015, BP announced a settlement agreement in principle with the U.S. Department of Justice (DOJ) and certain states and local government entities regarding essentially all of the outstanding claims against BP related to the Deepwater Horizon event (BP Settlement) and, in October 2015, lodged a proposed consent decree with the Louisiana District Court. In April 2016, the Louisiana District Court approved the consent decree. As a result of the BP Settlement and approval of the consent decree, all liability relating to OPA-related environmental costs was resolved and all NRD claims and claims by the United States and the Gulf states impacted by the event relating to the MDL action were dismissed. For any remaining claims relating to the MDL action, the Company is fully indemnified by BP against any losses pursuant to the Settlement Agreement. For additional disclosure related to the Deepwater Horizon events, see Note 15 — Contingencies — Deepwater Horizon Events in the Notes to Consolidated Financial Statements included in the Company’s Annual Report on Form 10-K for the year ended December 31, 2015. Penalties and Fines In December 2010, the DOJ, on behalf of the United States, filed a civil lawsuit in the Louisiana District Court against several parties, including the Company, seeking an assessment of civil penalties under the Clean Water Act (CWA) in an amount to be determined by the Louisiana District Court. After previously finding that Anadarko, as a nonoperating investor in the Macondo well, was not culpable with respect to the Deepwater Horizon events, the Louisiana District Court found Anadarko liable for civil penalties under Section 311 of the CWA as a working-interest owner in the Macondo well and entered a judgment of $159.5 million in December 2015. Neither party appealed the decision and the Company paid the penalty in the first quarter of 2016. |
Restructuring Charges
Restructuring Charges | 9 Months Ended |
Sep. 30, 2016 | |
Restructuring and Related Activities [Abstract] | |
Restructuring Charges | 12. Restructuring Charges In the first quarter of 2016, the Company initiated a workforce reduction program to align the size and composition of its workforce with its expected future operating and capital plans. Employee notifications related to the workforce reduction program were completed by June 30, 2016. All restructuring charges will be recognized in 2016, with the exception of approximately $17 million of expense for retirement benefits expected to be recognized in 2017. The following summarizes the total expected restructuring charges and the amounts expensed during the three and nine months ended September 30, 2016, which are included in general and administrative expenses in the Company’s Consolidated Statements of Income: millions Total Expected Costs Three Months Ended Nine Months Ended September 30, 2016 Costs by category Cash severance $ 154 $ 5 $ 151 Retirement benefits (1) 219 102 178 Share-based compensation 37 5 34 Total $ 410 $ 112 $ 363 __________________________________________________________________ (1) Includes termination benefits, curtailments, and settlements. See Note 13—Pension Plans and Other Postretirement Benefits . The following summarizes the changes in the cash severance-related liability included in accounts payable on the Company’s Consolidated Balance Sheet: millions 2016 Balance at January 1 $ — Accruals 151 Payments (141 ) Balance at September 30 $ 10 |
Pension Plans and Other Postret
Pension Plans and Other Postretirement Benefits | 9 Months Ended |
Sep. 30, 2016 | |
Compensation and Retirement Disclosure [Abstract] | |
Pension Plans and Other Postretirement Benefits | 13. Pension Plans and Other Postretirement Benefits The Company has contributory and non-contributory defined-benefit pension plans, which include both qualified and supplemental plans. The Company also provides certain health care and life insurance benefits for certain retired employees. Retiree health care benefits are funded by contributions from the retiree and, in certain circumstances, contributions from the Company. The Company’s retiree life insurance plan is noncontributory. The following summarizes the Company’s pension and other postretirement benefit cost: Pension Benefits Other Benefits millions 2016 2015 2016 2015 Three Months Ended September 30 Service cost $ 24 $ 30 $ 1 $ 3 Interest cost 24 25 3 3 Expected return on plan assets (24 ) (27 ) — — Amortization of net actuarial loss (gain) 12 13 — — Amortization of net prior service cost (credit) — — (6 ) 1 Settlement expense 102 — — — Net periodic benefit cost $ 138 $ 41 $ (2 ) $ 7 Nine Months Ended September 30 Service cost $ 73 $ 89 $ 2 $ 8 Interest cost 73 76 9 11 Expected return on plan assets (75 ) (82 ) — — Amortization of net actuarial loss (gain) 30 39 — — Amortization of net prior service cost (credit) — — (18 ) 2 Settlement expense 126 — — — Termination benefits expense 44 — — — Curtailment expense 8 — — — Net periodic benefit cost $ 279 $ 122 $ (7 ) $ 21 The Company’s workforce reduction program resulted in remeasurements of its pension and other postretirement plans during 2016. The remeasurements of the benefit obligation and plan assets resulted in a net liability increase of $327 million for the pension benefit plans and $24 million for the other postretirement benefit plans, with a corresponding decrease in other comprehensive income. At December 31, 2015, total expected contributions related to unfunded pension plans were $25 million for 2016. The Company expects to contribute an additional $82 million in 2016 and $23 million in 2017 to unfunded pension plans primarily related to the workforce reduction program. See Note 12—Restructuring Charges . |
Stockholders' Equity
Stockholders' Equity | 9 Months Ended |
Sep. 30, 2016 | |
Stockholders' Equity Note [Abstract] | |
Stockholders' Equity | 14. Stockholders’ Equity Common Stock Issuance In September 2016, the Company completed a public offering of 40.5 million shares of its common stock at a price of $53.23 per share. Net proceeds of $2.16 billion from this equity issuance will primarily be used to fund the acquisition of certain Gulf of Mexico assets, which is expected to close in the fourth quarter of 2016. The remaining net proceeds will be used for general corporate purposes. See Note 3—Acquisitions, Divestitures, and Assets Held for Sale . Earnings per Share (EPS) The Company’s basic EPS is computed based on the average number of shares of common stock outstanding for the period and includes the effect of any participating securities and TEUs as appropriate. Diluted EPS includes the effect of the Company’s outstanding stock options, restricted stock awards, restricted stock units, TEUs, and WES Series A Preferred units, if the inclusion of these items is dilutive. The following provides a reconciliation between basic and diluted earnings per share attributable to common stockholders: Three Months Ended Nine Months Ended millions except per-share amounts 2016 2015 2016 2015 Net income (loss) Net income (loss) attributable to common stockholders $ (830 ) $ (2,235 ) $ (2,556 ) $ (5,442 ) Income (loss) effect of TEUs (2 ) (3 ) (5 ) (3 ) Less distributions on participating securities 1 1 1 4 Basic $ (833 ) $ (2,239 ) $ (2,562 ) $ (5,449 ) Income (loss) effect of TEUs — — (1 ) — Diluted $ (833 ) $ (2,239 ) $ (2,563 ) $ (5,449 ) Shares Average number of common shares outstanding—basic 517 508 512 508 Average number of common shares outstanding—diluted 517 508 512 508 Excluded due to anti-dilutive effect 11 10 11 11 Net income (loss) per common share Basic $ (1.61 ) $ (4.41 ) $ (5.00 ) $ (10.73 ) Diluted $ (1.61 ) $ (4.41 ) $ (5.00 ) $ (10.73 ) |
Accumulated Other Comprehensive
Accumulated Other Comprehensive Income (Loss) | 9 Months Ended |
Sep. 30, 2016 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | |
Accumulated Other Comprehensive Income (Loss) | 15. Accumulated Other Comprehensive Income (Loss) The following summarizes the after-tax changes in the balances of accumulated other comprehensive income (loss): millions Interest-rate Derivatives Previously Subject to Hedge Accounting Pension and Other Postretirement Plans Total Balance at December 31, 2015 $ (42 ) $ (341 ) $ (383 ) Other comprehensive income (loss), before reclassifications — (219 ) (219 ) Reclassifications to Consolidated Statement of Income 4 80 84 Balance at September 30, 2016 $ (38 ) $ (480 ) $ (518 ) |
Noncontrolling Interests
Noncontrolling Interests | 9 Months Ended |
Sep. 30, 2016 | |
Noncontrolling Interest Items [Abstract] | |
Noncontrolling Interests | 16. Noncontrolling Interests WES, a publicly traded consolidated subsidiary, is a limited partnership formed by Anadarko to acquire, own, develop, and operate midstream assets. During the first quarter of 2016 , WES issued 14 million Series A Preferred units to private investors for net proceeds of $440 million , and issued 1.3 million common units to the Company. Proceeds from these issuances were used to acquire interests in Springfield Pipeline LLC from the Company. During the second quarter of 2016 , WES issued an additional eight million Series A Preferred units to private investors, pursuant to the full exercise of an option granted in connection with the initial issuance, and raised net proceeds of $247 million . Class C units issued to Anadarko will receive quarterly distributions in the form of additional Class C units until the end of 2017, unless WES elects to convert the units to common units earlier or Anadarko elects to extend the conversion date. WES distributed 749 thousand Class C units to Anadarko during the nine months ended September 30, 2016 , and 498 thousand Class C units to Anadarko during 2015. During 2015, WES issued approximately 874 thousand common units to the public for net proceeds of $57 million . WGP, a publicly traded consolidated subsidiary, is a limited partnership formed by Anadarko to own partnership interests in WES. During the three months ended June 30, 2016, Anadarko sold 12.5 million of its WGP common units to the public for net proceeds of $476 million . At September 30, 2016 , Anadarko’s ownership interest in WGP consisted of an 81.6% limited partner interest and the entire non-economic general partner interest. The remaining 18.4% limited partner interest in WGP was owned by the public. At September 30, 2016 , WGP’s ownership interest in WES consisted of a 30.0% limited partner interest, the entire 1.5% general partner interest, and all of the WES incentive distribution rights. At September 30, 2016 , Anadarko also owned an 8.5% limited partner interest in WES through other subsidiaries’ ownership of common and Class C units. The remaining 60.0% limited partner interest in WES was owned by the public. |
Variable Interest Entities
Variable Interest Entities | 9 Months Ended |
Sep. 30, 2016 | |
Variable Interest Entities [Abstract] | |
Variable Interest Entities | 17. Variable Interest Entities Consolidated VIEs The Company determined that the partners in WGP and WES with equity at risk lack the power, through voting rights or similar rights, to direct the activities that most significantly impact WGP’s and WES’s economic performance; therefore, WGP and WES are considered VIEs. Anadarko, through its ownership of the general partner interest in WGP, has the power to direct the activities that most significantly affect economic performance and the obligation to absorb losses or the right to receive benefits that could be potentially significant to WGP and WES, therefore Anadarko is considered the primary beneficiary and consolidates WGP and WES. See Note 16—Noncontrolling Interests for additional information on WGP and WES. Assets and Liabilities of VIEs The assets of WGP and WES cannot be used by Anadarko for general corporate purposes and are both included in and disclosed parenthetically on the Company’s Consolidated Balance Sheets. The carrying amounts of liabilities related to WGP and WES for which the creditors do not have recourse to other assets of the Company are both included in and disclosed parenthetically on the Company’s Consolidated Balance Sheets. All outstanding debt for WES at September 30, 2016, and December 31, 2015 , including any borrowings under the WES RCF, is recourse to WES’s general partner, which in turn has been indemnified in certain circumstances by certain wholly owned subsidiaries of the Company for such liabilities. All outstanding debt for WGP at September 30, 2016, and December 31, 2015 , including any borrowings under the WGP RCF, is recourse to WGP’s general partner, which is a wholly owned subsidiary of the Company. See Note 8—Debt and Interest Expense for additional information on WGP and WES long-term debt balances. VIE Financing WGP’s sources of liquidity include borrowings under its RCF and distributions from WES. WES’s sources of liquidity include cash and cash equivalents, cash flows generated from operations, interest income from a note receivable from Anadarko as discussed below, borrowings under its RCF, the issuance of additional partnership units, or debt offerings. See Note 8—Debt and Interest Expense and Note 16—Noncontrolling Interests for additional information on WGP and WES financing activity. Financial Support Provided to VIEs Concurrent with the closing of its May 2008 initial public offering, WES loaned the Company $260 million in exchange for a 30 -year note bearing interest at a fixed annual rate of 6.50% , payable quarterly. The related interest income for WES was $5 million for each of the three months ended September 30, 2016 and 2015 , and $13 million for each of the nine months ended September 30, 2016 and 2015 . The note receivable and related interest income are eliminated in consolidation. In March 2015, WES acquired the Company’s interest in Delaware Basin JV Gathering LLC (DBJV). The acquisition was financed using a deferred purchase price obligation which requires a cash payment from WES to the Company due on March 31, 2020. The cash payment due to the Company is equal to WES’s share in DBJV Net Earnings (defined below) for 2018 and 2019 less WES’s share of capital expenditures incurred for DBJV from March 1, 2015 to February 29, 2020. Net Earnings is defined as all revenues less cost of product, operating expenses, and property taxes. The net present value of this obligation was $16 million at September 30, 2016, and $189 million at December 31, 2015 . The reduction in the value of the deferred purchase price obligation was primarily due to revisions reflecting a decrease in WES’s estimate of future Net Earnings and an increase in WES’s estimate of capital expenditures to be incurred by DBJV. In order to reduce WES’s exposure to a majority of the commodity-price risk inherent in certain of their contracts, Anadarko has commodity price swap agreements in place with WES expiring on December 31, 2016. WES has recorded a capital contribution from Anadarko in its Consolidated Statement of Equity and Partners’ Capital for the amount by which the swap price exceeds the applicable market price. WES recorded a $35 million capital contribution from Anadarko for the nine months ended September 30, 2016 , and a capital contribution of $8 million for the nine months ended September 30, 2015 . |
Supplemental Cash Flow Informat
Supplemental Cash Flow Information | 9 Months Ended |
Sep. 30, 2016 | |
Supplemental Cash Flow Information [Abstract] | |
Supplemental Cash Flow Information | 18. Supplemental Cash Flow Information Additions to properties and equipment as presented within Anadarko’s cash flows from investing activities include cash payments for cost of properties, equipment, and facilities. The cost of properties includes the initial capitalization of drilling costs associated with all exploratory wells whether or not they were deemed to have a commercially sufficient quantity of proved reserves. The following summarizes cash paid (received) for interest and income taxes, as well as non-cash investing and financing activities: Nine Months Ended millions 2016 2015 Cash paid (received) Interest, net of amounts capitalized (1) $ 735 $ 1,916 Income taxes, net of refunds (2) (878 ) (163 ) Non-cash investing activities Fair value of properties and equipment from non-cash transactions $ 2 $ 156 Asset retirement cost additions 85 139 Accruals of property, plant, and equipment 454 858 Net liabilities assumed (divested) in acquisitions and divestitures (39 ) (84 ) Non-cash investing and financing activities Capital lease obligation (3) $ 10 $ — Floating production, storage, and offloading unit construction period obligation (3) 11 51 Deferred drilling lease liability 3 — __________________________________________________________________ (1) Includes $1.2 billion of interest related to the Tronox settlement payment in 2015. (2) Includes $881 million from a tax refund related to the income tax benefit associated with the Company’s 2015 tax net operating loss carryback. (3) Upon completion of the FPSO during the third quarter of 2016, the Company reported the construction period obligation as a capital lease obligation and recorded a fair-value adjustment. See Note 8—Debt and Interest Expense . |
Segment Information
Segment Information | 9 Months Ended |
Sep. 30, 2016 | |
Segment Reporting [Abstract] | |
Segment Information | 19. Segment Information Anadarko’s business segments are separately managed due to distinct operational differences and unique technology, distribution, and marketing requirements. The Company’s three reporting segments are oil and gas exploration and production, midstream, and marketing. The oil and gas exploration and production segment explores for and produces oil, condensate, natural gas, and NGLs and plans for the development and operation of the Company’s LNG project in Mozambique. The midstream segment engages in gathering, processing, treating, and transporting Anadarko and third-party oil, condensate, natural-gas, and NGLs production. The midstream reporting segment consists of two operating segments, WES and other midstream, which are aggregated into one reporting segment due to similar financial and operating characteristics. The marketing segment sells much of Anadarko’s oil, condensate, natural-gas, and NGLs production as well as third-party purchased volumes. 19. Segment Information (Continued) To assess the performance of Anadarko’s operating segments, the chief operating decision maker analyzes Adjusted EBITDAX. The Company defines Adjusted EBITDAX as income (loss) before income taxes; gains (losses) on divestitures, net; exploration expense; DD&A; impairments; interest expense; total (gains) losses on derivatives, net, less net cash from settlement of commodity derivatives; and certain items not related to the Company’s normal operations, less net income (loss) attributable to noncontrolling interests. During the periods presented, items not related to the Company’s normal operations included restructuring charges related to the workforce reduction program included in general and administrative expenses, Deepwater Horizon settlement and related costs included in other operating expenses, loss on early extinguishment of debt, Tronox-related contingent loss, and certain other nonoperating items included in other (income) expense, net. The Company’s definition of Adjusted EBITDAX excludes gains (losses) on divestitures, net and exploration expense as they are not indicators of operating efficiency for a given reporting period. However, exploration expense is monitored by management as part of costs incurred in exploration and development activities. Similarly, DD&A and impairments are excluded from Adjusted EBITDAX as a measure of segment operating performance because capital expenditures are evaluated at the time capital costs are incurred. Adjusted EBITDAX also excludes interest expense to allow for assessment of segment operating results without regard to Anadarko’s financing methods or capital structure. Total (gains) losses on derivatives, net, less net cash from settlement of commodity derivatives are excluded from Adjusted EBITDAX because these (gains) losses are not considered a measure of asset operating performance. Finally, net income (loss) attributable to noncontrolling interests is excluded from the Company’s measure of Adjusted EBITDAX because it represents earnings that are not attributable to the Company’s common stockholders. Management believes Adjusted EBITDAX provides information useful in assessing the Company’s operating and financial performance across periods. Adjusted EBITDAX as defined by Anadarko may not be comparable to similarly titled measures used by other companies and should be considered in conjunction with net income (loss) attributable to common stockholders and other performance measures, such as operating income. Below is a reconciliation of consolidated Adjusted EBITDAX to income (loss) before income taxes: Three Months Ended Nine Months Ended millions 2016 2015 2016 2015 Income (loss) before income taxes $ (1,007 ) $ (3,077 ) $ (3,313 ) $ (7,520 ) (Gains) losses on divestitures, net 414 578 516 1,003 Exploration expense 304 1,074 506 2,260 DD&A 1,069 1,111 3,202 3,581 Impairments 27 758 61 3,571 Interest expense 220 199 657 616 Total (gains) losses on derivatives, net, less net cash from settlement of commodity derivatives 88 360 863 374 Restructuring charges 112 — 363 — Other operating expense — — 1 4 Loss on early extinguishment of debt — — 124 — Tronox-related contingent loss — — — 5 Certain other nonoperating items — — (56 ) 22 Less net income (loss) attributable to noncontrolling interests 83 75 200 154 Consolidated Adjusted EBITDAX $ 1,144 $ 928 $ 2,724 $ 3,762 19. Segment Information (Continued) Information presented below as “Other and Intersegment Eliminations” includes corporate costs, results from hard-minerals royalties, and net cash from settlement of commodity derivatives. The following summarizes selected financial information for Anadarko’s reporting segments: millions Oil and Gas Exploration & Production Midstream Marketing Other and Intersegment Eliminations Total Three Months Ended September 30, 2016 Sales revenues $ 1,109 $ 174 $ 968 $ — $ 2,251 Intersegment revenues 717 370 (841 ) (246 ) — Other — — — 56 56 Total revenues and other (1) 1,826 544 127 (190 ) 2,307 Operating costs and expenses (2) 807 273 173 (79 ) 1,174 Net cash from settlement of commodity derivatives — — — (63 ) (63 ) Other (income) expense, net — — — (31 ) (31 ) Net income (loss) attributable to noncontrolling interests — 83 — — 83 Total expenses and other 807 356 173 (173 ) 1,163 Adjusted EBITDAX $ 1,019 $ 188 $ (46 ) $ (17 ) $ 1,144 Three Months Ended September 30, 2015 Sales revenues $ 1,067 $ 195 $ 968 $ — $ 2,230 Intersegment revenues 750 315 (832 ) (233 ) — Other — — — 36 36 Total revenues and other (1) 1,817 510 136 (197 ) 2,266 Operating costs and expenses (2) 840 287 181 (14 ) 1,294 Net cash from settlement of commodity derivatives — — — (79 ) (79 ) Other (income) expense, net — — — 47 47 Net income (loss) attributable to noncontrolling interests — 75 — — 75 Total expenses and other 840 362 181 (46 ) 1,337 Total (gains) losses on derivatives, net included in marketing revenue, less net cash from settlement — — (1 ) — (1 ) Adjusted EBITDAX $ 977 $ 148 $ (46 ) $ (151 ) $ 928 __________________________________________________________________ (1) Total revenues and other excludes gains (losses) on divestitures, net since these gains and losses are excluded from Adjusted EBITDAX. (2) Operating costs and expenses excludes exploration expense, DD&A, impairments, restructuring charges, and other operating expense since these expenses are excluded from Adjusted EBITDAX. 19. Segment Information (Continued) millions Oil and Gas Exploration & Production Midstream Marketing Other and Intersegment Eliminations Total Nine Months Ended September 30, 2016 Sales revenues $ 2,853 $ 440 $ 2,577 $ — $ 5,870 Intersegment revenues 1,885 1,012 (2,180 ) (717 ) — Other — — — 128 128 Total revenues and other (1) 4,738 1,452 397 (589 ) 5,998 Operating costs and expenses (2) 2,370 675 526 (233 ) 3,338 Net cash from settlement of commodity derivatives — — — (226 ) (226 ) Other (income) expense, net (3) — — — (30 ) (30 ) Net income (loss) attributable to noncontrolling interests — 200 — — 200 Total expenses and other 2,370 875 526 (489 ) 3,282 Total (gains) losses on derivatives, net included in marketing revenue, less net cash from settlement — — 8 — 8 Adjusted EBITDAX $ 2,368 $ 577 $ (121 ) $ (100 ) $ 2,724 Nine Months Ended September 30, 2015 Sales revenues $ 3,493 $ 560 $ 3,399 $ — $ 7,452 Intersegment revenues 2,752 920 (2,977 ) (695 ) — Other — — — 196 196 Total revenues and other (1) 6,245 1,480 422 (499 ) 7,648 Operating costs and expenses (2) 2,674 761 571 (110 ) 3,896 Net cash from settlement of commodity derivatives — — — (251 ) (251 ) Other (income) expense, net (3) — — — 87 87 Net income (loss) attributable to noncontrolling interests — 154 — — 154 Total expenses and other 2,674 915 571 (274 ) 3,886 Adjusted EBITDAX $ 3,571 $ 565 $ (149 ) $ (225 ) $ 3,762 __________________________________________________________________ (1) Total revenues and other excludes gains (losses) on divestitures, net since these gains and losses are excluded from Adjusted EBITDAX. (2) Operating costs and expenses excludes exploration expense, DD&A, impairments, restructuring charges, and other operating expense since these expenses are excluded from Adjusted EBITDAX. (3) Other (income) expense, net excludes certain other nonoperating items since these items are excluded from Adjusted EBITDAX. |
Summary of Significant Accoun27
Summary of Significant Accounting Policies (Policies) | 9 Months Ended |
Sep. 30, 2016 | |
Accounting Policies [Abstract] | |
Consolidation | The Consolidated Financial Statements include the accounts of Anadarko and subsidiaries in which Anadarko holds, directly or indirectly, more than 50% of the voting rights and variable interest entities (VIEs) for which Anadarko is the primary beneficiary. All intercompany transactions have been eliminated. Undivided interests in oil and natural-gas exploration and production joint ventures are consolidated on a proportionate basis. Investments in noncontrolled entities over which Anadarko has the ability to exercise significant influence over operating and financial policies and VIEs for which Anadarko is not the primary beneficiary are accounted for using the equity method. In applying the equity method of accounting, the investments are initially recognized at cost, and subsequently adjusted for the Company’s proportionate share of earnings, losses, and distributions. Other investments are carried at original cost. Investments accounted for using the equity method and cost method are reported as a component of other assets. |
Recently Issued Accounting Standards | Recently Adopted Accounting Standards The Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2015-03, Interest—Imputation of Interest (Subtopic 835-30): Simplifying the Presentation of Debt Issuance Costs and ASU 2015-15, Interest—Imputation of Interest (Subtopic 835-30): Presentation and Subsequent Measurement of Debt Issuance Costs Associated with Line-of-Credit Arrangements . These ASUs require capitalized debt issuance costs, except for those related to revolving credit facilities, to be presented in the balance sheet as a direct deduction from the carrying amount of the related debt liability, rather than as an asset. The Company adopted these ASUs on January 1, 2016, using a retrospective approach. The adoption resulted in a reclassification that reduced other current assets and short-term debt by $1 million and reduced other assets and long-term debt by $82 million on the Company’s Consolidated Balance Sheet at December 31, 2015. The FASB issued ASU 2015-02, Consolidation (Topic 810): Amendments to the Consolidation Analysis. The Company adopted this ASU on January 1, 2016. In accordance with the new ASU, Western Gas Equity Partners, LP (WGP) and Western Gas Partners, LP (WES), publicly traded consolidated subsidiaries of the Company, are considered VIEs for which the Company is the primary beneficiary. Prior to adoption of the ASU, WGP and WES were consolidated by the Company under the voting interest model. After adoption, WGP and WES were consolidated by the Company under the variable interest model. While this ASU requires additional financial statement disclosure, it has no impact on the Company’s consolidated results of operations, cash flows, or financial position. See Note 17—Variable Interest Entities . New Accounting Standards Issued But Not Yet Adopted The FASB issued ASU 2016-16, Income Taxes (Topic 740): Intra-Entity Transfers of Assets Other Than Inventory . This ASU requires an entity to recognize the income tax consequences of an intra-entity transfer of an asset other than inventory when the transfer occurs and eliminates the exception for an intra-entity transfer of an asset other than inventory. This ASU is effective for annual and interim periods beginning in 2018 and is required to be adopted using a modified retrospective approach, with early adoption permitted. The Company is evaluating the impact of the adoption of this ASU on its consolidated financial statements. 1. Summary of Significant Accounting Policies (Continued) The FASB issued ASU 2016-15, Statement of Cash Flows (Topic 230): Classification of Certain Cash Receipts and Cash Payments . This ASU provides clarification on how certain cash receipts and cash payments are presented and classified on the statement of cash flows. This ASU is effective for annual and interim periods beginning in 2018 and is required to be adopted using a retrospective approach if practicable, with early adoption permitted. The Company does not expect the adoption of this ASU to have a material impact on its Consolidated Statement of Cash Flows. The FASB issued ASU 2016-09, Compensation—Stock Compensation (Topic 718): Improvements to Employee Share-Based Payment Accounting. This ASU simplifies the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, classification on the statement of cash flows, and accounting for forfeitures. This ASU is effective for annual and interim periods beginning in 2017 with early adoption permitted. The Company will adopt this ASU beginning on January 1, 2017, and does not expect the adoption to have a material impact on its consolidated financial statements. The FASB issued ASU 2016-02, Leases (Topic 842). This ASU requires the lessees to recognize a lease liability and a right-of-use asset for all leases, including operating leases, with a term greater than 12 months on the balance sheet and disclose key information about their leasing transactions. This ASU is effective for annual and interim periods beginning in 2019. The Company is evaluating the impact of the adoption of this ASU on its consolidated financial statements. The FASB issued ASU 2014-09, Revenue from Contracts with Customers (Topic 606) , which supersedes current revenue recognition requirements and industry-specific guidance. The codification was amended through additional ASUs and, as amended, requires an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration the entity expects to be entitled to in exchange for those goods or services. The Company is required to adopt the new standard in the first quarter of 2018 using one of two retrospective application methods. The Company is continuing to evaluate the provisions of this ASU and has not determined the impact this standard may have on its consolidated financial statements and related disclosures or decided upon the method of adoption. |
Inventories (Tables)
Inventories (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Energy Related Inventory [Abstract] | |
Inventory Disclosure Table | The following summarizes the major classes of inventories included in other current assets: millions September 30, December 31, Oil $ 136 $ 116 Natural gas 35 36 NGLs 83 64 Total inventories $ 254 $ 216 |
Impairments (Tables)
Impairments (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Asset Impairment Charges [Abstract] | |
Schedule of Impairment Expense | The following summarizes impairments of long-lived assets and the related post-impairment fair values by segment: Three Months Ended Nine Months Ended millions Impairment Fair Value (1) Impairment Fair Value (1) September 30, 2016 Oil and gas exploration and production Long-lived assets held for use U.S. onshore properties $ 23 $ 32 $ 27 $ 617 Gulf of Mexico properties — — 2 — Cost-method investment (2) — — 2 32 Midstream Long-lived assets held for use 3 — 24 5 Other Long-lived assets held for use 1 — 6 — Total $ 27 $ 32 $ 61 $ 654 September 30, 2015 Oil and gas exploration and production Long-lived assets held for use U.S. onshore properties $ 641 $ 634 $ 2,944 $ 1,904 Gulf of Mexico properties 101 94 126 94 Cost-method investment (2) 1 32 2 32 Midstream Long-lived assets held for use 15 7 499 209 Total $ 758 $ 767 $ 3,571 $ 2,239 __________________________________________________________________ (1) Measured as of the impairment date using the income approach and Level 3 inputs. (2) Represents the after-tax net investment. |
Derivative Instruments (Tables)
Derivative Instruments (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Schedule of Derivative Instruments | The following is a summary of the Company’s derivative instruments related to oil and natural-gas production/processing derivative activities at September 30, 2016 : 2016 Settlement 2017 Settlement 2018 Settlement Oil Three-Way Collars (MBbls/d) 83 — — Average price per barrel Ceiling sold price (call) $ 63.82 $ — $ — Floor purchased price (put) $ 54.46 $ — $ — Floor sold price (put) $ 42.77 $ — $ — Natural Gas Three-Way Collars (thousand MMBtu/d) — 682 250 Average price per MMBtu Ceiling sold price (call) $ — $ 3.60 $ 3.54 Floor purchased price (put) $ — $ 2.75 $ 2.75 Floor sold price (put) $ — $ 2.00 $ 2.00 Fixed-Price Contracts (thousand MMBtu/d) — 37 — Average price per MMBtu $ — $ 3.14 $ — NGLs Fixed-Price Contracts (MBbls/d) — 2 — Average price per barrel $ — $ 15.84 $ — __________________________________________________________________ MBbls/d—thousand barrels per day MMBtu/d—million British thermal units per day MMBtu—million British thermal units The Company had the following outstanding interest-rate swaps at September 30, 2016 : millions except percentages Mandatory Weighted-Average Notional Principal Amount Reference Period Termination Date Interest Rate $ 500 September 2016 – 2046 September 2018 6.559% $ 300 September 2016 – 2046 September 2020 6.509% $ 450 September 2017 – 2047 September 2018 6.445% $ 100 September 2017 – 2047 September 2020 6.891% $ 250 September 2017 – 2047 September 2021 6.570% |
Schedule of Other Derivatives Not Designated as Hedging Instruments, Statements of Financial Performance and Financial Position, Location | The following summarizes the fair value of the Company’s derivative instruments: Gross Derivative Assets Gross Derivative Liabilities millions September 30, December 31, September 30, December 31, Balance Sheet Classification 2016 2015 2016 2015 Commodity derivatives Other current assets $ 65 $ 462 $ (8 ) $ (177 ) Other assets 29 8 (2 ) — Accrued expenses 2 — (18 ) (3 ) Other liabilities 3 — (22 ) — 99 470 (50 ) (180 ) Interest-rate derivatives Other current assets 4 2 — — Other assets 18 54 — — Accrued expenses — — (48 ) (54 ) Other liabilities — — (1,806 ) (1,488 ) 22 56 (1,854 ) (1,542 ) Total derivatives $ 121 $ 526 $ (1,904 ) $ (1,722 ) The following summarizes gains and losses related to derivative instruments: millions Three Months Ended Nine Months Ended Classification of (Gain) Loss Recognized 2016 2015 2016 2015 Commodity derivatives Gathering, processing, and marketing sales (1) $ (1 ) $ (1 ) $ 5 $ — (Gains) losses on derivatives, net (59 ) (125 ) 7 (177 ) Interest-rate derivatives (Gains) losses on derivatives, net 84 407 622 300 Total (gains) losses on derivatives, net $ 24 $ 281 $ 634 $ 123 __________________________________________________________________ (1) Represents the effect of Marketing and Trading Derivative Activities. |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis | The following summarizes the fair value of the Company’s derivative assets and liabilities by input level within the fair-value hierarchy: millions September 30, 2016 Level 1 Level 2 Level 3 Netting (1) Collateral Total Assets Commodity derivatives $ — $ 99 $ — $ (14 ) $ — $ 85 Interest-rate derivatives — 22 — — — 22 Total derivative assets $ — $ 121 $ — $ (14 ) $ — $ 107 Liabilities Commodity derivatives $ (1 ) $ (49 ) $ — $ 14 $ 2 $ (34 ) Interest-rate derivatives — (1,854 ) — — 422 (1,432 ) Total derivative liabilities $ (1 ) $ (1,903 ) $ — $ 14 $ 424 $ (1,466 ) December 31, 2015 Assets Commodity derivatives $ 10 $ 460 $ — $ (178 ) $ (8 ) $ 284 Interest-rate derivatives — 56 — — — 56 Total derivative assets $ 10 $ 516 $ — $ (178 ) $ (8 ) $ 340 Liabilities Commodity derivatives $ (1 ) $ (179 ) $ — $ 178 $ — $ (2 ) Interest-rate derivatives — (1,542 ) — — 58 (1,484 ) Total derivative liabilities $ (1 ) $ (1,721 ) $ — $ 178 $ 58 $ (1,486 ) __________________________________________________________________ (1) Represents the impact of netting commodity derivative assets and liabilities with counterparties where the Company has the contractual right and intends to net settle. |
Debt and Interest Expense (Tabl
Debt and Interest Expense (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Debt Disclosure [Abstract] | |
Debt Outstanding and Debt Activity Tables | The following summarizes the Company’s borrowing activity, after eliminating the effect of intercompany transactions, during the nine months ended September 30, 2016 : Carrying Value millions WES WGP (1) Anadarko (2) Anadarko Consolidated Description Balance at December 31, 2015 $ 2,691 $ — $ 12,957 $ 15,648 Issuances — — 794 794 4.850% Senior Notes due 2021 — — 1,088 1,088 5.550% Senior Notes due 2026 — — 1,088 1,088 6.600% Senior Notes due 2046 495 — — 495 WES 4.650% Senior Notes due 2026 Borrowings — — 1,750 1,750 364-Day Facility 600 — — 600 WES RCF — 28 — 28 WGP RCF Repayments — — (1,749 ) (1,749 ) 5.950% Senior Notes due 2016 — — (1,245 ) (1,245 ) 6.375% Senior Notes due 2017 — — (1,750 ) (1,750 ) 364-Day Facility (880 ) — — (880 ) WES RCF — — (250 ) (250 ) Commercial paper notes, net — — (25 ) (25 ) TEUs - senior amortizing notes Other, net 1 — 40 41 Amortization of discounts, premiums, and debt issuance costs Balance at September 30, 2016 $ 2,907 $ 28 $ 12,698 $ 15,633 __________________________________________________________________ (1) Excludes WES. (2) Excludes WES and WGP. The following summarizes the Company’s outstanding debt and capital lease obligations after eliminating the effect of intercompany transactions: millions WES WGP (1) Anadarko (2) Anadarko Consolidated September 30, 2016 Total borrowings at face value $ 2,940 $ 28 $ 14,317 $ 17,285 Net unamortized discounts, premiums, and debt issuance costs (3) (33 ) — (1,619 ) (1,652 ) Total borrowings (4) 2,907 28 12,698 15,633 Capital lease obligations — — 245 245 Less short-term debt (5) — — 788 788 Total long-term debt $ 2,907 $ 28 $ 12,155 $ 15,090 December 31, 2015 Total borrowings at face value $ 2,720 $ — $ 14,592 $ 17,312 Net unamortized discounts, premiums, and debt issuance costs (3) (29 ) — (1,635 ) (1,664 ) Total borrowings (4) 2,691 — 12,957 15,648 Capital lease obligations — — 20 20 Less short-term debt — — 32 32 Total long-term debt $ 2,691 $ — $ 12,945 $ 15,636 __________________________________________________________________ (1) Excludes WES. (2) Excludes WES and WGP. (3) Unamortized discounts, premiums, and debt issuance costs are amortized over the term of the related debt. Debt issuance costs related to revolving credit facilities are included in other current assets and other assets on the Company’s Consolidated Balance Sheets. (4) The Company’s outstanding borrowings, except for borrowings under the WGP revolving credit facility, are senior unsecured. (5) Short-term debt includes $750 million of 6.375% Senior Notes due September 2017 . In October 2016, the Company provided notice of its intent to redeem the notes prior to year end. |
Capital Lease Obligations Table | At September 30, 2016, future minimum lease payments due under capital leases were: millions 2016 $ 16 2017 42 2018 42 2019 42 2020 42 Remaining years 433 Total future minimum lease payments $ 617 Less portion representing imputed interest 372 Capital lease obligations $ 245 |
Interest Expense Table | The following summarizes interest expense: Three Months Ended Nine Months Ended millions 2016 2015 2016 2015 Debt and other $ 251 $ 245 $ 768 $ 743 Capitalized interest (31 ) (46 ) (111 ) (127 ) Total interest expense $ 220 $ 199 $ 657 $ 616 |
Income Taxes (Tables)
Income Taxes (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Income Tax Disclosure [Abstract] | |
Schedule of Income Taxes and Effective Tax Rate | The following summarizes income tax expense (benefit) and effective tax rates: Three Months Ended Nine Months Ended millions except percentages 2016 2015 2016 2015 Income tax expense (benefit) $ (260 ) $ (917 ) $ (957 ) $ (2,232 ) Income (loss) before income taxes (1,007 ) (3,077 ) (3,313 ) (7,520 ) Effective tax rate 26 % 30 % 29 % 30 % |
Conveyance of Future Hard Min33
Conveyance of Future Hard Minerals Royalty Revenues (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Deferred Revenue Disclosure [Abstract] | |
Schedule of Future Royalty Payments | The following summarizes the remaining amounts that the Company expects to pay, prior to the potential 3% to 4% of any excess described above: millions 2017 $ 50 2018 50 2019 52 2020 56 2021 57 Later years 263 Total $ 528 |
Restructuring Charges (Tables)
Restructuring Charges (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Restructuring and Related Activities [Abstract] | |
Schedule of Restructuring Charges | The following summarizes the total expected restructuring charges and the amounts expensed during the three and nine months ended September 30, 2016, which are included in general and administrative expenses in the Company’s Consolidated Statements of Income: millions Total Expected Costs Three Months Ended Nine Months Ended September 30, 2016 Costs by category Cash severance $ 154 $ 5 $ 151 Retirement benefits (1) 219 102 178 Share-based compensation 37 5 34 Total $ 410 $ 112 $ 363 __________________________________________________________________ (1) Includes termination benefits, curtailments, and settlements. See Note 13—Pension Plans and Other Postretirement Benefits . The following summarizes the changes in the cash severance-related liability included in accounts payable on the Company’s Consolidated Balance Sheet: millions 2016 Balance at January 1 $ — Accruals 151 Payments (141 ) Balance at September 30 $ 10 |
Pension Plans and Other Postr35
Pension Plans and Other Postretirement Benefits (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Compensation and Retirement Disclosure [Abstract] | |
Components of Net Periodic Benefit Cost Table | The following summarizes the Company’s pension and other postretirement benefit cost: Pension Benefits Other Benefits millions 2016 2015 2016 2015 Three Months Ended September 30 Service cost $ 24 $ 30 $ 1 $ 3 Interest cost 24 25 3 3 Expected return on plan assets (24 ) (27 ) — — Amortization of net actuarial loss (gain) 12 13 — — Amortization of net prior service cost (credit) — — (6 ) 1 Settlement expense 102 — — — Net periodic benefit cost $ 138 $ 41 $ (2 ) $ 7 Nine Months Ended September 30 Service cost $ 73 $ 89 $ 2 $ 8 Interest cost 73 76 9 11 Expected return on plan assets (75 ) (82 ) — — Amortization of net actuarial loss (gain) 30 39 — — Amortization of net prior service cost (credit) — — (18 ) 2 Settlement expense 126 — — — Termination benefits expense 44 — — — Curtailment expense 8 — — — Net periodic benefit cost $ 279 $ 122 $ (7 ) $ 21 |
Stockholders' Equity (Tables)
Stockholders' Equity (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Stockholders' Equity Note [Abstract] | |
Earnings Per Share Table | The following provides a reconciliation between basic and diluted earnings per share attributable to common stockholders: Three Months Ended Nine Months Ended millions except per-share amounts 2016 2015 2016 2015 Net income (loss) Net income (loss) attributable to common stockholders $ (830 ) $ (2,235 ) $ (2,556 ) $ (5,442 ) Income (loss) effect of TEUs (2 ) (3 ) (5 ) (3 ) Less distributions on participating securities 1 1 1 4 Basic $ (833 ) $ (2,239 ) $ (2,562 ) $ (5,449 ) Income (loss) effect of TEUs — — (1 ) — Diluted $ (833 ) $ (2,239 ) $ (2,563 ) $ (5,449 ) Shares Average number of common shares outstanding—basic 517 508 512 508 Average number of common shares outstanding—diluted 517 508 512 508 Excluded due to anti-dilutive effect 11 10 11 11 Net income (loss) per common share Basic $ (1.61 ) $ (4.41 ) $ (5.00 ) $ (10.73 ) Diluted $ (1.61 ) $ (4.41 ) $ (5.00 ) $ (10.73 ) |
Accumulated Other Comprehensi37
Accumulated Other Comprehensive Income (Loss) (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract] | |
Schedule Of Accumulated Other Comprehensive Income (Loss) | The following summarizes the after-tax changes in the balances of accumulated other comprehensive income (loss): millions Interest-rate Derivatives Previously Subject to Hedge Accounting Pension and Other Postretirement Plans Total Balance at December 31, 2015 $ (42 ) $ (341 ) $ (383 ) Other comprehensive income (loss), before reclassifications — (219 ) (219 ) Reclassifications to Consolidated Statement of Income 4 80 84 Balance at September 30, 2016 $ (38 ) $ (480 ) $ (518 ) |
Supplemental Cash Flow Inform38
Supplemental Cash Flow Information (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Supplemental Cash Flow Information [Abstract] | |
Supplemental Cash Flow Table | The following summarizes cash paid (received) for interest and income taxes, as well as non-cash investing and financing activities: Nine Months Ended millions 2016 2015 Cash paid (received) Interest, net of amounts capitalized (1) $ 735 $ 1,916 Income taxes, net of refunds (2) (878 ) (163 ) Non-cash investing activities Fair value of properties and equipment from non-cash transactions $ 2 $ 156 Asset retirement cost additions 85 139 Accruals of property, plant, and equipment 454 858 Net liabilities assumed (divested) in acquisitions and divestitures (39 ) (84 ) Non-cash investing and financing activities Capital lease obligation (3) $ 10 $ — Floating production, storage, and offloading unit construction period obligation (3) 11 51 Deferred drilling lease liability 3 — __________________________________________________________________ (1) Includes $1.2 billion of interest related to the Tronox settlement payment in 2015. (2) Includes $881 million from a tax refund related to the income tax benefit associated with the Company’s 2015 tax net operating loss carryback. (3) Upon completion of the FPSO during the third quarter of 2016, the Company reported the construction period obligation as a capital lease obligation and recorded a fair-value adjustment. See Note 8—Debt and Interest Expense . |
Segment Information (Tables)
Segment Information (Tables) | 9 Months Ended |
Sep. 30, 2016 | |
Segment Reporting [Abstract] | |
Reconciliation of Consolidated Adjusted EBITDAX to Income (Loss) Before Income Taxes | Below is a reconciliation of consolidated Adjusted EBITDAX to income (loss) before income taxes: Three Months Ended Nine Months Ended millions 2016 2015 2016 2015 Income (loss) before income taxes $ (1,007 ) $ (3,077 ) $ (3,313 ) $ (7,520 ) (Gains) losses on divestitures, net 414 578 516 1,003 Exploration expense 304 1,074 506 2,260 DD&A 1,069 1,111 3,202 3,581 Impairments 27 758 61 3,571 Interest expense 220 199 657 616 Total (gains) losses on derivatives, net, less net cash from settlement of commodity derivatives 88 360 863 374 Restructuring charges 112 — 363 — Other operating expense — — 1 4 Loss on early extinguishment of debt — — 124 — Tronox-related contingent loss — — — 5 Certain other nonoperating items — — (56 ) 22 Less net income (loss) attributable to noncontrolling interests 83 75 200 154 Consolidated Adjusted EBITDAX $ 1,144 $ 928 $ 2,724 $ 3,762 |
Schedule of Segment Reporting Information, by Segment | The following summarizes selected financial information for Anadarko’s reporting segments: millions Oil and Gas Exploration & Production Midstream Marketing Other and Intersegment Eliminations Total Three Months Ended September 30, 2016 Sales revenues $ 1,109 $ 174 $ 968 $ — $ 2,251 Intersegment revenues 717 370 (841 ) (246 ) — Other — — — 56 56 Total revenues and other (1) 1,826 544 127 (190 ) 2,307 Operating costs and expenses (2) 807 273 173 (79 ) 1,174 Net cash from settlement of commodity derivatives — — — (63 ) (63 ) Other (income) expense, net — — — (31 ) (31 ) Net income (loss) attributable to noncontrolling interests — 83 — — 83 Total expenses and other 807 356 173 (173 ) 1,163 Adjusted EBITDAX $ 1,019 $ 188 $ (46 ) $ (17 ) $ 1,144 Three Months Ended September 30, 2015 Sales revenues $ 1,067 $ 195 $ 968 $ — $ 2,230 Intersegment revenues 750 315 (832 ) (233 ) — Other — — — 36 36 Total revenues and other (1) 1,817 510 136 (197 ) 2,266 Operating costs and expenses (2) 840 287 181 (14 ) 1,294 Net cash from settlement of commodity derivatives — — — (79 ) (79 ) Other (income) expense, net — — — 47 47 Net income (loss) attributable to noncontrolling interests — 75 — — 75 Total expenses and other 840 362 181 (46 ) 1,337 Total (gains) losses on derivatives, net included in marketing revenue, less net cash from settlement — — (1 ) — (1 ) Adjusted EBITDAX $ 977 $ 148 $ (46 ) $ (151 ) $ 928 __________________________________________________________________ (1) Total revenues and other excludes gains (losses) on divestitures, net since these gains and losses are excluded from Adjusted EBITDAX. (2) Operating costs and expenses excludes exploration expense, DD&A, impairments, restructuring charges, and other operating expense since these expenses are excluded from Adjusted EBITDAX. 19. Segment Information (Continued) millions Oil and Gas Exploration & Production Midstream Marketing Other and Intersegment Eliminations Total Nine Months Ended September 30, 2016 Sales revenues $ 2,853 $ 440 $ 2,577 $ — $ 5,870 Intersegment revenues 1,885 1,012 (2,180 ) (717 ) — Other — — — 128 128 Total revenues and other (1) 4,738 1,452 397 (589 ) 5,998 Operating costs and expenses (2) 2,370 675 526 (233 ) 3,338 Net cash from settlement of commodity derivatives — — — (226 ) (226 ) Other (income) expense, net (3) — — — (30 ) (30 ) Net income (loss) attributable to noncontrolling interests — 200 — — 200 Total expenses and other 2,370 875 526 (489 ) 3,282 Total (gains) losses on derivatives, net included in marketing revenue, less net cash from settlement — — 8 — 8 Adjusted EBITDAX $ 2,368 $ 577 $ (121 ) $ (100 ) $ 2,724 Nine Months Ended September 30, 2015 Sales revenues $ 3,493 $ 560 $ 3,399 $ — $ 7,452 Intersegment revenues 2,752 920 (2,977 ) (695 ) — Other — — — 196 196 Total revenues and other (1) 6,245 1,480 422 (499 ) 7,648 Operating costs and expenses (2) 2,674 761 571 (110 ) 3,896 Net cash from settlement of commodity derivatives — — — (251 ) (251 ) Other (income) expense, net (3) — — — 87 87 Net income (loss) attributable to noncontrolling interests — 154 — — 154 Total expenses and other 2,674 915 571 (274 ) 3,886 Adjusted EBITDAX $ 3,571 $ 565 $ (149 ) $ (225 ) $ 3,762 __________________________________________________________________ (1) Total revenues and other excludes gains (losses) on divestitures, net since these gains and losses are excluded from Adjusted EBITDAX. (2) Operating costs and expenses excludes exploration expense, DD&A, impairments, restructuring charges, and other operating expense since these expenses are excluded from Adjusted EBITDAX. (3) Other (income) expense, net excludes certain other nonoperating items since these items are excluded from Adjusted EBITDAX. |
Summary of Significant Accoun40
Summary of Significant Accounting Policies (Detail) - USD ($) $ in Millions | Sep. 30, 2016 | Dec. 31, 2015 | |
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||
Reduction in other current assets | $ (347) | $ (573) | |
Reduction in short-term debt | (788) | [1] | (32) |
Reduction in other assets | (2,203) | (2,268) | |
Reduction in long-term debt | $ (15,090) | (15,636) | |
Accounting Standards Update 2015-03 [Member] | Restatement Adjustment [Member] | |||
New Accounting Pronouncements or Change in Accounting Principle [Line Items] | |||
Reduction in other current assets | 1 | ||
Reduction in short-term debt | 1 | ||
Reduction in other assets | 82 | ||
Reduction in long-term debt | $ 82 | ||
[1] | Short-term debt includes $750 million of 6.375% Senior Notes due September 2017. In October 2016, the Company provided notice of its intent to redeem the notes prior to year end. |
Inventories (Detail)
Inventories (Detail) - USD ($) $ in Millions | Sep. 30, 2016 | Dec. 31, 2015 |
Energy Related Inventory [Abstract] | ||
Oil | $ 136 | $ 116 |
Natural gas | 35 | 36 |
NGLs | 83 | 64 |
Total inventories | $ 254 | $ 216 |
Acquisitions, Divestitures, a42
Acquisitions, Divestitures, and Assets Held for Sale - Acquisitions (Detail) shares in Millions, $ in Billions | 9 Months Ended |
Sep. 30, 2016USD ($)shares | |
Property, Plant, and Equipment [Line Items] | |
Common stock issued during the period | shares | 40.5 |
Oil and Gas Assets in the Gulf of Mexico [Member] | |
Property, Plant, and Equipment [Line Items] | |
Purchase price | $ | $ 2 |
Acquisitions, Divestitures, a43
Acquisitions, Divestitures, and Assets Held for Sale - Divestitures and Assets Held for Sale (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Net proceeds from divestitures | $ 1,281 | $ 1,248 | ||
Net losses from divestitures and assets held for sale | $ 414 | $ 578 | 516 | $ 1,003 |
Held for Sale [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Long-term assets associated with assets held for sale | 1,100 | 1,100 | ||
Goodwill associated with assets held for sale | 184 | 184 | ||
Long-term liabilities associated with assets held for sale | 44 | 44 | ||
Oil and Gas Exploration and Production and Midstream Reporting Segment [Member] | Certain U.S. Onshore West Texas Assets [Member] | Asset Disposed of by Sale [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Net proceeds from divestitures | 223 | |||
Gain (loss) on divestitures | (50) | |||
Oil and Gas Exploration and Production and Midstream Reporting Segment [Member] | Certain Onshore Domestic East Texas Assets [Member] | Held for Sale [Member] | Fair Value, Inputs, Level 2 [Member] | Market Approach Valuation Technique [Member] | Fair Value, Measurements, Nonrecurring [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Loss on asset held for sale | $ 355 | |||
Oil and Gas Exploration and Production Reporting Segment [Member] | Certain U.S. Onshore East Texas/Louisiana Assets [Member] | Asset Disposed of by Sale [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Net proceeds from divestitures | 199 | |||
Gain (loss) on divestitures | (41) | |||
Oil and Gas Exploration and Production Reporting Segment [Member] | Certain U.S. Onshore Wyoming Assets [Member] | Asset Disposed of by Sale [Member] | ||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||
Net proceeds from divestitures | 588 | |||
Gain (loss) on divestitures | $ (59) |
Impairments - Impairments and F
Impairments - Impairments and Fair Values by Segment Table (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | ||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Total impairments | $ 27 | $ 758 | $ 61 | $ 3,571 | |
Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Total fair value | [1] | 654 | 2,239 | 654 | 2,239 |
Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | Assets Impaired During 3rd Quarter [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Total fair value | [1] | 32 | 767 | 32 | 767 |
Oil and Gas Exploration and Production Reporting Segment [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Impairment of cost-method investment | 0 | 1 | 2 | 2 | |
Oil and Gas Exploration and Production Reporting Segment [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of cost-method investment | [1],[2] | 32 | 32 | 32 | 32 |
Oil and Gas Exploration and Production Reporting Segment [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | Assets Impaired During 3rd Quarter [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of cost-method investment | [1],[2] | 0 | 32 | 0 | 32 |
Oil and Gas Exploration and Production Reporting Segment [Member] | U.S. Onshore Properties [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Impairment of long-lived assets held for use | 23 | 641 | 27 | 2,944 | |
Oil and Gas Exploration and Production Reporting Segment [Member] | U.S. Onshore Properties [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of long-lived assets held for use | [1] | 617 | 1,904 | 617 | 1,904 |
Oil and Gas Exploration and Production Reporting Segment [Member] | U.S. Onshore Properties [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | Assets Impaired During 3rd Quarter [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of long-lived assets held for use | [1] | 32 | 634 | 32 | 634 |
Oil and Gas Exploration and Production Reporting Segment [Member] | Gulf of Mexico Properties [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Impairment of long-lived assets held for use | 0 | 101 | 2 | 126 | |
Oil and Gas Exploration and Production Reporting Segment [Member] | Gulf of Mexico Properties [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of long-lived assets held for use | [1] | 0 | 94 | 0 | 94 |
Oil and Gas Exploration and Production Reporting Segment [Member] | Gulf of Mexico Properties [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | Assets Impaired During 3rd Quarter [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of long-lived assets held for use | [1] | 0 | 94 | 0 | 94 |
Midstream Reporting Segment [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Impairment of long-lived assets held for use | 3 | 15 | 24 | 499 | |
Midstream Reporting Segment [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of long-lived assets held for use | [1] | 5 | 209 | 5 | 209 |
Midstream Reporting Segment [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | Assets Impaired During 3rd Quarter [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of long-lived assets held for use | [1] | 0 | $ 7 | 0 | $ 7 |
Other and Intersegment Eliminations [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Impairment of long-lived assets held for use | 1 | 6 | |||
Other and Intersegment Eliminations [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of long-lived assets held for use | [1] | 0 | 0 | ||
Other and Intersegment Eliminations [Member] | Nonrecurring [Member] | Fair Value, Inputs, Level 3 [Member] | Income Approach Valuation Technique [Member] | Assets Impaired During 3rd Quarter [Member] | |||||
Impaired Long Lived Assets Held and Used [Line Items] | |||||
Fair value of long-lived assets held for use | [1] | $ 0 | $ 0 | ||
[1] | Measured as of the impairment date using the income approach and Level 3 inputs. | ||||
[2] | Represents the after-tax net investment. |
Impairments - Additional Inform
Impairments - Additional Information (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | Dec. 31, 2015 | |
Property, Plant, and Equipment [Line Items] | ||||
Impairment of unproved properties | $ 300 | $ 1,993 | ||
Net book value | $ 31,099 | $ 33,751 | ||
Percent decline in oil price assumption for impairment analysis | 10.00% | |||
Percent decline in natural-gas price assumption for impairment analysis | 10.00% | |||
Unproved Utica Properties [Member] | ||||
Property, Plant, and Equipment [Line Items] | ||||
Impairment of unproved properties | $ 109 | |||
Unproved Greater Natural Buttes Properties [Member] | ||||
Property, Plant, and Equipment [Line Items] | ||||
Impairment of unproved properties | $ 935 | |||
Certain International Asset Group at Risk for Impairment [Member] | ||||
Property, Plant, and Equipment [Line Items] | ||||
Net book value | $ 1,400 | |||
Potential non-cash impairments that could be recognized in the future, in excess of | 600 | |||
Certain U.S. Onshore Asset Groups at Risk for Impairment [Member] | ||||
Property, Plant, and Equipment [Line Items] | ||||
Net book value | 1,100 | |||
Potential non-cash impairments that could be recognized in the future, in excess of | $ 400 |
Suspended Exploratory Well Co46
Suspended Exploratory Well Costs (Detail) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2016 | Dec. 31, 2015 | |
Capitalized Exploratory Well Costs [Abstract] | ||
Suspended exploratory well costs | $ 1,200 | $ 1,100 |
Property, Plant, and Equipment [Line Items] | ||
Suspended exploratory well costs previously capitalized for a period greater than one year since the completion of drilling at December 31, 2015, charged to exploration expense | 142 | |
Shenandoah Well in the Gulf of Mexico [Member] | ||
Property, Plant, and Equipment [Line Items] | ||
Suspended exploratory well costs previously capitalized for a period greater than one year since the completion of drilling at December 31, 2015, charged to exploration expense | 64 | |
Orca-4 Well in Mozambique [Member] | ||
Property, Plant, and Equipment [Line Items] | ||
Suspended exploratory well costs previously capitalized for a period greater than one year since the completion of drilling at December 31, 2015, charged to exploration expense | 38 | |
Tubarão Tigre Discovery [Member] | ||
Property, Plant, and Equipment [Line Items] | ||
Suspended exploratory well costs previously capitalized for a period greater than one year since the completion of drilling at December 31, 2015, charged to exploration expense | 33 | |
Suspended exploratory well costs previously capitalized for less than one year at December 31, 2015, charged to expense | $ 21 |
Derivative Instruments - Oil an
Derivative Instruments - Oil and Natural-Gas Production/Processing Derivative Activities Table (Detail) - Not Designated as Hedging Instrument [Member] MMBTU / d in Thousands | 9 Months Ended |
Sep. 30, 2016MMBTU / dMBbls / d$ / bbl$ / MMBTU | |
Three Way Collars Oil 2016 [Member] | |
Derivative [Line Items] | |
Oil or NGL derivative nonmonetary notional amount per day | MBbls / d | 83 |
Three Way Collars Oil 2016 [Member] | Call Option [Member] | Short [Member] | |
Average price per MMBtu or barrel | |
Average ceiling price | $ / bbl | 63.82 |
Three Way Collars Oil 2016 [Member] | Put Option [Member] | Short [Member] | |
Average price per MMBtu or barrel | |
Average floor price | $ / bbl | 42.77 |
Three Way Collars Oil 2016 [Member] | Put Option [Member] | Long [Member] | |
Average price per MMBtu or barrel | |
Average floor price | $ / bbl | 54.46 |
Three Way Collars Natural Gas 2017 [Member] | |
Average price per MMBtu or barrel | |
Natural-gas derivative nonmonetary notional amount per day | MMBTU / d | 682 |
Three Way Collars Natural Gas 2017 [Member] | Call Option [Member] | Short [Member] | |
Average price per MMBtu or barrel | |
Average ceiling price | 3.60 |
Three Way Collars Natural Gas 2017 [Member] | Put Option [Member] | Short [Member] | |
Average price per MMBtu or barrel | |
Average floor price | 2 |
Three Way Collars Natural Gas 2017 [Member] | Put Option [Member] | Long [Member] | |
Average price per MMBtu or barrel | |
Average floor price | 2.75 |
Three Way Collars Natural Gas 2018 [Member] | |
Average price per MMBtu or barrel | |
Natural-gas derivative nonmonetary notional amount per day | MMBTU / d | 250 |
Three Way Collars Natural Gas 2018 [Member] | Call Option [Member] | Short [Member] | |
Average price per MMBtu or barrel | |
Average ceiling price | 3.54 |
Three Way Collars Natural Gas 2018 [Member] | Put Option [Member] | Short [Member] | |
Average price per MMBtu or barrel | |
Average floor price | 2 |
Three Way Collars Natural Gas 2018 [Member] | Put Option [Member] | Long [Member] | |
Average price per MMBtu or barrel | |
Average floor price | 2.75 |
Forward Contracts Natural Gas 2017 [Member] | |
Average price per MMBtu or barrel | |
Natural-gas derivative nonmonetary notional amount per day | MMBTU / d | 37 |
Average price per MMBtu or barrel | 3.14 |
Forward Contracts Natural Gas Liquids 2017 [Member] | |
Derivative [Line Items] | |
Oil or NGL derivative nonmonetary notional amount per day | MBbls / d | 2 |
Average price per MMBtu or barrel | |
Average price per MMBtu or barrel | $ / bbl | 15.84 |
Derivative Instruments - Additi
Derivative Instruments - Additional Information (Detail) $ in Millions | 2 Months Ended | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||
Feb. 29, 2016 | Sep. 30, 2016USD ($) | Mar. 31, 2016USD ($) | Sep. 30, 2016USD ($)Bcf | Sep. 30, 2015USD ($) | Dec. 31, 2015USD ($)Bcf | |
Derivative [Line Items] | ||||||
Cash payment for settled interest-rate swap | $ 639 | $ 44 | ||||
Debt instrument, principal amount | $ 17,285 | 17,285 | $ 17,312 | |||
Return of collateral due to a negotiated increase of a credit threshold | 200 | |||||
Amount of collateral posted related to derivative instruments with credit-risk-related contingent features | 422 | 422 | 58 | |||
Total Amount of Senior Notes Due in 2019 [Member] | ||||||
Derivative [Line Items] | ||||||
Debt instrument, principal amount | 900 | $ 900 | ||||
Zero-Coupon Senior Notes [Member] | ||||||
Derivative [Line Items] | ||||||
Debt instrument, maturity date | Oct. 10, 2036 | |||||
Debt Instrument, earliest call date | Oct. 10, 2016 | |||||
Zero-Coupon Senior Notes [Member] | Accreted Value at Next Potential Put Date [Member] | ||||||
Derivative [Line Items] | ||||||
Debt instrument, accreted value | 839 | $ 839 | ||||
Not Designated as Hedging Instrument [Member] | ||||||
Derivative [Line Items] | ||||||
Gross derivative liabilities | 1,904 | 1,904 | 1,722 | |||
Aggregate fair value of derivative instruments with credit-risk-related contingent features for which a net liability position existed (net of collateral) | 1,400 | 1,400 | 1,300 | |||
Not Designated as Hedging Instrument [Member] | Settled Interest Rate Swap 1 [Member] | ||||||
Derivative [Line Items] | ||||||
Cash payment for settled interest-rate swap | $ 193 | |||||
Not Designated as Hedging Instrument [Member] | Settled Interest Rate Swap 2 [Member] | ||||||
Derivative [Line Items] | ||||||
Cash payment for settled interest-rate swap | 73 | |||||
Not Designated as Hedging Instrument [Member] | Interest-Rate Swaps 1 and 3 [Member] | Modified Interest-Rate Swaps for Mandatory Termination Dates [Member] | ||||||
Derivative [Line Items] | ||||||
Mandatory termination date for interest-rate swap prior to modification | Sep. 15, 2021 | |||||
Notional principal amount of interest-rate swap | 500 | 500 | ||||
Not Designated as Hedging Instrument [Member] | Interest-Rate Swaps 1 Through 5 [Member] | ||||||
Derivative [Line Items] | ||||||
Notional principal amount of interest-rate swap | 1,600 | 1,600 | ||||
Not Designated as Hedging Instrument [Member] | Permitted to Offset Gross Derivative Asset with Financial Institutions [Member] | ||||||
Derivative [Line Items] | ||||||
Gross derivative liabilities | $ 52 | $ 52 | $ 347 | |||
Natural Gas [Member] | Commodity [Member] | Not Designated as Hedging Instrument [Member] | ||||||
Derivative [Line Items] | ||||||
Financial derivative transactions | Bcf | 5 | 8 |
Derivative Instruments - Intere
Derivative Instruments - Interest-Rate Derivatives Table (Detail) - Not Designated as Hedging Instrument [Member] $ in Millions | 9 Months Ended |
Sep. 30, 2016USD ($) | |
Interest-Rate Swap 1 [Member] | |
Derivative [Line Items] | |
Notional principal amount of interest-rate swap | $ 500 |
Reference period start date for interest-rate swap | Sep. 15, 2016 |
Reference period end date for interest-rate swap | Sep. 15, 2046 |
Mandatory termination date for interest-rate swap | Sep. 15, 2018 |
Weighted-average interest rate for interest-rate swap | 6.559% |
Interest-Rate Swap 2 [Member] | |
Derivative [Line Items] | |
Notional principal amount of interest-rate swap | $ 300 |
Reference period start date for interest-rate swap | Sep. 15, 2016 |
Reference period end date for interest-rate swap | Sep. 15, 2046 |
Mandatory termination date for interest-rate swap | Sep. 15, 2020 |
Weighted-average interest rate for interest-rate swap | 6.509% |
Interest-Rate Swap 3 [Member] | |
Derivative [Line Items] | |
Notional principal amount of interest-rate swap | $ 450 |
Reference period start date for interest-rate swap | Sep. 15, 2017 |
Reference period end date for interest-rate swap | Sep. 15, 2047 |
Mandatory termination date for interest-rate swap | Sep. 15, 2018 |
Weighted-average interest rate for interest-rate swap | 6.445% |
Interest-Rate Swap 4 [Member] | |
Derivative [Line Items] | |
Notional principal amount of interest-rate swap | $ 100 |
Reference period start date for interest-rate swap | Sep. 15, 2017 |
Reference period end date for interest-rate swap | Sep. 15, 2047 |
Mandatory termination date for interest-rate swap | Sep. 15, 2020 |
Weighted-average interest rate for interest-rate swap | 6.891% |
Interest-Rate Swap 5 [Member] | |
Derivative [Line Items] | |
Notional principal amount of interest-rate swap | $ 250 |
Reference period start date for interest-rate swap | Sep. 15, 2017 |
Reference period end date for interest-rate swap | Sep. 15, 2047 |
Mandatory termination date for interest-rate swap | Sep. 15, 2021 |
Weighted-average interest rate for interest-rate swap | 6.57% |
Derivative Instruments - Effect
Derivative Instruments - Effect of Derivative Instruments - Balance Sheet Table (Detail) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Millions | Sep. 30, 2016 | Dec. 31, 2015 |
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | $ 121 | $ 526 |
Gross derivative liabilities | (1,904) | (1,722) |
Commodity Derivatives [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 99 | 470 |
Gross derivative liabilities | (50) | (180) |
Commodity Derivatives [Member] | Other Current Assets [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 65 | 462 |
Gross derivative liabilities | (8) | (177) |
Commodity Derivatives [Member] | Other Assets [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 29 | 8 |
Gross derivative liabilities | (2) | 0 |
Commodity Derivatives [Member] | Accrued Expenses [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 2 | 0 |
Gross derivative liabilities | (18) | (3) |
Commodity Derivatives [Member] | Other Liabilities [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 3 | 0 |
Gross derivative liabilities | (22) | 0 |
Interest-Rate Derivatives [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 22 | 56 |
Gross derivative liabilities | (1,854) | (1,542) |
Interest-Rate Derivatives [Member] | Other Current Assets [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 4 | 2 |
Gross derivative liabilities | 0 | 0 |
Interest-Rate Derivatives [Member] | Other Assets [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 18 | 54 |
Gross derivative liabilities | 0 | 0 |
Interest-Rate Derivatives [Member] | Accrued Expenses [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 0 | 0 |
Gross derivative liabilities | (48) | (54) |
Interest-Rate Derivatives [Member] | Other Liabilities [Member] | ||
Derivatives Fair Value [Line Items] | ||
Gross derivative assets | 0 | 0 |
Gross derivative liabilities | $ (1,806) | $ (1,488) |
Derivative Instruments - Effe51
Derivative Instruments - Effect of Derivative Instruments - Statement of Income Table (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | ||
Derivative [Line Items] | |||||
Total (gains) losses on derivatives, net | $ 24 | $ 281 | $ 634 | $ 123 | |
Commodity Derivatives [Member] | Gathering, Processing, and Marketing Sales [Member] | |||||
Derivative [Line Items] | |||||
Total (gains) losses on derivatives, net | [1] | (1) | (1) | 5 | 0 |
Commodity Derivatives [Member] | (Gains) Losses on Derivatives, Net [Member] | |||||
Derivative [Line Items] | |||||
Total (gains) losses on derivatives, net | (59) | (125) | 7 | (177) | |
Interest-Rate Derivatives [Member] | (Gains) Losses on Derivatives, Net [Member] | |||||
Derivative [Line Items] | |||||
Total (gains) losses on derivatives, net | $ 84 | $ 407 | $ 622 | $ 300 | |
[1] | Represents the effect of Marketing and Trading Derivative Activities. |
Derivative Instruments - Fair V
Derivative Instruments - Fair Value Table (Detail) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Millions | Sep. 30, 2016 | Dec. 31, 2015 | |
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | $ 121 | $ 526 | |
Gross derivative liabilities | (1,904) | (1,722) | |
Derivative assets netting | [1] | (14) | (178) |
Derivative liabilities netting | [1] | 14 | 178 |
Cash collateral from counterparties | 0 | (8) | |
Cash collateral held by counterparties | 424 | 58 | |
Derivative assets | 107 | 340 | |
Derivative liabilities | (1,466) | (1,486) | |
Commodity Derivatives [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 99 | 470 | |
Gross derivative liabilities | (50) | (180) | |
Derivative assets netting | [1] | (14) | (178) |
Derivative liabilities netting | [1] | 14 | 178 |
Cash collateral from counterparties | 0 | (8) | |
Cash collateral held by counterparties | 2 | 0 | |
Derivative assets | 85 | 284 | |
Derivative liabilities | (34) | (2) | |
Interest-Rate Derivatives [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 22 | 56 | |
Gross derivative liabilities | (1,854) | (1,542) | |
Derivative assets netting | [1] | 0 | 0 |
Derivative liabilities netting | [1] | 0 | 0 |
Cash collateral from counterparties | 0 | 0 | |
Cash collateral held by counterparties | 422 | 58 | |
Derivative assets | 22 | 56 | |
Derivative liabilities | (1,432) | (1,484) | |
Recurring [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 0 | 10 | |
Gross derivative liabilities | (1) | (1) | |
Recurring [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 121 | 516 | |
Gross derivative liabilities | (1,903) | (1,721) | |
Recurring [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 0 | 0 | |
Gross derivative liabilities | 0 | 0 | |
Recurring [Member] | Commodity Derivatives [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 0 | 10 | |
Gross derivative liabilities | (1) | (1) | |
Recurring [Member] | Commodity Derivatives [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 99 | 460 | |
Gross derivative liabilities | (49) | (179) | |
Recurring [Member] | Commodity Derivatives [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 0 | 0 | |
Gross derivative liabilities | 0 | 0 | |
Recurring [Member] | Interest-Rate Derivatives [Member] | Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 0 | 0 | |
Gross derivative liabilities | 0 | 0 | |
Recurring [Member] | Interest-Rate Derivatives [Member] | Fair Value, Inputs, Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 22 | 56 | |
Gross derivative liabilities | (1,854) | (1,542) | |
Recurring [Member] | Interest-Rate Derivatives [Member] | Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items] | |||
Gross derivative assets | 0 | 0 | |
Gross derivative liabilities | $ 0 | $ 0 | |
[1] | Represents the impact of netting commodity derivative assets and liabilities with counterparties where the Company has the contractual right and intends to net settle. |
Tangible Equity Units (Detail)
Tangible Equity Units (Detail) shares in Millions, $ in Millions | 9 Months Ended | ||
Sep. 30, 2016unit$ / unit | Sep. 30, 2015USD ($)$ / unitshares | Sep. 07, 2015$ / unit | |
Senior Note Component of 7.50% Tangible Equity Units [Member] | |||
Tangible Equity Units [Line Items] | |||
Tangible equity unit rate | 7.50% | ||
Principal amount per amortizing note | 10.95 | ||
Fixed annual rate | 1.50% | ||
Quarterly cash installment payment per amortizing note | 0.9375 | ||
First quarterly cash installment payment per amortizing note | 0.9063 | ||
Final installment payment date | Jun. 7, 2018 | ||
7.50% Tangible Equity Units [Member] | |||
Tangible Equity Units [Line Items] | |||
Number of tangible equity units issued | shares | 9.2 | ||
Tangible equity unit rate | 7.50% | ||
Stated amount per tangible equity unit | 50 | ||
Total net proceeds | $ | $ 445 | ||
Equity Component of 7.50% Tangible Equity Units [Member] | |||
Tangible Equity Units [Line Items] | |||
Purchase contract, mandatory settlement date | Jun. 7, 2018 | ||
Equity Component of 7.50% Tangible Equity Units [Member] | Settled in WGP Common Units [Member] | |||
Tangible Equity Units [Line Items] | |||
Maximum settlement rate | unit | 0.8591 | ||
Minimum settlement rate | unit | 0.7159 |
Debt and Interest Expense - Deb
Debt and Interest Expense - Debt Activity Table (Detail) $ in Millions | 9 Months Ended | |
Sep. 30, 2016USD ($) | ||
Debt Instrument [Line Items] | ||
Balance at December 31, 2015 | $ 15,648 | [1] |
Other, net | 41 | |
Balance at September 30, 2016 | 15,633 | [1] |
Western Gas Partners, LP [Member] | ||
Debt Instrument [Line Items] | ||
Balance at December 31, 2015 | 2,691 | [1] |
Other, net | 1 | |
Balance at September 30, 2016 | 2,907 | [1] |
Western Gas Equity Partners, LP excluding WES [Member] | ||
Debt Instrument [Line Items] | ||
Balance at December 31, 2015 | 0 | [1],[2] |
Other, net | 0 | [2] |
Balance at September 30, 2016 | 28 | [1],[2] |
Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Balance at December 31, 2015 | 12,957 | [1],[3] |
Other, net | 40 | [3] |
Balance at September 30, 2016 | 12,698 | [1],[3] |
364-Day Credit Facility Due 2017 [Member] | ||
Debt Instrument [Line Items] | ||
Borrowings, credit facility | 1,750 | |
Repayments, credit facility | (1,750) | |
364-Day Credit Facility Due 2017 [Member] | Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Borrowings, credit facility | 1,750 | [3] |
Repayments, credit facility | (1,750) | [3] |
WES RCF [Member] | ||
Debt Instrument [Line Items] | ||
Borrowings, credit facility | 600 | |
Repayments, credit facility | (880) | |
WES RCF [Member] | Western Gas Partners, LP [Member] | ||
Debt Instrument [Line Items] | ||
Borrowings, credit facility | 600 | |
Repayments, credit facility | (880) | |
WGP RCF [Member] | ||
Debt Instrument [Line Items] | ||
Borrowings, credit facility | 28 | |
WGP RCF [Member] | Western Gas Equity Partners, LP excluding WES [Member] | ||
Debt Instrument [Line Items] | ||
Borrowings, credit facility | 28 | [2] |
Commercial Paper [Member] | ||
Debt Instrument [Line Items] | ||
Repayments, commercial paper | (250) | |
Commercial Paper [Member] | Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Repayments, commercial paper | (250) | [3] |
4.850% Senior Notes Due 2021 [Member] | ||
Debt Instrument [Line Items] | ||
Issuances | $ 794 | |
Debt instrument, stated interest rate | 4.85% | |
Debt instrument, maturity date | Mar. 15, 2021 | |
4.850% Senior Notes Due 2021 [Member] | Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Issuances | $ 794 | [3] |
5.550% Senior Notes Due 2026 [Member] | ||
Debt Instrument [Line Items] | ||
Issuances | $ 1,088 | |
Debt instrument, stated interest rate | 5.55% | |
Debt instrument, maturity date | Mar. 15, 2026 | |
5.550% Senior Notes Due 2026 [Member] | Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Issuances | $ 1,088 | [3] |
6.600% Senior Notes Due 2046 [Member] | ||
Debt Instrument [Line Items] | ||
Issuances | $ 1,088 | |
Debt instrument, stated interest rate | 6.60% | |
Debt instrument, maturity date | Mar. 15, 2046 | |
6.600% Senior Notes Due 2046 [Member] | Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Issuances | $ 1,088 | [3] |
WES 4.650% Senior Notes Due 2026 [Member] | ||
Debt Instrument [Line Items] | ||
Issuances | $ 495 | |
Debt instrument, stated interest rate | 4.65% | |
Debt instrument, maturity date | Jul. 15, 2026 | |
WES 4.650% Senior Notes Due 2026 [Member] | Western Gas Partners, LP [Member] | ||
Debt Instrument [Line Items] | ||
Issuances | $ 495 | |
5.950% Senior Notes Due 2016 [Member] | ||
Debt Instrument [Line Items] | ||
Repayments, senior notes | $ (1,749) | |
Debt instrument, stated interest rate | 5.95% | |
Debt instrument, maturity date | Sep. 15, 2016 | |
5.950% Senior Notes Due 2016 [Member] | Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Repayments, senior notes | $ (1,749) | [3] |
Portion of 6.375% Senior Notes Due 2017 [Member] | ||
Debt Instrument [Line Items] | ||
Repayments, senior notes | (1,245) | |
Portion of 6.375% Senior Notes Due 2017 [Member] | Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Repayments, senior notes | (1,245) | [3] |
Senior Note Component of 7.50% Tangible Equity Units [Member] | ||
Debt Instrument [Line Items] | ||
Repayments, senior notes | $ (25) | |
Debt instrument, stated interest rate | 1.50% | |
Debt instrument, maturity date | Jun. 7, 2018 | |
Senior Note Component of 7.50% Tangible Equity Units [Member] | Anadarko excluding WES and WGP [Member] | ||
Debt Instrument [Line Items] | ||
Repayments, senior notes | $ (25) | [3] |
[1] | The Company’s outstanding borrowings, except for borrowings under the WGP revolving credit facility, are senior unsecured. | |
[2] | Excludes WES. | |
[3] | Excludes WES and WGP. |
Debt and Interest Expense - Add
Debt and Interest Expense - Additional Information (Detail) - USD ($) | Oct. 18, 2016 | Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | Dec. 31, 2015 |
Debt Instrument [Line Items] | ||||||
Debt instrument, principal amount | $ 17,285,000,000 | $ 17,285,000,000 | $ 17,312,000,000 | |||
Loss on early extinguishment of debt | 0 | $ 0 | 124,000,000 | $ 0 | ||
Premiums for early retirement and redemption of senior notes | 114,000,000 | |||||
FPSO capital lease obligation | 245,000,000 | 245,000,000 | 20,000,000 | |||
Five-Year Credit Facility [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Line of credit, maximum capacity | 3,000,000,000 | $ 3,000,000,000 | ||||
Debt instrument, term | 5 years | |||||
Line of credit, expiration date | Jan. 23, 2021 | |||||
Line of credit, outstanding borrowings | 0 | $ 0 | ||||
364-Day Credit Facility Due 2017 [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Line of credit, maximum capacity | 2,000,000,000 | $ 2,000,000,000 | ||||
Debt instrument, term | 364 days | |||||
Line of credit, expiration date | Jan. 15, 2017 | |||||
Line of credit, outstanding borrowings | 0 | $ 0 | ||||
Commercial Paper [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Line of credit, maximum capacity | 3,000,000,000 | 3,000,000,000 | ||||
Commercial paper, outstanding borrowings | 0 | $ 0 | ||||
Commercial Paper [Member] | Maximum [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Debt instrument, term | 397 days | |||||
WES RCF [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Line of credit, maximum capacity | 1,200,000,000 | $ 1,200,000,000 | ||||
Debt instrument, term | 5 years | |||||
Line of credit, expiration date | Feb. 26, 2019 | |||||
Line of credit, outstanding borrowings | $ 20,000,000 | $ 20,000,000 | ||||
Line of credit, interest rate | 1.82% | 1.82% | ||||
Line of credit, available borrowing capacity | $ 1,180,000,000 | $ 1,180,000,000 | ||||
Line of credit, expandable maximum capacity | 1,500,000,000 | 1,500,000,000 | ||||
Letters of credit, outstanding | 5,000,000 | 5,000,000 | ||||
WGP RCF [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Line of credit, maximum capacity | 250,000,000 | $ 250,000,000 | ||||
Debt instrument, term | 3 years | |||||
Line of credit, expiration date | Mar. 14, 2019 | |||||
Line of credit, outstanding borrowings | $ 28,000,000 | $ 28,000,000 | ||||
Line of credit, interest rate | 2.53% | 2.53% | ||||
Line of credit, available borrowing capacity | $ 222,000,000 | $ 222,000,000 | ||||
Line of credit, expandable maximum capacity | 500,000,000 | $ 500,000,000 | ||||
WGP RCF [Member] | London Interbank Offered Rate (LIBOR) [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Line of credit, variable rate floor | 0.00% | |||||
WGP RCF [Member] | London Interbank Offered Rate (LIBOR) [Member] | Alternate Base Rate [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Applicable margin added | 1.00% | |||||
WGP RCF [Member] | Percentage Above Federal Funds Effective Rate [Member] | Alternate Base Rate [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Applicable margin added | 0.50% | |||||
WGP RCF [Member] | Minimum [Member] | London Interbank Offered Rate (LIBOR) [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Applicable margin added | 2.00% | |||||
WGP RCF [Member] | Minimum [Member] | Base Rate [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Applicable margin added | 1.00% | |||||
WGP RCF [Member] | Maximum [Member] | London Interbank Offered Rate (LIBOR) [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Applicable margin added | 2.75% | |||||
WGP RCF [Member] | Maximum [Member] | Base Rate [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Applicable margin added | 1.75% | |||||
Fair Value, Inputs, Level 2 [Member] | Market Approach Valuation Technique [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Estimated fair value of total borrowings | 17,600,000,000 | $ 17,600,000,000 | $ 15,700,000,000 | |||
Senior Notes 1 Through 3 [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Debt instrument, principal amount | 3,000,000,000 | 3,000,000,000 | ||||
Portion of 6.375% Senior Notes Due 2017 [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Amount of debt extinguished | 1,250,000,000 | |||||
6.375% Senior Notes Due 2017 [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Debt instrument, principal amount | $ 2,000,000,000 | $ 2,000,000,000 | ||||
Debt instrument, stated interest rate | 6.375% | 6.375% | ||||
Debt instrument, maturity date | Sep. 15, 2017 | |||||
5.950% Senior Notes Due 2016 [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Amount of debt extinguished | $ 1,750,000,000 | |||||
Debt instrument, stated interest rate | 5.95% | 5.95% | ||||
Debt instrument, maturity date | Sep. 15, 2016 | |||||
Zero-Coupon Senior Notes [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Debt instrument, maturity date | Oct. 10, 2036 | |||||
Debt Instrument, earliest call date | Oct. 10, 2016 | |||||
Zero-Coupon Senior Notes [Member] | Accreted Value at Next Potential Put Date [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Debt instrument, accreted value | $ 839,000,000 | $ 839,000,000 | ||||
WES 4.650% Senior Notes Due 2026 [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Debt instrument, principal amount | $ 500,000,000 | $ 500,000,000 | ||||
Debt instrument, stated interest rate | 4.65% | 4.65% | ||||
Debt instrument, maturity date | Jul. 15, 2026 | |||||
WES 5.450% Senior Notes Due 2044 | Subsequent Event [Member] | ||||||
Debt Instrument [Line Items] | ||||||
Debt instrument, principal amount | $ 200,000,000 | |||||
Debt instrument, stated interest rate | 5.45% | |||||
Debt instrument, maturity date | Apr. 1, 2044 | |||||
FPSO Capital Lease [Member] | ||||||
Debt Instrument [Line Items] | ||||||
FPSO nonoperated working interest | 19.00% | 19.00% | ||||
FPSO capital lease asset | $ 225,000,000 | $ 225,000,000 | ||||
FPSO capital lease obligation | $ 225,000,000 | $ 225,000,000 | ||||
FPSO capital lease initial term | 10 years | |||||
FPSO capital lease additional term | 10 years |
Debt and Interest Expense - Out
Debt and Interest Expense - Outstanding Debt Table (Detail) - USD ($) $ in Millions | 9 Months Ended | |||
Sep. 30, 2016 | Dec. 31, 2015 | |||
Debt Instrument [Line Items] | ||||
Total borrowings at face value | $ 17,285 | $ 17,312 | ||
Net unamortized discounts, premiums, and debt issuance costs (3) | [1] | (1,652) | (1,664) | |
Total borrowings (4) | [2] | 15,633 | 15,648 | |
Capital lease obligations | 245 | 20 | ||
Less short-term debt (5) | 788 | [3] | 32 | |
Total long-term debt | 15,090 | 15,636 | ||
Portion of 6.375% Senior Notes Due 2017 [Member] | ||||
Debt Instrument [Line Items] | ||||
Less short-term debt (5) | 750 | |||
6.375% Senior Notes Due 2017 [Member] | ||||
Debt Instrument [Line Items] | ||||
Total borrowings at face value | $ 2,000 | |||
Debt instrument, stated interest rate | 6.375% | |||
Debt instrument, maturity date | Sep. 15, 2017 | |||
Western Gas Partners, LP [Member] | ||||
Debt Instrument [Line Items] | ||||
Total borrowings at face value | $ 2,940 | 2,720 | ||
Net unamortized discounts, premiums, and debt issuance costs (3) | [1] | (33) | (29) | |
Total borrowings (4) | [2] | 2,907 | 2,691 | |
Capital lease obligations | 0 | 0 | ||
Less short-term debt (5) | 0 | 0 | ||
Total long-term debt | 2,907 | 2,691 | ||
Western Gas Equity Partners, LP excluding WES [Member] | ||||
Debt Instrument [Line Items] | ||||
Total borrowings at face value | [4] | 28 | 0 | |
Net unamortized discounts, premiums, and debt issuance costs (3) | [1],[4] | 0 | 0 | |
Total borrowings (4) | [2],[4] | 28 | 0 | |
Capital lease obligations | [4] | 0 | 0 | |
Less short-term debt (5) | [4] | 0 | 0 | |
Total long-term debt | [4] | 28 | 0 | |
Anadarko excluding WES and WGP [Member] | ||||
Debt Instrument [Line Items] | ||||
Total borrowings at face value | [5] | 14,317 | 14,592 | |
Net unamortized discounts, premiums, and debt issuance costs (3) | [1],[5] | (1,619) | (1,635) | |
Total borrowings (4) | [2],[5] | 12,698 | 12,957 | |
Capital lease obligations | [5] | 245 | 20 | |
Less short-term debt (5) | [5] | 788 | [3] | 32 |
Total long-term debt | [5] | $ 12,155 | $ 12,945 | |
[1] | Unamortized discounts, premiums, and debt issuance costs are amortized over the term of the related debt. Debt issuance costs related to revolving credit facilities are included in other current assets and other assets on the Company’s Consolidated Balance Sheets. | |||
[2] | The Company’s outstanding borrowings, except for borrowings under the WGP revolving credit facility, are senior unsecured. | |||
[3] | Short-term debt includes $750 million of 6.375% Senior Notes due September 2017. In October 2016, the Company provided notice of its intent to redeem the notes prior to year end. | |||
[4] | Excludes WES. | |||
[5] | Excludes WES and WGP. |
Debt and Interest Expense - Cap
Debt and Interest Expense - Capital Lease Obligations (Detail) - USD ($) $ in Millions | Sep. 30, 2016 | Dec. 31, 2015 |
Debt Disclosure [Abstract] | ||
2,016 | $ 16 | |
2,017 | 42 | |
2,018 | 42 | |
2,019 | 42 | |
2,020 | 42 | |
Remaining years | 433 | |
Total future minimum lease payments | 617 | |
Less portion representing imputed interest | 372 | |
Capital lease obligations | $ 245 | $ 20 |
Debt and Interest Expense - Int
Debt and Interest Expense - Interest Expense Table (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Debt Disclosure [Abstract] | ||||
Debt and other | $ 251 | $ 245 | $ 768 | $ 743 |
Capitalized interest | (31) | (46) | (111) | (127) |
Total interest expense | $ 220 | $ 199 | $ 657 | $ 616 |
Income Taxes - Income Tax Expen
Income Taxes - Income Tax Expense (Benefit) Table (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Income Tax Disclosure [Abstract] | ||||
Income tax expense (benefit) | $ (260) | $ (917) | $ (957) | $ (2,232) |
Income (loss) before income taxes | $ (1,007) | $ (3,077) | $ (3,313) | $ (7,520) |
Effective tax rate | 26.00% | 30.00% | 29.00% | 30.00% |
Income Taxes - Additional Infor
Income Taxes - Additional Information (Detail) | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Income Tax Disclosure [Abstract] | ||||
U.S. federal statutory rate | 35.00% | 35.00% | 35.00% | 35.00% |
Conveyance of Future Hard Min61
Conveyance of Future Hard Minerals Royalty Revenues - Additional Information (Detail) - USD ($) $ in Millions | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Mar. 31, 2016 | |
Deferred Revenue Disclosure [Abstract] | |||
Proceeds from conveyance of future hard minerals royalty revenues, net of transaction costs | $ 413 | $ 0 | |
Maximum amount of total future royalty revenue third-party is entitled to | 528 | $ 553 | |
Deferred Revenue Arrangement [Line Items] | |||
Amount of deferred revenue amortized in period | 27 | ||
Payments of future hard minerals royalty revenues conveyed | $ 25 | $ 0 | |
Royalties Between $800 and $900 Million During the First 10 Years [Member] | |||
Deferred Revenue Arrangement [Line Items] | |||
Percentage of excess royalties | 3.00% | ||
Baseline amount of excess royalties | $ 800 | ||
Royalties In Excess Of $900 Million During the First 10 Years [Member] | |||
Deferred Revenue Arrangement [Line Items] | |||
Percentage of excess royalties | 4.00% | ||
Baseline amount of excess royalties | $ 900 | ||
Minimum [Member] | |||
Deferred Revenue Arrangement [Line Items] | |||
Term of conveyance | 10 years | ||
Maximum [Member] | |||
Deferred Revenue Arrangement [Line Items] | |||
Term of conveyance | 15 years |
Conveyance of Future Hard Min62
Conveyance of Future Hard Minerals Royalty Revenues - Schedule of Future Royalty Payments (Detail) - USD ($) $ in Millions | Sep. 30, 2016 | Mar. 31, 2016 |
Deferred Revenue Disclosure [Abstract] | ||
2,017 | $ 50 | |
2,018 | 50 | |
2,019 | 52 | |
2,020 | 56 | |
2,021 | 57 | |
Later years | 263 | |
Total | $ 528 | $ 553 |
Contingencies (Detail)
Contingencies (Detail) - USD ($) $ in Millions | 3 Months Ended | 12 Months Ended | |
Mar. 31, 2016 | Dec. 31, 2015 | Sep. 30, 2011 | |
Macondo Exploration Well [Member] | |||
Loss Contingencies [Line Items] | |||
Nonoperated interest | 25.00% | ||
Deepwater Horizon [Member] | Judicial Ruling [Member] | Clean Water Act [Member] | |||
Loss Contingencies [Line Items] | |||
CWA penalty | $ 159.5 | ||
Amount of penalty paid | $ 159.5 |
Restructuring Charges - Schedul
Restructuring Charges - Schedule of Resctucturing Charges (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | ||
Restructuring Cost and Reserve [Line Items] | |||||
Total expected restructuring charges | $ 410 | $ 410 | |||
Restructuring charges | 112 | $ 0 | 363 | $ 0 | |
General and Administrative Expense [Member] | |||||
Restructuring Cost and Reserve [Line Items] | |||||
Restructuring charges | 112 | 363 | |||
Cash Severance [Member] | |||||
Restructuring Cost and Reserve [Line Items] | |||||
Total expected restructuring charges | 154 | 154 | |||
Cash Severance [Member] | General and Administrative Expense [Member] | |||||
Restructuring Cost and Reserve [Line Items] | |||||
Restructuring charges | 5 | 151 | |||
Retirement Benefits [Member] | |||||
Restructuring Cost and Reserve [Line Items] | |||||
Total expected restructuring charges | [1] | 219 | 219 | ||
Retirement Benefits [Member] | General and Administrative Expense [Member] | |||||
Restructuring Cost and Reserve [Line Items] | |||||
Restructuring charges | [1] | 102 | 178 | ||
Share-based Compensation [Member] | |||||
Restructuring Cost and Reserve [Line Items] | |||||
Total expected restructuring charges | 37 | 37 | |||
Share-based Compensation [Member] | General and Administrative Expense [Member] | |||||
Restructuring Cost and Reserve [Line Items] | |||||
Restructuring charges | 5 | 34 | |||
Amount to be Recognized in 2017 [Member] | Retirement Benefits [Member] | |||||
Restructuring Cost and Reserve [Line Items] | |||||
Total expected restructuring charges | $ 17 | $ 17 | |||
[1] | Includes termination benefits, curtailments, and settlements. See Note 13—Pension Plans and Other Postretirement Benefits. |
Restructuring Charges - Rollfor
Restructuring Charges - Rollforward of Cash Severance-related Liability (Detail) - Cash Severance [Member] $ in Millions | 9 Months Ended |
Sep. 30, 2016USD ($) | |
Restructuring Cost and Reserve [Line Items] | |
Accruals | $ 151 |
Payments | (141) |
Accounts Payable [Member] | |
Restructuring Cost and Reserve [Line Items] | |
Balance at January 1 | 0 |
Balance at September 30 | $ 10 |
Pension Plans and Other Postr66
Pension Plans and Other Postretirement Benefits - Components of Net Periodic Benefit Cost Table (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Pension Plan [Member] | ||||
Components of net periodic benefit cost | ||||
Service cost | $ 24 | $ 30 | $ 73 | $ 89 |
Interest cost | 24 | 25 | 73 | 76 |
Expected return on plan assets | (24) | (27) | (75) | (82) |
Amortization of net actuarial loss (gain) | 12 | 13 | 30 | 39 |
Amortization of net prior service cost (credit) | 0 | 0 | 0 | 0 |
Settlement expense | 102 | 0 | 126 | 0 |
Termination benefits expense | 44 | 0 | ||
Curtailment expense | 8 | 0 | ||
Net periodic benefit cost | 138 | 41 | 279 | 122 |
Other Postretirement Benefit Plans [Member] | ||||
Components of net periodic benefit cost | ||||
Service cost | 1 | 3 | 2 | 8 |
Interest cost | 3 | 3 | 9 | 11 |
Expected return on plan assets | 0 | 0 | 0 | 0 |
Amortization of net actuarial loss (gain) | 0 | 0 | 0 | 0 |
Amortization of net prior service cost (credit) | (6) | 1 | (18) | 2 |
Settlement expense | 0 | 0 | 0 | 0 |
Termination benefits expense | 0 | 0 | ||
Curtailment expense | 0 | 0 | ||
Net periodic benefit cost | $ (2) | $ 7 | $ (7) | $ 21 |
Pension Plans and Other Postr67
Pension Plans and Other Postretirement Benefits - Additional Information (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | Dec. 31, 2015 | |
Defined Benefit Plan Disclosure [Line Items] | |||||
Corresponding decrease in other comprehensive income related to the net liability increase | $ 157 | $ 0 | $ 347 | $ 0 | |
Pension Plan [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net liability increase for the period | 327 | ||||
Corresponding decrease in other comprehensive income related to the net liability increase | 327 | ||||
Other Postretirement Benefit Plans [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Net liability increase for the period | 24 | ||||
Corresponding decrease in other comprehensive income related to the net liability increase | 24 | ||||
Unfunded Pension Plans [Member] | Pension Plan [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Expected future employer contributions | $ 25 | ||||
Unfunded Pension Plans [Member] | Pension Plan [Member] | Retirement Benefits [Member] | |||||
Defined Benefit Plan Disclosure [Line Items] | |||||
Expected future employer contributions | 23 | ||||
Expected employer contributions in 2016 | $ 82 |
Stockholders' Equity - Addition
Stockholders' Equity - Additional Information (Detail) $ / shares in Units, shares in Millions, $ in Millions | 9 Months Ended |
Sep. 30, 2016USD ($)$ / sharesshares | |
Equity [Abstract] | |
Common stock issued during the period | shares | 40.5 |
Price per share of common stock issued during the period | $ / shares | $ 53.23 |
Proceeds from issuance of common stock | $ | $ 2,160 |
Stockholders' Equity - Earnings
Stockholders' Equity - Earnings Per Share Reconciliation Table (Detail) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Net income (loss) | ||||
Net income (loss) attributable to common stockholders | $ (830) | $ (2,235) | $ (2,556) | $ (5,442) |
Income (loss) effect of TEUs | (2) | (3) | (5) | (3) |
Less distributions on participating securities | 1 | 1 | 1 | 4 |
Basic | (833) | (2,239) | (2,562) | (5,449) |
Income (loss) effect of TEUs | 0 | 0 | (1) | 0 |
Diluted | $ (833) | $ (2,239) | $ (2,563) | $ (5,449) |
Shares | ||||
Average number of common shares outstanding—basic | 517 | 508 | 512 | 508 |
Average number of common shares outstanding—diluted | 517 | 508 | 512 | 508 |
Excluded due to anti-dilutive effect | 11 | 10 | 11 | 11 |
Net income (loss) per common share | ||||
Basic | $ (1.61) | $ (4.41) | $ (5) | $ (10.73) |
Diluted | $ (1.61) | $ (4.41) | $ (5) | $ (10.73) |
Accumulated Other Comprehensi70
Accumulated Other Comprehensive Income (Loss) (Detail) $ in Millions | 9 Months Ended |
Sep. 30, 2016USD ($) | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward] | |
Balance | $ 15,457 |
Other comprehensive income (loss), before reclassifications | (219) |
Reclassifications to Consolidated Statement of Income | 84 |
Balance | 15,912 |
Interest-rate Derivatives Previously Subject to Hedge Accounting [Member] | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward] | |
Balance | (42) |
Other comprehensive income (loss), before reclassifications | 0 |
Reclassifications to Consolidated Statement of Income | 4 |
Balance | (38) |
Pension and Other Postretirement Plans [Member] | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward] | |
Balance | (341) |
Other comprehensive income (loss), before reclassifications | (219) |
Reclassifications to Consolidated Statement of Income | 80 |
Balance | (480) |
Accumulated Other Comprehensive Income (Loss) [Member] | |
Accumulated Other Comprehensive Income (Loss), Net of Tax [Roll Forward] | |
Balance | (383) |
Balance | $ (518) |
Noncontrolling Interests (Detai
Noncontrolling Interests (Detail) - USD ($) shares in Thousands, $ in Millions | 3 Months Ended | 9 Months Ended | 12 Months Ended | |
Jun. 30, 2016 | Mar. 31, 2016 | Sep. 30, 2016 | Dec. 31, 2015 | |
Western Gas Equity Partners, LP [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Common units issued to the public | 12,500 | |||
Net proceeds from common units | $ 476 | |||
Western Gas Equity Partners, LP [Member] | Limited Partner [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Ownership interest in subsidiary | 81.60% | |||
Public ownership interest in subsidiary | 18.40% | |||
Western Gas Partners, LP [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Units issued in private placement | 1,300 | |||
Common units issued to the public | 874 | |||
Net proceeds from common units | $ 57 | |||
Western Gas Partners, LP [Member] | Limited Partner [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Public ownership interest in subsidiary | 60.00% | |||
Western Gas Partners, LP [Member] | Limited Partner [Member] | Western Gas Equity Partners, LP Ownership Interest in Western Gas Partners, LP [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Ownership interest in subsidiary | 30.00% | |||
Western Gas Partners, LP [Member] | Limited Partner [Member] | Anadarko Limited Partner Interest in WES Owned Through Other Subsidiaries [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Ownership interest in subsidiary | 8.50% | |||
Western Gas Partners, LP [Member] | General Partner [Member] | Western Gas Equity Partners, LP Ownership Interest in Western Gas Partners, LP [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Ownership interest in subsidiary | 1.50% | |||
Series A Preferred Units [Member] | Western Gas Partners, LP [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Units issued in private placement | 8,000 | 14,000 | ||
Net proceeds from Series A preferred units | $ 247 | $ 440 | ||
Class C Units [Member] | Western Gas Partners, LP [Member] | ||||
Noncontrolling Interest [Line Items] | ||||
Units issued in private placement | 749 | 498 |
Variable Interest Entities (Det
Variable Interest Entities (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | Dec. 31, 2015 | |
Variable Interest Entity [Line Items] | |||||
Interest income for WES | $ 251 | $ 245 | $ 768 | $ 743 | |
Variable Interest Entity, Primary Beneficiary [Member] | Western Gas Partners, LP [Member] | |||||
Variable Interest Entity [Line Items] | |||||
Note receivable for WES | $ 260 | $ 260 | |||
Debt instrument, term | 30 years | ||||
Fixed annual rate | 6.50% | 6.50% | |||
Interest income for WES | $ 5 | $ 5 | $ 13 | 13 | |
Deferred purchase price obligation - Anadarko | $ 16 | 16 | $ 189 | ||
Above-market component of swap extensions with Anadarko | $ 35 | $ 8 |
Supplemental Cash Flow Inform73
Supplemental Cash Flow Information (Detail) - USD ($) $ in Millions | 9 Months Ended | ||||
Sep. 30, 2016 | Sep. 30, 2015 | ||||
Cash (paid) received | |||||
Interest, net of amounts capitalized (1) | $ 735 | $ 1,916 | [1] | ||
Income taxes, net of refunds (2) | (878) | [2] | (163) | ||
Non-cash investing activities | |||||
Fair value of properties and equipment from non-cash transactions | 2 | 156 | |||
Asset retirement cost additions | 85 | 139 | |||
Accruals of property, plant, and equipment | 454 | 858 | |||
Net liabilities assumed (divested) in acquisitions and divestitures | (39) | (84) | |||
Non-cash investing and financing activities | |||||
Capital lease obligation (3) | [3] | 10 | 0 | ||
Floating production, storage, and offloading unit construction period obligation (3) | [3] | 11 | 51 | ||
Deferred drilling lease liability | 3 | 0 | |||
Related to Net Operating Loss Carryback [Member] | |||||
Cash (paid) received | |||||
Income taxes, net of refunds (2) | $ 881 | ||||
Tronox Litigation [Member] | Judicial Ruling [Member] | |||||
Cash (paid) received | |||||
Interest, net of amounts capitalized (1) | $ 1,200 | ||||
[1] | Includes $1.2 billion of interest related to the Tronox settlement payment in 2015. | ||||
[2] | Includes $881 million from a tax refund related to the income tax benefit associated with the Company’s 2015 tax net operating loss carryback. | ||||
[3] | Upon completion of the FPSO during the third quarter of 2016, the Company reported the construction period obligation as a capital lease obligation and recorded a fair-value adjustment. See Note 8—Debt and Interest Expense. |
Segment Information - Additiona
Segment Information - Additional Information (Detail) | 9 Months Ended |
Sep. 30, 2016Segment | |
Segment Reporting [Abstract] | |
Number of reporting segments | 3 |
Midstream Reporting Segment [Member] | |
Segment Reporting Information [Line Items] | |
Number of operating segments | 2 |
Segment Information - Reconcili
Segment Information - Reconciliation of Consolidated Adjusted EBITDAX to Income (Loss) Before Income Taxes (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | |
Segment Reporting [Abstract] | ||||
Income (loss) before income taxes | $ (1,007) | $ (3,077) | $ (3,313) | $ (7,520) |
(Gains) losses on divestitures, net | 414 | 578 | 516 | 1,003 |
Exploration expense | 304 | 1,074 | 506 | 2,260 |
DD&A | 1,069 | 1,111 | 3,202 | 3,581 |
Impairments | 27 | 758 | 61 | 3,571 |
Interest expense | 220 | 199 | 657 | 616 |
Total (gains) losses on derivatives, net, less net cash from settlement of commodity derivatives | 88 | 360 | 863 | 374 |
Restructuring charges | 112 | 0 | 363 | 0 |
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Loss on early extinguishment of debt | 0 | 0 | 124 | 0 |
Net income (loss) attributable to noncontrolling interests | 83 | 75 | 200 | 154 |
Consolidated Adjusted EBITDAX | 1,144 | 928 | 2,724 | 3,762 |
Certain Other Nonoperating Items [Member] | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Certain other nonoperating items | 0 | 0 | (56) | 22 |
Deepwater Horizon [Member] | Pending Litigation [Member] | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Other operating expense | 0 | 4 | ||
Deepwater Horizon [Member] | Judicial Ruling [Member] | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Other operating expense | 0 | 1 | ||
Tronox Litigation [Member] | Judicial Ruling [Member] | ||||
Segment Reporting, Reconciling Item for Operating Profit (Loss) from Segment to Consolidated [Line Items] | ||||
Other operating expense | $ 0 | $ 0 | 0 | 5 |
Certain other nonoperating items | $ 0 | $ (5,210) |
Segment Information - Selected
Segment Information - Selected Financial Information for Anadarko's Reporting Segments Table (Detail) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||||
Sep. 30, 2016 | Sep. 30, 2015 | Sep. 30, 2016 | Sep. 30, 2015 | ||||
Segment Reporting Information [Line Items] | |||||||
Revenues | $ 2,251 | $ 2,230 | $ 5,870 | $ 7,452 | |||
Other | 56 | 36 | 128 | 196 | |||
Total revenues and other (1) | 1,893 | 1,688 | 5,482 | 6,645 | |||
Operating costs and expenses (2) | 2,686 | 4,237 | 7,471 | 13,312 | |||
Net cash from settlement of commodity derivatives | (229) | (251) | |||||
Other (income) expense, net | (31) | 47 | (86) | 109 | |||
Net income (loss) attributable to noncontrolling interests | 83 | 75 | 200 | 154 | |||
Total expenses and other | 1,163 | 1,337 | 3,282 | 3,886 | |||
Consolidated Adjusted EBITDAX | 1,144 | 928 | 2,724 | 3,762 | |||
(Gains) Losses on Derivatives, Net [Member] | Commodity Contract [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Net cash from settlement of commodity derivatives | (63) | (79) | (226) | (251) | |||
Gathering, Processing, and Marketing Sales [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total (gains) losses on derivatives, net included in marketing revenue, less net cash from settlement | (1) | 8 | |||||
Excluding Gains Losses On Divestitures Net [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total revenues and other (1) | [1] | 2,307 | 2,266 | 5,998 | 7,648 | ||
Excluding Certain Items [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating costs and expenses (2) | [2] | 1,174 | 1,294 | 3,338 | 3,896 | ||
Excluding Certain Other Nonoperating Items [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Other (income) expense, net | (31) | 47 | (30) | [3] | 87 | [3] | |
Other and Intersegment Eliminations [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Other | 56 | 36 | 128 | 196 | |||
Total expenses and other | (173) | (46) | (489) | (274) | |||
Consolidated Adjusted EBITDAX | (17) | (151) | (100) | (225) | |||
Other and Intersegment Eliminations [Member] | (Gains) Losses on Derivatives, Net [Member] | Commodity Contract [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Net cash from settlement of commodity derivatives | (63) | (79) | (226) | (251) | |||
Other and Intersegment Eliminations [Member] | Excluding Gains Losses On Divestitures Net [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total revenues and other (1) | [1] | (190) | (197) | (589) | (499) | ||
Other and Intersegment Eliminations [Member] | Excluding Certain Items [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating costs and expenses (2) | [2] | (79) | (14) | (233) | (110) | ||
Other and Intersegment Eliminations [Member] | Excluding Certain Other Nonoperating Items [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Other (income) expense, net | (31) | 47 | (30) | [3] | 87 | [3] | |
Other and Intersegment Eliminations [Member] | Intersegment Revenues [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Revenues | (246) | (233) | (717) | (695) | |||
Oil and Gas Exploration and Production Reporting Segment [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Revenues | 1,109 | 1,067 | 2,853 | 3,493 | |||
Oil and Gas Exploration and Production Reporting Segment [Member] | Intersegment Revenues [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Revenues | 717 | 750 | 1,885 | 2,752 | |||
Oil and Gas Exploration and Production Reporting Segment [Member] | Operating Segments [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total expenses and other | 807 | 840 | 2,370 | 2,674 | |||
Consolidated Adjusted EBITDAX | 1,019 | 977 | 2,368 | 3,571 | |||
Oil and Gas Exploration and Production Reporting Segment [Member] | Operating Segments [Member] | Excluding Gains Losses On Divestitures Net [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total revenues and other (1) | [1] | 1,826 | 1,817 | 4,738 | 6,245 | ||
Oil and Gas Exploration and Production Reporting Segment [Member] | Operating Segments [Member] | Excluding Certain Items [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating costs and expenses (2) | [2] | 807 | 840 | 2,370 | 2,674 | ||
Midstream Reporting Segment [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Revenues | 174 | 195 | 440 | 560 | |||
Midstream Reporting Segment [Member] | Intersegment Revenues [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Revenues | 370 | 315 | 1,012 | 920 | |||
Midstream Reporting Segment [Member] | Operating Segments [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Net income (loss) attributable to noncontrolling interests | 83 | 75 | 200 | 154 | |||
Total expenses and other | 356 | 362 | 875 | 915 | |||
Consolidated Adjusted EBITDAX | 188 | 148 | 577 | 565 | |||
Midstream Reporting Segment [Member] | Operating Segments [Member] | Excluding Gains Losses On Divestitures Net [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total revenues and other (1) | [1] | 544 | 510 | 1,452 | 1,480 | ||
Midstream Reporting Segment [Member] | Operating Segments [Member] | Excluding Certain Items [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating costs and expenses (2) | [2] | 273 | 287 | 675 | 761 | ||
Marketing Reporting Segment [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Revenues | 968 | 968 | 2,577 | 3,399 | |||
Marketing Reporting Segment [Member] | Intersegment Revenues [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Revenues | (841) | (832) | (2,180) | (2,977) | |||
Marketing Reporting Segment [Member] | Operating Segments [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total expenses and other | 173 | 181 | 526 | 571 | |||
Consolidated Adjusted EBITDAX | (46) | (46) | (121) | (149) | |||
Marketing Reporting Segment [Member] | Operating Segments [Member] | Gathering, Processing, and Marketing Sales [Member] | Commodity Contract [Member] | Not Designated as Hedging Instrument [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total (gains) losses on derivatives, net included in marketing revenue, less net cash from settlement | (1) | 8 | |||||
Marketing Reporting Segment [Member] | Operating Segments [Member] | Excluding Gains Losses On Divestitures Net [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Total revenues and other (1) | [1] | 127 | 136 | 397 | 422 | ||
Marketing Reporting Segment [Member] | Operating Segments [Member] | Excluding Certain Items [Member] | |||||||
Segment Reporting Information [Line Items] | |||||||
Operating costs and expenses (2) | [2] | $ 173 | $ 181 | $ 526 | $ 571 | ||
[1] | Total revenues and other excludes gains (losses) on divestitures, net since these gains and losses are excluded from Adjusted EBITDAX. | ||||||
[2] | Operating costs and expenses excludes exploration expense, DD&A, impairments, restructuring charges, and other operating expense since these expenses are excluded from Adjusted EBITDAX. | ||||||
[3] | Other (income) expense, net excludes certain other nonoperating items since these items are excluded from Adjusted EBITDAX. |