Document and Entity Information
Document and Entity Information - shares | 9 Months Ended | |
Sep. 30, 2015 | Oct. 31, 2015 | |
Document and Entity Information [Abstract] | ||
Document Type | 10-Q | |
Document Period End Date | Sep. 30, 2015 | |
Document Fiscal Period Focus | Q3 | |
Document Fiscal Year Focus | 2,015 | |
Amendment Flag | false | |
Entity Registrant Name | Marathon Oil Corp | |
Entity Central Index Key | 101,778 | |
Entity Current Reporting Status | Yes | |
Entity Voluntary Filers | No | |
Current Fiscal Year End Date | --12-31 | |
Entity Filer Category | Large Accelerated Filer | |
Entity Well Known Seasoned Issuer | Yes | |
Entity Common Stock Shares Outstanding | 677,260,116 |
Consolidated Statements of Inco
Consolidated Statements of Income - USD ($) shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Revenues and other income: | ||||
Sales and other operating revenues, including related party | $ 1,300 | $ 2,316 | $ 3,887 | $ 6,735 |
Marketing revenues | 84 | 554 | 471 | 1,713 |
Income from equity method investments | 36 | 89 | 98 | 346 |
Net loss on disposal of assets | (109) | (3) | (108) | (88) |
Other income | 12 | 15 | 38 | 55 |
Total revenues and other income | 1,323 | 2,971 | 4,386 | 8,761 |
Costs and expenses: | ||||
Production | 406 | 593 | 1,300 | 1,697 |
Marketing, including purchases from related parties | 84 | 554 | 471 | 1,710 |
Other operating | 93 | 99 | 281 | 303 |
Exploration | 585 | 96 | 786 | 314 |
Depreciation, depletion and amortization | 717 | 737 | 2,289 | 2,060 |
Impairments | 337 | 109 | 381 | 130 |
Taxes other than income | 46 | 115 | 191 | 319 |
General and administrative | 125 | 160 | 464 | 486 |
Total costs and expenses | 2,393 | 2,463 | 6,163 | 7,019 |
Income (loss) from operations | (1,070) | 508 | (1,777) | 1,742 |
Net interest and other | (75) | (55) | (180) | (180) |
Income (loss) from continuing operations before income taxes | (1,145) | 453 | (1,957) | 1,562 |
Provision (benefit) for income taxes | (396) | 149 | (546) | 500 |
Income (loss) from continuing operations | (749) | 304 | (1,411) | 1,062 |
Discontinued operations | 0 | 127 | 0 | 1,058 |
Net income (loss) | $ (749) | $ 431 | $ (1,411) | $ 2,120 |
Basic: | ||||
Income (loss) from continuing operations per basic share | $ (1.11) | $ 0.45 | $ (2.09) | $ 1.56 |
Discontinued operations per basic share | 0 | 0.19 | 0 | 1.55 |
Net income (loss), per basic share | (1.11) | 0.64 | (2.09) | 3.11 |
Diluted: | ||||
Income (loss) from continuing operations per diluted share | (1.11) | 0.45 | (2.09) | 1.55 |
Discontinued operations per diluted share | 0 | 0.19 | 0 | 1.55 |
Net income (loss), per diluted share | (1.11) | 0.64 | (2.09) | 3.10 |
Dividends paid, per share | $ 0.21 | $ 0.21 | $ 0.63 | $ 0.59 |
Weighted average common shares outstanding, basic | 677 | 675 | 677 | 681 |
Weighted average common shares outstanding, diluted | 677 | 678 | 677 | 684 |
Consolidated Statements of Comp
Consolidated Statements of Comprehensive Income - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Statement of Comprehensive Income [Abstract] | ||||
Net income (loss) | $ (749) | $ 431 | $ (1,411) | $ 2,120 |
Postretirement and postemployment plans | ||||
Change in actuarial loss and other | (2) | 3 | 160 | (40) |
Income tax benefit (provision) on postretirement and postemployment plans | (1) | (2) | (58) | 13 |
Postretirement and postemployment plans, net of tax | (3) | 1 | 102 | (27) |
Comprehensive income (loss) | $ (752) | $ 432 | $ (1,309) | $ 2,093 |
Consolidated Balance Sheets
Consolidated Balance Sheets - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Current assets: | ||
Cash and cash equivalents | $ 1,680 | $ 2,398 |
Short-term Investments | 700 | 0 |
Receivables, less reserve of $4 and $3 | 991 | 1,729 |
Inventories | 324 | 357 |
Other current assets | 163 | 109 |
Total current assets | 3,858 | 4,593 |
Equity method investments | 1,012 | 1,113 |
Property, plant and equipment, less accumulated depreciation, depletion and amortization of $23,713 and $21,884 | 27,920 | 29,040 |
Goodwill | 457 | 459 |
Other noncurrent assets | 1,427 | 806 |
Total assets | 34,674 | 36,011 |
Current liabilities: | ||
Accounts payable | 1,246 | 2,545 |
Payroll and benefits payable | 138 | 191 |
Accrued taxes | 143 | 285 |
Other current liabilities | 286 | 290 |
Long-term debt due within one year | 1,035 | 1,068 |
Total current liabilities | 2,848 | 4,379 |
Long-term debt | 7,323 | 5,323 |
Deferred tax liabilities | 2,542 | 2,486 |
Defined benefit postretirement plan obligations | 436 | 598 |
Asset retirement obligations | 1,965 | 1,917 |
Deferred credit and other liabilities | 225 | 288 |
Total liabilities | $ 15,339 | $ 14,991 |
Commitments and contingencies | ||
Stockholders' Equity | ||
Preferred stock - no shares issued or outstanding (no par value, 26 million shares authorized) | $ 0 | $ 0 |
Common stock issued - 770 million shares (par value $1 per share, 1.1 billion shares authorized) | 770 | 770 |
Common stock, securities exchangeable into common stock - no shares issued or outstanding (no par value, 29 million shares authorized) | 0 | 0 |
Common stock, held in treasury, at cost - 93 million and 95 million shares | (3,553) | (3,642) |
Additional paid-in capital | 6,493 | 6,531 |
Retained earnings | 15,800 | 17,638 |
Accumulated other comprehensive loss | (175) | (277) |
Total stockholders' equity | 19,335 | 21,020 |
Total liabilities and stockholders' equity | $ 34,674 | $ 36,011 |
Consolidated Balance Sheets Par
Consolidated Balance Sheets Parentheticals - USD ($) shares in Millions, $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Consolidated Balance Sheets Parenthetical [Abstract] | ||
Allowance for Doubtful Accounts Receivable, Current | $ 4 | $ 3 |
Less accumulated depreciation, depletion and amortization | $ (23,713) | $ (21,884) |
Preferred stock, no par value | $ 0 | $ 0 |
Preferred stock shares authorized | 26 | 26 |
Preferred stock shares issued | 0 | 0 |
Preferred stock shares outstanding | 0 | 0 |
Common stock, par value per share | $ 1 | $ 1 |
Common stock shares authorized | 1,100 | 1,100 |
Common stock, shares issued | 770 | 770 |
Common stock, securities exchangeable, no par value | $ 0 | $ 0 |
Common stock, securities exchangeable, shares authorized | 29 | 29 |
Common stock, securities exchangeable, shares issued | 0 | 0 |
Common stock, securities exchangeable, shares outstanding | 0 | 0 |
Common stock, held in treasury, shares | 93 | 95 |
Consolidated Statements of Cash
Consolidated Statements of Cash Flows - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2015 | Sep. 30, 2014 | |
Operating activities: | ||
Net income (loss) | $ (1,411) | $ 2,120 |
Adjustments to reconcile net income (loss) to net cash provided by operating activities: | ||
Discontinued operations | 0 | (1,058) |
Deferred income taxes | (590) | 337 |
Depreciation, depletion and amortization | 2,289 | 2,060 |
Impairments | 381 | 130 |
Pension and other postretirement benefits, net | 9 | (27) |
Exploratory dry well costs and unproved property impairments | 708 | 220 |
Net loss on disposal of assets | 108 | 88 |
Equity method investments, net | 41 | 51 |
Changes in: | ||
Current receivables, changes in | 738 | (270) |
Inventories, changes in | 30 | (32) |
Current accounts payable and accrued liabilities, changes in | (954) | (115) |
All other operating, net | (136) | (28) |
Net cash provided by continuing operations | 1,213 | 3,476 |
Net cash provided by discontinued operations | 0 | 856 |
Net cash provided by operating activities | 1,213 | 4,332 |
Investing activities: | ||
Acquisitions, net of cash acquired | 0 | (12) |
Additions to property, plant and equipment | (2,948) | (3,639) |
Disposal of assets | 105 | 2,237 |
Investments - return of capital | 61 | 46 |
Purchases of short-term investments | (925) | 0 |
Proceeds from Sale, Maturity and Collection of Investments | 225 | 0 |
Investing activities of discontinued operations | 0 | (356) |
All other investing, net | 22 | (24) |
Net cash used in investing activities | (3,460) | (1,748) |
Financing activities: | ||
Commercial paper, net | 0 | (135) |
Borrowings | 1,996 | 0 |
Debt issuance costs | (19) | 0 |
Debt repayments | (34) | (34) |
Purchases of common stock | 0 | (1,000) |
Dividends paid | (427) | (401) |
All other financing, net | 14 | 150 |
Net cash provided by (used in) financing activities | 1,530 | (1,420) |
Effect of Exchange Rate on Cash and Cash Equivalents, Continuing Operations | (1) | (1) |
Effect of Exchange Rate on Cash and Cash Equivalents, Discontinued Operations | 0 | (11) |
Cash held for sale | 0 | (655) |
Net increase (decrease) in cash and cash equivalents | (718) | 497 |
Cash and cash equivalents at beginning of period | 2,398 | 264 |
Cash and cash equivalents at end of period | $ 1,680 | $ 761 |
Basis of Presentation
Basis of Presentation | 9 Months Ended |
Sep. 30, 2015 | |
Accounting Policies [Abstract] | |
Basis of Presentation [Text Block] | Basis of Presentation These consolidated financial statements are unaudited; however, in the opinion of management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal recurring nature unless disclosed otherwise. These consolidated financial statements, including notes, have been prepared in accordance with the applicable rules of the SEC and do not include all of the information and disclosures required by U.S. GAAP for complete financial statements. As a result of the sale of our Angola assets and our Norway business in 2014, both are reflected as discontinued operations. The disclosures in this report related to results of operations and cash flows are presented on the basis of continuing operations, unless otherwise noted. These interim financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our 2014 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2015 are not necessarily indicative of the results to be expected for the full year. |
Accounting Standards
Accounting Standards | 9 Months Ended |
Sep. 30, 2015 | |
Accounting Standards Disclosure [Abstract] | |
Accounting Standards [Text Block] | Accounting Standards Not Yet Adopted In May 2015, the FASB issued an update that removes the requirement to categorize within the fair value hierarchy all investments for which fair value is measured using the net asset value per share practical expedient. The amendment also removes certain disclosure requirements regarding all investments that are eligible to be measured using the net asset value per share practical expedient and only requires certain disclosures on those investments for which an entity elects to use the net asset value per share expedient. This standard is effective for us in the first quarter of 2016 and will be applied on a retrospective basis. Early adoption is permitted. This standard only modifies disclosure requirements; as such, there will be no impact on our consolidated results of operations, financial position or cash flows. In April 2015, the FASB issued an update that requires debt issuance costs to be presented in the balance sheet as a direct reduction from the associated debt liability. This standard is effective for us in the first quarter of 2016 and will be applied on a retrospective basis. Early adoption is permitted. We do not expect the adoption of this standard to have a significant impact on our consolidated results of operations, financial position or cash flows. In February 2015, the FASB issued an amendment to the guidance for determining whether an entity is a variable interest entity ("VIE"). The standard does not add or remove any of the five characteristics that determine if an entity is a VIE. However, it does change the manner by which a reporting entity assesses whether the equity holders at risk lack decision making rights if the decision-making over the subject entity’s most significant activities was outsourced. This standard is effective for us in the first quarter of 2016 and early adoption is permitted. We do not expect the adoption of this standard to have a significant impact on our consolidated results of operations, financial position or cash flows. In August 2014, the FASB issued an update that requires management to assess an entity’s ability to continue as a going concern by incorporating and expanding upon certain principles that are currently in United States auditing standards. This standard is effective for us in the first quarter of 2017 and early adoption is permitted. We do not expect the adoption of this standard to have a significant impact on our consolidated results of operations, financial position or cash flows. In May 2014, the FASB issued an update that supersedes the existing revenue recognition requirements. This standard includes a five-step revenue recognition model to depict the transfer of goods or services to customers in an amount that reflects the consideration to which the company expects to be entitled in exchange for those goods or services. Among other things, the standard also eliminates industry-specific revenue guidance, requires enhanced disclosures about revenue, provides guidance for transactions that were not previously addressed comprehensively, and improves guidance for multiple-element arrangements. This standard is effective for us in the first quarter of 2018 and should be applied retrospectively to each prior reporting period presented or with the cumulative effect of initially applying the update recognized at the date of initial application. Early adoption is permitted with an effective date no earlier than first quarter of 2017. We are evaluating the provisions of this accounting standards update and assessing the impact, if any, it may have on our consolidated results of operations, financial position or cash flows. Recently Adopted In April 2014, the FASB issued an amendment to accounting standards that changes the criteria for reporting discontinued operations while enhancing related disclosures. Under the amendment, only disposals representing a strategic shift in operations should be presented as discontinued operations. Expanded disclosures about the assets, liabilities, income and expenses of discontinued operations are required. In addition, disclosure of the pretax income attributable to a disposal of a significant part of an organization that does not qualify for discontinued operations reporting will be made in order to provide users with information about the ongoing trends in an organization’s results from continuing operations. The amendments were effective for us in the first quarter of 2015 and apply to dispositions or classifications as held for sale thereafter. Adoption of this standard did not impact our consolidated results of operations, financial position or cash flows. |
Variable Interest Entity
Variable Interest Entity | 9 Months Ended |
Sep. 30, 2015 | |
Variable Interest Entity, Not Primary Beneficiary, Disclosures [Abstract] | |
Variable Interest Entity [Text Block] | Variable Interest Entity The owners of the Athabasca Oil Sands Project, in which we hold a 20% undivided interest, contracted with a wholly owned subsidiary of a publicly traded Canadian limited partnership (“Corridor Pipeline”) to provide materials transportation capabilities among the Muskeg River and Jackpine mines, the Scotford upgrader and markets in Edmonton, Alberta, Canada. Costs under this contract are accrued and recorded on a monthly basis, with current liabilities of $2 million recorded at September 30, 2015 and $3 million at December 31, 2014. This contract qualifies as a variable interest contractual arrangement, and the Corridor Pipeline qualifies as a VIE. We hold a variable interest but are not the primary beneficiary because our shipments are only 20% of the total; therefore, the Corridor Pipeline is not consolidated by us. Our maximum exposure to loss as a result of our involvement with this VIE is the amount we expect to pay over the contract term, which was $471 million as of September 30, 2015 . The liability on our books related to this contract at any given time will reflect amounts due for the immediately previous month’s activity, which is substantially less than the maximum exposure over the contract term. |
Income per Common Share
Income per Common Share | 9 Months Ended |
Sep. 30, 2015 | |
Earnings Per Share [Abstract] | |
Income per Common Share [Text Block] | Income (Loss) per Common Share Basic income (loss) per share is based on the weighted average number of common shares outstanding. Diluted income per share assumes exercise of stock options, provided the effect is not antidilutive. The per share calculations below exclude 13 million and 2 million stock options for the third quarters of 2015 and 2014 and 13 million and 4 million stock options for the first nine months of 2015 and 2014 that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2015 2014 2015 2014 Income (loss) from continuing operations $ (749 ) $ 304 $ (1,411 ) $ 1,062 Discontinued operations — 127 — 1,058 Net income (loss) $ (749 ) $ 431 $ (1,411 ) $ 2,120 Weighted average common shares outstanding 677 675 677 681 Effect of dilutive securities — 3 — 3 Weighted average common shares, diluted 677 678 677 684 Per basic share: Income (loss) from continuing operations $ (1.11 ) $ 0.45 $ (2.09 ) $ 1.56 Discontinued operations $ — $ 0.19 $ — $ 1.55 Net income (loss) $ (1.11 ) $ 0.64 $ (2.09 ) $ 3.11 Per diluted share: Income (loss) from continuing operations $ (1.11 ) $ 0.45 $ (2.09 ) $ 1.55 Discontinued operations $ — $ 0.19 $ — $ 1.55 Net income (loss) $ (1.11 ) $ 0.64 $ (2.09 ) $ 3.10 |
Acquisitions (Notes)
Acquisitions (Notes) | 9 Months Ended |
Sep. 30, 2015 | |
Acquisitions [Abstract] | |
Business Combination Disclosure [Text Block] | Acquisitions 2014 - North America E&P Segment In the third quarter of 2014, we acquired acreage in the Oklahoma Resource Basins at a cost of $68 million after final settlement adjustments. |
Dispositions
Dispositions | 9 Months Ended |
Sep. 30, 2015 | |
Discontinued Operations and Disposal Groups [Abstract] | |
Dispositions [Text Block] | Dispositions 2015 - North America E&P Segment In August 2015, we closed the sale of our East Texas, North Louisiana and Wilburton, Oklahoma natural gas assets for proceeds of approximately $100 million and recorded a pretax loss of $1 million . During the second quarter of 2015, we recorded a non-cash impairment charge of $44 million related to these assets (See Note 15 ). 2015 - International E&P Segment In September 2015, we entered into an agreement to sell our East Africa exploration acreage in Ethiopia and Kenya. A pretax loss of $ 109 million was recorded in the third quarter of 2015. This transaction is expected to close during the fourth quarter of 2015. 2014 - North America E&P Segment In the second quarter of 2014, we closed the sale of non-core acreage located in the far northwest portion of Williston Basin for proceeds of $90 million and recorded a pretax loss of $91 million . 2014 - International E&P Segment In the second quarter of 2014, we entered into an agreement to sell our Norway business, including the operated Alvheim floating production, storage and offloading vessel, 10 operated licenses and a number of non-operated licenses on the Norwegian Continental Shelf in the North Sea. The transaction closed during the fourth quarter of 2014. Our Norway business was reflected as discontinued operations in the consolidated statements of income and the consolidated statements of cash flows for 2014. Select amounts reported in discontinued operations were as follows: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2014 2014 Revenues applicable to discontinued operations $ 528 $ 1,901 Pretax income from discontinued operations $ 487 $ 1,617 After-tax income from discontinued operations $ 127 $ 449 (a) (a) Includes a tax benefit of $26 million related to a decrease in the valuation allowance on U.S. foreign tax credits from the Norway operations. In the first quarter of 2014, we closed the sales of our non-operated 10% working interests in the Production Sharing Contracts and Joint Operating Agreements for Angola Blocks 31 and 32 for aggregate proceeds of approximately $2 billion and recorded a $576 million after-tax gain on sale. Included in the after-tax gain is a deferred tax benefit reflecting our ability to utilize foreign tax credits that otherwise would have needed a valuation allowance. Our Angola operations are reflected as discontinued operations in the consolidated statements of income and the consolidated statements of cash flows for the prior period. Select amounts reported in discontinued operations were as follows: Nine Months Ended September 30, (In millions) 2014 Revenues applicable to discontinued operations $ 58 Pretax income from discontinued operations, before gain $ 51 Pretax gain on disposition of discontinued operations $ 470 After-tax income from discontinued operations $ 609 |
Segment Information
Segment Information | 9 Months Ended |
Sep. 30, 2015 | |
Segment Reporting [Abstract] | |
Segment Information [Text Block] | Segment Information We are a global energy company with operations in North America, Europe and Africa. Each of our three reportable operating segments is organized and managed based upon both geographic location and the nature of the products and services it offers. • N.A. E&P – explores for, produces and markets crude oil and condensate, NGLs and natural gas in North America; • Int'l E&P – explores for, produces and markets crude oil and condensate, NGLs and natural gas outside of North America and produces and markets products manufactured from natural gas, such as LNG and methanol, in E.G.; and • Oil Sands Mining (“OSM”) – mines, extracts and transports bitumen from oil sands deposits in Alberta, Canada, and upgrades the bitumen to produce and market synthetic crude oil and vacuum gas oil. Information regarding assets by segment is not presented because it is not reviewed by the chief operating decision maker (“CODM”). Segment income represents income from continuing operations excluding certain items not allocated to segments, net of income taxes attributable to the operating segments. Our corporate and operations support general and administrative costs are not allocated to the operating segments. These costs primarily consist of employment costs (including pension effects), professional services, facilities and other costs associated with corporate and operations support activities. Gains or losses on dispositions, certain impairments, change in tax expense associated with a tax rate change, unrealized gains or losses on crude oil derivative instruments, or other items that affect comparability also are not allocated to operating segments. As discussed in Note 6 , as a result of the sale of our Angola assets and our Norway business in 2014, both are reflected as discontinued operations and excluded from the Int'l E&P segment for 2014. Three Months Ended September 30, 2015 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 796 $ 182 $ 242 $ 80 (c) $ 1,300 Marketing revenues 57 25 2 — 84 Total revenues 853 207 244 80 1,384 Income (loss) from equity method investments — 48 — (12 ) (d) 36 Net gain (loss) on disposal of assets and other income 6 6 — (109 ) (e) (97 ) Less: Production expenses 179 61 166 — 406 Marketing costs 56 25 3 — 84 Exploration expenses 22 10 — 553 (f) 585 Depreciation, depletion and amortization 549 79 76 13 717 Impairments — — 4 333 (g) 337 Other expenses (a) 106 25 8 79 (h) 218 Taxes other than income 42 — 5 (1 ) 46 Net interest and other — — — 75 75 Income tax provision (benefit) (34 ) 32 (7 ) (387 ) (396 ) Segment income (loss) /Loss from continuing operations $ (61 ) $ 29 $ (11 ) $ (706 ) $ (749 ) Capital expenditures (b) $ 564 $ 30 $ (11 ) $ 12 $ 595 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on crude oil derivative instruments. (d) Partial impairment of investment in equity method investee (See Note 15 ). (e) Includes loss on sale of East Africa exploration acreage (See Note 6 ). (f) Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (See Note 14 ). (g) Proved property impairments (See Note 14 ). (h) Includes pension settlement loss of $18 million and severance related expenses associated with workforce reductions of $4 million (See Note 8 ). Three Months Ended September 30, 2014 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 1,586 $ 273 $ 457 $ — $ 2,316 Marketing revenues 506 46 2 — 554 Total revenues 2,092 319 459 — 2,870 Income from equity method investments — 89 — — 89 Net gain (loss) on disposal of assets and other income (1 ) 12 — 1 12 Less: Production expenses 233 108 252 — 593 Marketing costs 507 45 2 — 554 Exploration expenses 55 41 — — 96 Depreciation, depletion and amortization 609 55 62 11 737 Impairments — — — 109 (c) 109 Other expenses (a) 118 26 14 101 (d) 259 Taxes other than income 109 — 5 1 115 Net interest and other — — — 55 55 Income tax provision (benefit) 168 39 31 (89 ) 149 Segment income/Income from continuing operations $ 292 $ 106 $ 93 $ (187 ) $ 304 Capital expenditures (b) $ 1,277 $ 166 $ 49 $ 16 $ 1,508 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Proved property impairment (See Note 14 ). (d) Includes pension settlement loss of $ 22 million (See Note 8 ). Nine Months Ended September 30, 2015 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 2,639 $ 575 $ 614 $ 59 (c) $ 3,887 Marketing revenues 345 81 45 — 471 Total revenues 2,984 656 659 59 4,358 Income (loss) from equity method investments — 110 — (12 ) (d) 98 Net gain (loss) on disposal of assets and other income 17 20 1 (108 ) (e) (70 ) Less: Production expenses 560 192 548 — 1,300 Marketing costs 348 79 44 — 471 Exploration expenses 148 85 — 553 (f) 786 Depreciation, depletion and amortization 1,866 214 173 36 2,289 Impairments — — 4 377 (g) 381 Other expenses (a) 322 67 26 330 (h) 745 Taxes other than income 170 — 15 6 191 Net interest and other — — — 180 180 Income tax provision (benefit) (146 ) 56 (43 ) (413 ) (i) (546 ) Segment income (loss) /Loss from continuing operations $ (267 ) $ 93 $ (107 ) $ (1,130 ) $ (1,411 ) Capital expenditures (b) $ 2,048 $ 275 $ 26 $ 26 $ 2,375 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on crude oil derivative instruments. (d) Partial impairment of investment in equity-method investee (See Note 15 ). (e) Includes loss on sale of East Africa exploration acreage (See Note 6 ). (f) Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (See Note 14 ). (g) Proved property impairments (See Note 14 ). (h) Includes pension settlement loss of $99 million and severance related expenses associated with workforce reductions of $47 million (See Note 8 ). (i) Includes $135 million of deferred tax expense related to Alberta provincial corporate tax rate increase (See Note 9 ). Nine Months Ended September 30, 2014 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 4,518 $ 1,000 $ 1,217 $ — $ 6,735 Marketing revenues 1,486 177 50 — 1,713 Total revenues 6,004 1,177 1,267 — 8,448 Income from equity method investments — 346 — — 346 Net gain (loss) on disposal of assets and other income 17 44 3 (97 ) (c) (33 ) Less: Production expenses 661 307 729 — 1,697 Marketing costs 1,484 176 50 — 1,710 Exploration expenses 194 120 — — 314 Depreciation, depletion and amortization 1,674 201 152 33 2,060 Impairments 21 — — 109 (d) 130 Other expenses (a) 354 98 40 297 (e) 789 Taxes other than income 301 — 16 2 319 Net interest and other — — — 180 180 Income tax provision (benefit) 496 178 71 (245 ) 500 Segment income /Income from continuing operations $ 836 $ 487 $ 212 $ (473 ) $ 1,062 Capital expenditures (b) $ 3,246 $ 386 $ 172 $ 29 $ 3,833 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Primarily related to the sale of non-core acreage (See Note 6 ). (d) Proved property impairments (See Note 14 ). (e) Includes pension settlement loss of $ 93 million (See Note 8 ). |
Defined Benefit Postretirement
Defined Benefit Postretirement Plans | 9 Months Ended |
Sep. 30, 2015 | |
Defined Benefit Postretirement Plans Disclosure [Abstract] | |
Defined Benefit Postretirement Plans [Text Block] | Defined Benefit Postretirement Plans The following summarizes the components of net periodic benefit cost: Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2015 2014 2015 2014 Service cost $ 11 $ 12 $ — $ — Interest cost 12 15 3 4 Expected return on plan assets (17 ) (16 ) — — Amortization: – prior service cost (credit) (3 ) 1 (1 ) (1 ) – actuarial loss 5 7 1 — Net settlement loss (a) 18 22 — — Net curtailment loss (b) 4 — — — Net periodic benefit cost $ 30 $ 41 $ 3 $ 3 Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2015 2014 2015 2014 Service cost $ 35 $ 35 $ 2 $ 2 Interest cost 39 46 8 10 Expected return on plan assets (53 ) (48 ) — — Amortization: – prior service cost (credit) (4 ) 4 (3 ) (3 ) – actuarial loss 19 23 1 — Net settlement loss (a) 99 93 — — Net curtailment loss (gain) (b) 5 — (4 ) — Net periodic benefit cost $ 140 $ 153 $ 4 $ 9 (a) Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan's total service and interest cost for that year. (b) Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans and the impact of discontinuing accruals for future benefits under the U.K. pension plan effective December 31, 2015. During the first nine months of 2015 , we recorded the effects of a workforce reduction, a U.S. pension plan amendment and the discontinuation of accruals for future benefits under the U.K. pension plan. The U.S. pension plan amendment freezes the final average pay used to calculate the benefit under the legacy final average pay formula and was effective July 6, 2015. For the U.K. pension plan, a final decision was reached with the plan trustees to close the plan to future benefit accruals effective December 31, 2015. Additionally, during the first nine months of 2015 and 2014, we recorded the effects of settlements of our U.S. pension plans. As required, we remeasured the plans' assets and liabilities as of the applicable balance sheet dates. The cumulative effects of these events are included in the remeasurement and reflected in both the pension liability and net periodic benefit cost. During the first nine months of 2015 , we made contributions of $65 million to our funded pension plans. We expect to make additional contributions up to an estimated $18 million to our funded pension plans over the remainder of 2015 . During the first nine months of 2015 , we made payments of $57 million and $13 million related to unfunded pension plans and other postretirement benefit plans, respectively. |
Income Taxes
Income Taxes | 9 Months Ended |
Sep. 30, 2015 | |
Income Tax Disclosure [Abstract] | |
Income Taxes | Income Taxes Effective Tax Rate The effective income tax rate is influenced by a variety of factors including the geographic and functional sources of income and the relative magnitude of these sources of income. The difference between the total provision (benefit) and the sum of the amounts allocated to segments is reported in the “Not Allocated to Segments” column of the tables in Note 7 . Our effective income tax rates on continuing operations for the first nine months of 2015 and 2014 were 28% and 32% . The tax provision (benefit) applicable to Libyan ordinary income (loss) was recorded as a discrete item in the first nine months of 2015 and 2014 . Excluding Libya, the effective tax rates on continuing operations, would be 27% and 32% for the first nine months of 2015 and 2014. In Libya, uncertainty remains around the timing of future production and sales levels. Reliable estimates of 2015 and 2014 Libyan annual ordinary income from our operations could not be made and the range of possible scenarios in the worldwide annual effective tax rate calculation demonstrates significant variability. Thus, for the first nine months of 2015 and 2014 , estimated annual effective tax rates were calculated excluding Libya and applied to consolidated ordinary income (loss). Change in Tax Law On June 29, 2015, the Alberta government enacted legislation to increase the provincial corporate tax rate from 10% to 12% . As a result of this legislation, we recorded additional non-cash deferred tax expense of $135 million in the second quarter of 2015. Indefinite Reinvestment Assertion In the second quarter of 2015, we reviewed our operations and concluded that we do not have the same level of capital needs outside the U.S. as previously expected. Therefore, we no longer intend for previously unremitted foreign earnings of approximately $1 billion associated with our Canadian operations to be permanently reinvested outside the U.S. As such, none of Marathon Oil’s foreign earnings remain permanently reinvested abroad. We anticipate foreign tax credits associated with these Canadian earnings would be sufficient to offset any incremental U.S. tax liabilities, and therefore, no additional net deferred taxes were recorded in the second quarter of 2015. Deferred Tax Assets In connection with our assessment of the realizability of our deferred tax assets, we consider whether it is more likely than not that some portion or all of our deferred tax assets will not be realized. In the event it is more likely than not that some portion or all of our deferred taxes will not be realized, such assets are reduced by a valuation allowance. Future increases to our valuation allowance are possible if our estimates and assumptions (particularly as they relate to downward revisions of our long-term commodity price forecast) are revised such that they reduce estimates of future taxable income during the carryforward period. |
Short-term Investments (Notes)
Short-term Investments (Notes) | 9 Months Ended |
Sep. 30, 2015 | |
Short-term Investments [Abstract] | |
Investment [Text Block] | Short-term Investments As of September 30, 2015, our short-term investments are comprised of bank time deposits with original maturities of greater than three months and remaining maturities of less than twelve months. They are classified as held-to-maturity investments, which are recorded at amortized cost. The carrying values of our short-term investments approximate fair value. These short-term investments matured during October 2015. |
Inventories
Inventories | 9 Months Ended |
Sep. 30, 2015 | |
Inventory Disclosure [Abstract] | |
Inventories [Text Block] | Inventories Inventories of liquid hydrocarbons, natural gas and bitumen are carried at the lower of cost or market value. Materials and supplies are valued at weighted average cost and reviewed for obsolescence or impairment when market conditions indicate. September 30, December 31, (In millions) 2015 2014 Liquid hydrocarbons, natural gas and bitumen $ 39 $ 58 Supplies and other items 285 299 Inventories, at cost $ 324 $ 357 |
Property, Plant and Equipment
Property, Plant and Equipment | 9 Months Ended |
Sep. 30, 2015 | |
Property, Plant and Equipment [Abstract] | |
Property, Plant and Equipment [Text Block] | Property, Plant and Equipment, net of Accumulated Depreciation, Depletion and Amortization September 30, December 31, (In millions) 2015 2014 North America E&P $ 15,875 $ 16,717 International E&P 2,604 2,741 Oil Sands Mining 9,334 9,455 Corporate 107 127 Net property, plant and equipment $ 27,920 $ 29,040 Our Libya operations continue to be impacted by civil unrest and, in December 2014, Libya’s National Oil Corporation once again declared force majeure at the Es Sider oil terminal, as disruptions from civil unrest continue. Considerable uncertainty remains around the timing of future production and sales levels. As of September 30, 2015 , our net property, plant and equipment investment in Libya is $775 million , and total proved reserves (unaudited) in Libya as of December 31, 2014 are 243 million boe. We and our partners in the Waha concessions continue to assess the situation and the condition of our assets in Libya. Our periodic assessment of the carrying value of our net property, plant and equipment in Libya specifically considers the net investment in the assets, the duration of our concessions and the reserves anticipated to be recoverable in future periods. The undiscounted cash flows related to our Libya assets continue to exceed the carrying value of $775 million by a material amount. Exploratory well costs capitalized greater than one year after completion of drilling were $88 million and $126 million as of September 30, 2015 and December 31, 2014 . This $38 million net decrease was associated with a write-down of our Canadian in-situ assets at Birchwood in the second quarter of 2015. After further evaluation of the estimated recoverable resources and our development plans, we withdrew our regulatory application for the proposed steam assisted gravity drainage demonstration project at Birchwood. |
Other Noncurrent Assets (Notes)
Other Noncurrent Assets (Notes) | 9 Months Ended |
Sep. 30, 2015 | |
Other Noncurrent Assets Disclosure [Abstract] | |
Other Assets Disclosure [Text Block] | Other Noncurrent Assets September 30, December 31, (in millions) 2015 2014 Deferred tax assets $ 1,115 $ 525 Intangible assets 95 96 Other 217 185 Other noncurrent assets $ 1,427 $ 806 |
Impairments and Exploration Exp
Impairments and Exploration Expenses (Notes) | 9 Months Ended |
Sep. 30, 2015 | |
Impairments and Exploration Expenses [Abstract] | |
Impairments and Exploration Expenses [Text Block] | Impairments and Exploration Expenses The continued decline of commodity prices resulted in a downward revision of our long-term commodity price assumptions and was a triggering event which required us to reassess long-lived assets related to oil and gas producing properties for impairment as of September 30, 2015 . Further changes in management's forecast assumptions may cause us to reassess our long-lived assets for impairment, and could result in non-cash impairment charges in the future. The following table summarizes impairment charges of proved properties: Three Months Ended September 30, Nine Months Ended September 30, (in millions) 2015 2014 2015 2014 Total impairments $ 337 $ 109 $ 381 $ 130 Impairments for the three and nine months ended September 30, 2015 consisted primarily of proved properties in Colorado and the Gulf of Mexico as a result of lower forecasted commodity prices. Impairments for the three and nine months ended September 30, 2014 consisted primarily of proved properties in the Gulf of Mexico, Texas and North Dakota as a result of revisions to estimated abandonment costs and lower forecasted commodity prices. See Note 7 for relevant detail regarding segment presentation and Note 15 for fair value measurements related to impairments of proved properties. The following table summarizes the components of exploration expenses: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2015 2014 2015 2014 Exploration Expenses Unproved property impairments $ 563 $ 39 $ 612 $ 140 Dry well costs (3 ) 25 96 80 Geological and geophysical 8 10 23 27 Other 17 22 55 67 Total exploration expenses $ 585 $ 96 $ 786 $ 314 Included in the unproved property impairments for the three and nine months ended September 30, 2015 are non-cash charges of $553 million as a result of changes in our conventional exploration strategy (Gulf of Mexico and Harir block in the Kurdistan Region of Iraq) and lower forecasted commodity prices (Colorado). Unproved property impairments for the three and nine months ended September 30, 2014 primarily consist of leases in Texas and North Dakota that either expired or we decided not to drill or extend. See Note 7 for relevant detail regarding segment presentation. |
Fair Value Measurements
Fair Value Measurements | 9 Months Ended |
Sep. 30, 2015 | |
Fair Value Disclosures [Abstract] | |
Fair Value Measurements [Text Block] | Fair Value Measurements Fair Values - Recurring The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 by fair value hierarchy level. September 30, 2015 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 61 $ — $ 61 Interest rate — 15 — 15 Derivative instruments, assets $ — $ 76 $ — $ 76 Derivative instruments, liabilities Commodity (a) $ — $ 3 $ — $ 3 Derivative instruments, liabilities $ — $ 3 $ — $ 3 (a) Derivative instruments are recorded on a net basis in the company's balance sheet (see Note 16 ). December 31, 2014 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Interest rate $ — $ 8 $ — $ 8 Derivative instruments, assets $ — $ 8 $ — $ 8 Commodity derivatives include three-way collars, swaptions, extendable three-way collars and call options. These instruments are measured at fair value using either the Black-Scholes Model or Black Model. Inputs to both models include prices, interest rates, and implied volatility. The inputs to these models are categorized as Level 2 because predominantly all assumptions and inputs are observable in active markets throughout the term of the instruments. Interest rate swaps are measured at fair value with a market approach using actionable broker quotes, which are Level 2 inputs. See Note 16 for additional discussion of the types of derivative instruments we use. Fair Values - Nonrecurring The following table shows the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition. Three Months Ended September 30, 2015 2014 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 41 $ 337 $ 43 $ 109 Nine Months Ended September 30, 2015 2014 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 58 $ 381 $ 43 $ 130 Commodity prices began declining in the second half of 2014 and remain substantially lower through 2015. The prolonged decline in commodity prices, and the resulting change in management's future commodity price assumptions, was a triggering event which required us to reassess long-lived assets related to oil and gas producing properties for impairment as of September 30, 2015 . Further changes in management's forecast assumptions may cause us to reassess our long-lived assets for impairment, and could result in non-cash impairment charges in the future. Long-lived assets held for use that were impaired are discussed below. The fair values of each were measured using an income approach based upon internal estimates of future production levels, prices and discount rate, all of which are Level 3 inputs, unless otherwise noted. Inputs to the fair value measurement include reserve and production estimates made by our reservoir engineers, estimated future commodity prices adjusted for quality and location differentials, and forecasted operating expenses for the remaining estimated life of the reservoir. 2015 - North America E&P In the third quarter of 2015, impairments of $333 million were recorded primarily related to certain producing assets in Colorado and the Gulf of Mexico as a result of lower forecasted commodity prices, to an aggregate fair value of $41 million . During the second quarter of 2015, we recorded a non-cash impairment charge of $44 million related to our East Texas, North Louisiana and Wilburton, Oklahoma natural gas assets as a result of the anticipated sale (see Note 6 ). The fair values were measured using a probability weighted income approach based on both the anticipated sales price and a held-for-use model. 2015 - International E&P In the third quarter of 2015, a partial impairment of $12 million was recorded to an investment in an equity method investee as a result of lower forecasted commodity prices, to a fair value of $604 million . This impairment was reflected in income from equity method investments in our consolidated statements of income. 2014 - North America E&P The Ozona development in the Gulf of Mexico ceased producing in 2013, at which time those long-lived assets were fully impaired. In the first nine months of 2014, we recorded additional impairments of $30 million as a result of estimated abandonment cost revisions. In the third quarter of 2014, impairments of $53 million were recorded to certain other Gulf of Mexico properties as a result of estimated abandonment cost and other revisions, to an aggregate fair value of $19 million . In addition, two additional on-shore fields were impaired a total of $47 million to an aggregate fair value of $24 million primarily due to lower forecasted commodity prices. Fair Values – Goodwill Unlike long-lived assets, goodwill must be tested for impairment at least annually, or between annual tests if an event occurs or circumstances change that would more likely than not reduce the fair value of a reporting unit below its carrying amount. Goodwill is tested for impairment at the reporting unit level. After we performed our annual goodwill impairment test in April 2015, a triggering event (downward revision of forecasted commodity price assumptions) required us to reassess our goodwill for impairment as of September 30, 2015. Based on the results of this assessment, we concluded no impairment was required. The fair value of the North America E&P and International E&P reporting units exceeded their respective book values by a significant margin. Changes in management's forecast commodity price assumptions may cause us to reassess our goodwill for impairment, and could result in non-cash impairment charges in the future. Fair Values – Financial Instruments Our current assets and liabilities include financial instruments, the most significant of which are receivables, short-term investments, long-term debt due within one year, and payables. We believe the carrying values of our receivables, short-term investments and payables approximate fair value. Our fair value assessment incorporates a variety of considerations, including (1) the short-term duration of the instruments, (2) our investment-grade credit rating, and (3) our historical incurrence of and expected future insignificant bad debt expense, which includes an evaluation of counterparty credit risk. The following table summarizes financial instruments, excluding receivables, short-term investments, payables and derivative financial instruments, and their reported fair value by individual balance sheet line item at September 30, 2015 and December 31, 2014 . September 30, 2015 December 31, 2014 Fair Carrying Fair Carrying (In millions) Value Amount Value Amount Financial assets Other noncurrent assets $ 109 $ 116 $ 132 $ 129 Total financial assets 109 116 132 129 Financial liabilities Other current liabilities 15 14 13 13 Long-term debt, including current portion (a) 8,302 8,324 6,887 6,360 Deferred credits and other liabilities 69 64 69 68 Total financial liabilities $ 8,386 $ 8,402 $ 6,969 $ 6,441 (a) Excludes capital leases. Fair values of our financial assets included in other noncurrent assets, and of our financial liabilities included in other current liabilities and deferred credits and other liabilities, are measured using an income approach and most inputs are internally generated, which results in a Level 3 classification. Estimated future cash flows are discounted using a rate deemed appropriate to obtain the fair value. Most of our long-term debt instruments are publicly-traded. A market approach, based upon quotes from major financial institutions, which are Level 2 inputs, is used to measure the fair value of such debt. The fair value of our debt that is not publicly-traded is measured using an income approach. The future debt service payments are discounted using the rate at which we currently expect to borrow. All inputs to this calculation are Level 3. |
Derivatives
Derivatives | 9 Months Ended |
Sep. 30, 2015 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivatives [Text Block] | Derivatives For further information regarding the fair value measurement of derivative instruments, see Note 15 . All of our interest rate and commodity derivatives are subject to enforceable master netting arrangements or similar agreements under which we may report net amounts. The following tables present the gross fair values of derivative instruments and the reported net amounts where they appear on the consolidated balance sheets as of September 30, 2015 and December 31, 2014 . September 30, 2015 (In millions) Asset Liability Net Asset Balance Sheet Location Fair Value Hedges Interest rate $ 15 $ — $ 15 Other noncurrent assets Total Designated Hedges 15 — 15 Not Designated as Hedges Commodity 55 2 53 Other current assets Commodity 6 1 5 Other noncurrent assets Total Not Designated as Hedges 61 3 58 Total $ 76 $ 3 $ 73 December 31, 2014 (In millions) Asset Liability Net Asset Balance Sheet Location Fair Value Hedges Interest rate $ 8 $ — $ 8 Other noncurrent assets Total $ 8 $ — $ 8 Derivatives Designated as Fair Value Hedges The following table presents, by maturity date, information about our interest rate swap agreements as of September 30, 2015 and December 31, 2014 , including the weighted average, London Interbank Offer Rate (“LIBOR”)-based, floating rate. September 30, 2015 December 31, 2014 Aggregate Notional Amount Weighted Average, LIBOR-Based, Aggregate Notional Amount Weighted Average, LIBOR-Based, Maturity Dates (in millions) Floating Rate (in millions) Floating Rate October 1, 2017 $ 600 4.68 % $ 600 4.64 % March 15, 2018 $ 300 4.54 % $ 300 4.49 % The pretax effects of derivative instruments designated as hedges of fair value in our consolidated statements of income are summarized in the table below. The foreign currency forwards were used to hedge the current Norwegian tax liability of our Norway business that was sold in the fourth quarter of 2014. Those instruments outstanding were transferred to the purchaser of the Norway business upon closing of the sale. There is no ineffectiveness related to the fair value hedges. Gain (Loss) Three Months Ended September 30, Nine Months Ended September 30, (In millions) Income Statement Location 2015 2014 2015 2014 Derivative Interest rate Net interest and other $ 4 $ (6 ) $ 7 $ (3 ) Foreign currency Discontinued operations $ — $ (18 ) $ — $ (29 ) Hedged Item Long-term debt Net interest and other $ (4 ) $ 6 $ (7 ) $ 3 Accrued taxes Discontinued operations $ — $ 18 $ — $ 29 Derivatives not Designated as Hedges During the first nine months of 2015, we entered into multiple crude oil derivatives indexed to New York Mercantile Exchange ("NYMEX") WTI related to a portion of our forecasted North America E&P sales through December 2016. These commodity derivatives consist of three-way collars, extendable three-way collars and call options. Three way-collars consist of a sold call (ceiling), a purchased put (floor) and a sold put. The ceiling price is the maximum we will receive for the contract crude oil volumes, the floor is the minimum price we will receive, unless the market price falls below the sold put strike price. In this case, we receive the NYMEX WTI price plus the difference between the floor and the sold put price. These commodity derivatives were not designated as hedges and are shown in the table below: Financial Instrument Weighted Average Price Barrels per day Remaining Term Three-Way Collars Ceiling $70.34 35,000 October- December 2015 Floor $55.57 Sold put $41.29 Ceiling $60.00 2,000 October 2015- March 2016 (a) Floor $50.00 Sold put $40.00 Ceiling $71.84 12,000 January- December 2016 Floor $60.48 Sold put $50.00 Ceiling $73.13 2,000 January- June 2016 (b) Floor $65.00 Sold put $50.00 Call Options $72.39 10,000 January- December 2016 (c) (a) Counterparties have the option, exercisable on March 31, 2016, to extend these collars through September of 2016 at the same volume and weighted average price as the underlying three-way collars. (b) Counterparty has the option, exercisable on June 30, 2016, to extend these collars through the remainder of 2016 at the same volume and weighted average price as the underlying three-way collars. (c) Call options settle monthly. The impact of these crude oil derivative instruments appears in sales and other operating revenues in our consolidated statements of income and was a net gain of $108 million and $91 million in the third quarter and first nine months 2015 . There were no crude oil derivative instruments in the first nine months of 2014. On June 1, 2015, we entered into Treasury rate locks, which expired on the same day, to hedge against timing differences as it related to our Notes offering (see Note 18 ). Following the execution of the Treasury locks, corresponding interest rates increased during the day of June 1. As a result, the settlement of the Treasury rate locks resulted in a gain of $6 million , which was recognized in net interest and other in our consolidated statements of income. |
Incentive Based Compensation
Incentive Based Compensation | 9 Months Ended |
Sep. 30, 2015 | |
Incentive Based Compensation Plans [Abstract] | |
Incentive Based Compensation [Text Block] | Incentive Based Compensation Stock option and restricted stock awards The following table presents a summary of stock option and restricted stock award activity for the first nine months of 2015 : Stock Options Restricted Stock Number of Shares Weighted Average Exercise Price Awards Weighted Average Grant Date Fair Value Outstanding at December 31, 2014 13,427,836 $29.68 3,448,353 $34.04 Granted 724,082 (a) $29.06 2,674,987 $30.52 Options Exercised/Stock Vested (549,926 ) $16.84 (1,135,635 ) $33.25 Canceled (605,760 ) $34.11 (708,380 ) $33.20 Outstanding at September 30, 2015 12,996,232 $29.99 4,279,325 $32.17 (a) The weighted average grant date fair value of stock option awards granted was $6.84 per share. Stock-based performance unit awards During the first nine months of 2015, we granted 382,335 stock-based performance units to certain officers. The grant date fair value per unit was $31.77 . |
Debt (Notes)
Debt (Notes) | 9 Months Ended |
Sep. 30, 2015 | |
Debt Disclosure [Abstract] | |
Debt | Debt Revolving Credit Facility As of September 30, 2015 , we had no borrowings against our revolving credit facility (as amended, the "Credit Facility"), as described below. In May 2015, we amended our $2.5 billion unsecured Credit Facility to increase the facility size by $500 million to a total of $3 billion and extended the maturity date by an additional year such that the Credit Facility now matures in May 2020. The amendment additionally provides us the ability to request two one-year extensions to the maturity date and an option to increase the commitment amount by up to an additional $500 million , subject to the consent of any increasing lenders. The sub-facilities for swing-line loans and letters of credit remain unchanged allowing up to an aggregate amount of $100 million and $500 million , respectively. Fees on the unused commitment of each lender, as well as the borrowing options under the Credit Facility, remain unchanged. The Credit Facility includes a covenant requiring that our ratio of total debt to total capitalization not exceed 65% as of the last day of each fiscal quarter. If an event of default occurs, the lenders holding more than half of the commitments may terminate the commitments under the Credit Facility and require the immediate repayment of all outstanding borrowings and the cash collateralization of all outstanding letters of credit under the Credit Facility. As of September 30, 2015 , we were in compliance with this covenant with a debt-to-capitalization ratio of 30% . Debt Issuance On June 10, 2015, we issued $2 billion aggregate principal amount of unsecured senior notes which consist of the following series: • $600 million of 2.70% senior notes due June 1, 2020 • $900 million of 3.85% senior notes due June 1, 2025 • $500 million of 5.20% senior notes due June 1, 2045 Interest on each series of senior notes is payable semi-annually beginning December 1, 2015. We may redeem some or all of the senior notes at any time at the applicable redemption price, plus accrued interest, if any. The aggregate net proceeds were used to repay our $1 billion 0.90% senior notes that matured in November 2015, and the remainder for general corporate purposes. As of September 30, 2015 , we were in compliance with the covenants under the indenture governing the senior notes. |
Reclassifications out of Accumu
Reclassifications out of Accumulated Other Comprehensive Income | 9 Months Ended |
Sep. 30, 2015 | |
Reclassifications out of AccumulatedOtherComprehensiveIncome [Abstract] | |
Reclassifications Out of Accumulated Other Comprehensive Loss | Reclassifications Out of Accumulated Other Comprehensive Income (Loss) The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss) to income (loss) from continuing operations in their entirety: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2015 2014 2015 2014 Income Statement Line Postretirement and postemployment plans Amortization of actuarial loss $ (6 ) $ (7 ) $ (20 ) $ (23 ) General and administrative Net settlement loss (18 ) (22 ) (99 ) (93 ) General and administrative Net curtailment gain (loss) (4 ) — (1 ) — General and administrative (28 ) (29 ) (120 ) (116 ) Income (loss) from operations 10 10 44 38 Benefit for income taxes Other insignificant, net of tax — — — (1 ) Total reclassifications $ (18 ) $ (19 ) $ (76 ) $ (79 ) Income (loss) from continuing operations |
Supplemental Cash Flow Informat
Supplemental Cash Flow Information | 9 Months Ended |
Sep. 30, 2015 | |
Supplemental Cash Flow Information [Abstract] | |
Supplemental Cash Flow Information [Text Block] | Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2015 2014 Net cash used in operating activities: Interest paid (net of amounts capitalized) $ (200 ) $ (201 ) Income taxes paid to taxing authorities (a) (174 ) (1,514 ) Net cash provided by (used in) financing activities: Commercial paper, net: Issuances $ — $ 2,285 Repayments — (2,420 ) Commercial paper, net $ — $ (135 ) Noncash investing activities, related to continuing operations: Asset retirement costs capitalized, net of revisions $ 12 $ 240 Asset retirement obligations assumed by buyer 23 52 Receivable for disposal of assets — 44 (a) The first nine months of 2014 included $1,195 million related to discontinued operations. |
Commitments and Contingencies
Commitments and Contingencies | 9 Months Ended |
Sep. 30, 2015 | |
Commitments and Contingencies Disclosure [Abstract] | |
Commitments and Contingencies | Commitments and Contingencies We are a defendant in a number of lawsuits arising in the ordinary course of business, including, but not limited to, royalty claims, contract claims and environmental claims. While the ultimate outcome and impact to us cannot be predicted with certainty, we believe the resolution of these proceedings will not have a material adverse effect on our consolidated financial position, results of operations or cash flows. |
Basis of Presentation Accountin
Basis of Presentation Accounting Policy (Policies) | 9 Months Ended |
Sep. 30, 2015 | |
Accounting Policies [Abstract] | |
Basis of Accounting, Policy [Policy Text Block] | These consolidated financial statements are unaudited; however, in the opinion of management, these statements reflect all adjustments necessary for a fair statement of the results for the periods reported. All such adjustments are of a normal recurring nature unless disclosed otherwise. These consolidated financial statements, including notes, have been prepared in accordance with the applicable rules of the SEC and do not include all of the information and disclosures required by U.S. GAAP for complete financial statements. As a result of the sale of our Angola assets and our Norway business in 2014, both are reflected as discontinued operations. The disclosures in this report related to results of operations and cash flows are presented on the basis of continuing operations, unless otherwise noted. These interim financial statements should be read in conjunction with the consolidated financial statements and notes thereto included in our 2014 Annual Report on Form 10-K. The results of operations for the third quarter and first nine months of 2015 are not necessarily indicative of the results to be expected for the full year. |
Income per Common Share (Tables
Income per Common Share (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Earnings Per Share [Abstract] | |
Schedule of Earnings Per Share, Basic and Diluted [Table Text Block] | The per share calculations below exclude 13 million and 2 million stock options for the third quarters of 2015 and 2014 and 13 million and 4 million stock options for the first nine months of 2015 and 2014 that were antidilutive. Three Months Ended September 30, Nine Months Ended September 30, (In millions, except per share data) 2015 2014 2015 2014 Income (loss) from continuing operations $ (749 ) $ 304 $ (1,411 ) $ 1,062 Discontinued operations — 127 — 1,058 Net income (loss) $ (749 ) $ 431 $ (1,411 ) $ 2,120 Weighted average common shares outstanding 677 675 677 681 Effect of dilutive securities — 3 — 3 Weighted average common shares, diluted 677 678 677 684 Per basic share: Income (loss) from continuing operations $ (1.11 ) $ 0.45 $ (2.09 ) $ 1.56 Discontinued operations $ — $ 0.19 $ — $ 1.55 Net income (loss) $ (1.11 ) $ 0.64 $ (2.09 ) $ 3.11 Per diluted share: Income (loss) from continuing operations $ (1.11 ) $ 0.45 $ (2.09 ) $ 1.55 Discontinued operations $ — $ 0.19 $ — $ 1.55 Net income (loss) $ (1.11 ) $ 0.64 $ (2.09 ) $ 3.10 |
Dispositions (Tables)
Dispositions (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Discontinued Operations and Disposal Groups [Abstract] | |
Schedule of Disposal Groups, Including Discontinued Operations, Income Statement, Balance Sheet and Additional Disclosures [Table Text Block] | Select amounts reported in discontinued operations were as follows: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2014 2014 Revenues applicable to discontinued operations $ 528 $ 1,901 Pretax income from discontinued operations $ 487 $ 1,617 After-tax income from discontinued operations $ 127 $ 449 (a) (a) Includes a tax benefit of $26 million related to a decrease in the valuation allowance on U.S. foreign tax credits from the Norway operations. In the first quarter of 2014, we closed the sales of our non-operated 10% working interests in the Production Sharing Contracts and Joint Operating Agreements for Angola Blocks 31 and 32 for aggregate proceeds of approximately $2 billion and recorded a $576 million after-tax gain on sale. Included in the after-tax gain is a deferred tax benefit reflecting our ability to utilize foreign tax credits that otherwise would have needed a valuation allowance. Our Angola operations are reflected as discontinued operations in the consolidated statements of income and the consolidated statements of cash flows for the prior period. Select amounts reported in discontinued operations were as follows: Nine Months Ended September 30, (In millions) 2014 Revenues applicable to discontinued operations $ 58 Pretax income from discontinued operations, before gain $ 51 Pretax gain on disposition of discontinued operations $ 470 After-tax income from discontinued operations $ 609 |
Segment Information (Tables)
Segment Information (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Segment Reporting [Abstract] | |
Schedule of Segment Reporting Information, by Segment [Table Text Block] | Three Months Ended September 30, 2015 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 796 $ 182 $ 242 $ 80 (c) $ 1,300 Marketing revenues 57 25 2 — 84 Total revenues 853 207 244 80 1,384 Income (loss) from equity method investments — 48 — (12 ) (d) 36 Net gain (loss) on disposal of assets and other income 6 6 — (109 ) (e) (97 ) Less: Production expenses 179 61 166 — 406 Marketing costs 56 25 3 — 84 Exploration expenses 22 10 — 553 (f) 585 Depreciation, depletion and amortization 549 79 76 13 717 Impairments — — 4 333 (g) 337 Other expenses (a) 106 25 8 79 (h) 218 Taxes other than income 42 — 5 (1 ) 46 Net interest and other — — — 75 75 Income tax provision (benefit) (34 ) 32 (7 ) (387 ) (396 ) Segment income (loss) /Loss from continuing operations $ (61 ) $ 29 $ (11 ) $ (706 ) $ (749 ) Capital expenditures (b) $ 564 $ 30 $ (11 ) $ 12 $ 595 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on crude oil derivative instruments. (d) Partial impairment of investment in equity method investee (See Note 15 ). (e) Includes loss on sale of East Africa exploration acreage (See Note 6 ). (f) Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (See Note 14 ). (g) Proved property impairments (See Note 14 ). (h) Includes pension settlement loss of $18 million and severance related expenses associated with workforce reductions of $4 million (See Note 8 ). Three Months Ended September 30, 2014 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 1,586 $ 273 $ 457 $ — $ 2,316 Marketing revenues 506 46 2 — 554 Total revenues 2,092 319 459 — 2,870 Income from equity method investments — 89 — — 89 Net gain (loss) on disposal of assets and other income (1 ) 12 — 1 12 Less: Production expenses 233 108 252 — 593 Marketing costs 507 45 2 — 554 Exploration expenses 55 41 — — 96 Depreciation, depletion and amortization 609 55 62 11 737 Impairments — — — 109 (c) 109 Other expenses (a) 118 26 14 101 (d) 259 Taxes other than income 109 — 5 1 115 Net interest and other — — — 55 55 Income tax provision (benefit) 168 39 31 (89 ) 149 Segment income/Income from continuing operations $ 292 $ 106 $ 93 $ (187 ) $ 304 Capital expenditures (b) $ 1,277 $ 166 $ 49 $ 16 $ 1,508 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Proved property impairment (See Note 14 ). (d) Includes pension settlement loss of $ 22 million (See Note 8 ). Nine Months Ended September 30, 2015 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 2,639 $ 575 $ 614 $ 59 (c) $ 3,887 Marketing revenues 345 81 45 — 471 Total revenues 2,984 656 659 59 4,358 Income (loss) from equity method investments — 110 — (12 ) (d) 98 Net gain (loss) on disposal of assets and other income 17 20 1 (108 ) (e) (70 ) Less: Production expenses 560 192 548 — 1,300 Marketing costs 348 79 44 — 471 Exploration expenses 148 85 — 553 (f) 786 Depreciation, depletion and amortization 1,866 214 173 36 2,289 Impairments — — 4 377 (g) 381 Other expenses (a) 322 67 26 330 (h) 745 Taxes other than income 170 — 15 6 191 Net interest and other — — — 180 180 Income tax provision (benefit) (146 ) 56 (43 ) (413 ) (i) (546 ) Segment income (loss) /Loss from continuing operations $ (267 ) $ 93 $ (107 ) $ (1,130 ) $ (1,411 ) Capital expenditures (b) $ 2,048 $ 275 $ 26 $ 26 $ 2,375 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Unrealized gain on crude oil derivative instruments. (d) Partial impairment of investment in equity-method investee (See Note 15 ). (e) Includes loss on sale of East Africa exploration acreage (See Note 6 ). (f) Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (See Note 14 ). (g) Proved property impairments (See Note 14 ). (h) Includes pension settlement loss of $99 million and severance related expenses associated with workforce reductions of $47 million (See Note 8 ). (i) Includes $135 million of deferred tax expense related to Alberta provincial corporate tax rate increase (See Note 9 ). Nine Months Ended September 30, 2014 Not Allocated (In millions) N.A. E&P Int'l E&P OSM to Segments Total Sales and other operating revenues $ 4,518 $ 1,000 $ 1,217 $ — $ 6,735 Marketing revenues 1,486 177 50 — 1,713 Total revenues 6,004 1,177 1,267 — 8,448 Income from equity method investments — 346 — — 346 Net gain (loss) on disposal of assets and other income 17 44 3 (97 ) (c) (33 ) Less: Production expenses 661 307 729 — 1,697 Marketing costs 1,484 176 50 — 1,710 Exploration expenses 194 120 — — 314 Depreciation, depletion and amortization 1,674 201 152 33 2,060 Impairments 21 — — 109 (d) 130 Other expenses (a) 354 98 40 297 (e) 789 Taxes other than income 301 — 16 2 319 Net interest and other — — — 180 180 Income tax provision (benefit) 496 178 71 (245 ) 500 Segment income /Income from continuing operations $ 836 $ 487 $ 212 $ (473 ) $ 1,062 Capital expenditures (b) $ 3,246 $ 386 $ 172 $ 29 $ 3,833 (a) Includes other operating expenses and general and administrative expenses. (b) Includes accruals. (c) Primarily related to the sale of non-core acreage (See Note 6 ). (d) Proved property impairments (See Note 14 ). (e) Includes pension settlement loss of $ 93 million (See Note 8 ). |
Defined Benefit Postretiremen32
Defined Benefit Postretirement Plans (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Defined Benefit Postretirement Plans Disclosure [Abstract] | |
Schedule of Defined Benefit Plans Disclosures [Table Text Block] | The following summarizes the components of net periodic benefit cost: Three Months Ended September 30, Pension Benefits Other Benefits (In millions) 2015 2014 2015 2014 Service cost $ 11 $ 12 $ — $ — Interest cost 12 15 3 4 Expected return on plan assets (17 ) (16 ) — — Amortization: – prior service cost (credit) (3 ) 1 (1 ) (1 ) – actuarial loss 5 7 1 — Net settlement loss (a) 18 22 — — Net curtailment loss (b) 4 — — — Net periodic benefit cost $ 30 $ 41 $ 3 $ 3 Nine Months Ended September 30, Pension Benefits Other Benefits (In millions) 2015 2014 2015 2014 Service cost $ 35 $ 35 $ 2 $ 2 Interest cost 39 46 8 10 Expected return on plan assets (53 ) (48 ) — — Amortization: – prior service cost (credit) (4 ) 4 (3 ) (3 ) – actuarial loss 19 23 1 — Net settlement loss (a) 99 93 — — Net curtailment loss (gain) (b) 5 — (4 ) — Net periodic benefit cost $ 140 $ 153 $ 4 $ 9 (a) Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan's total service and interest cost for that year. (b) Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans and the impact of discontinuing accruals for future benefits under the U.K. pension plan effective December 31, 2015. |
Inventories (Tables)
Inventories (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Inventory Disclosure [Abstract] | |
Schedule of Inventory, Current [Table Text Block] | Inventories of liquid hydrocarbons, natural gas and bitumen are carried at the lower of cost or market value. Materials and supplies are valued at weighted average cost and reviewed for obsolescence or impairment when market conditions indicate. September 30, December 31, (In millions) 2015 2014 Liquid hydrocarbons, natural gas and bitumen $ 39 $ 58 Supplies and other items 285 299 Inventories, at cost $ 324 $ 357 |
Property, Plant and Equipment (
Property, Plant and Equipment (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Property, Plant and Equipment [Abstract] | |
Schedule Of Property Plant And Equipment [Table Text Block] | September 30, December 31, (In millions) 2015 2014 North America E&P $ 15,875 $ 16,717 International E&P 2,604 2,741 Oil Sands Mining 9,334 9,455 Corporate 107 127 Net property, plant and equipment $ 27,920 $ 29,040 |
Other Noncurrent Assets (Tables
Other Noncurrent Assets (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Other Noncurrent Assets Disclosure [Abstract] | |
Schedule of Other Assets, Noncurrent [Table Text Block] | September 30, December 31, (in millions) 2015 2014 Deferred tax assets $ 1,115 $ 525 Intangible assets 95 96 Other 217 185 Other noncurrent assets $ 1,427 $ 806 |
Impairments and Exploration E36
Impairments and Exploration Expenses (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Impairments and Exploration Expenses [Abstract] | |
Details of Impairment of Long-Lived Assets Held and Used by Asset [Table Text Block] | The following table summarizes impairment charges of proved properties: Three Months Ended September 30, Nine Months Ended September 30, (in millions) 2015 2014 2015 2014 Total impairments $ 337 $ 109 $ 381 $ 130 |
Exploration Expenses [Table Text Block] | The following table summarizes the components of exploration expenses: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2015 2014 2015 2014 Exploration Expenses Unproved property impairments $ 563 $ 39 $ 612 $ 140 Dry well costs (3 ) 25 96 80 Geological and geophysical 8 10 23 27 Other 17 22 55 67 Total exploration expenses $ 585 $ 96 $ 786 $ 314 |
Fair Value Measurements (Tables
Fair Value Measurements (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Fair Value Disclosures [Abstract] | |
Schedule of Fair Value, Assets and Liabilities Measured on Recurring Basis [Table Text Block] | The following tables present assets and liabilities accounted for at fair value on a recurring basis as of September 30, 2015 and December 31, 2014 by fair value hierarchy level. September 30, 2015 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Commodity (a) $ — $ 61 $ — $ 61 Interest rate — 15 — 15 Derivative instruments, assets $ — $ 76 $ — $ 76 Derivative instruments, liabilities Commodity (a) $ — $ 3 $ — $ 3 Derivative instruments, liabilities $ — $ 3 $ — $ 3 (a) Derivative instruments are recorded on a net basis in the company's balance sheet (see Note 16 ). December 31, 2014 (In millions) Level 1 Level 2 Level 3 Total Derivative instruments, assets Interest rate $ — $ 8 $ — $ 8 Derivative instruments, assets $ — $ 8 $ — $ 8 |
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis [Table Text Block] | The following table shows the values of assets, by major category, measured at fair value on a nonrecurring basis in periods subsequent to their initial recognition. Three Months Ended September 30, 2015 2014 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 41 $ 337 $ 43 $ 109 Nine Months Ended September 30, 2015 2014 (In millions) Fair Value Impairment Fair Value Impairment Long-lived assets held for use $ 58 $ 381 $ 43 $ 130 |
Fair Value, by Balance Sheet Grouping [Table Text Block] | The following table summarizes financial instruments, excluding receivables, short-term investments, payables and derivative financial instruments, and their reported fair value by individual balance sheet line item at September 30, 2015 and December 31, 2014 . September 30, 2015 December 31, 2014 Fair Carrying Fair Carrying (In millions) Value Amount Value Amount Financial assets Other noncurrent assets $ 109 $ 116 $ 132 $ 129 Total financial assets 109 116 132 129 Financial liabilities Other current liabilities 15 14 13 13 Long-term debt, including current portion (a) 8,302 8,324 6,887 6,360 Deferred credits and other liabilities 69 64 69 68 Total financial liabilities $ 8,386 $ 8,402 $ 6,969 $ 6,441 (a) Excludes capital leases. |
Derivatives (Tables)
Derivatives (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Derivative Instruments and Hedging Activities Disclosure [Abstract] | |
Derivatives as they appear on the balance sheet [Table Text Block] | The following tables present the gross fair values of derivative instruments and the reported net amounts where they appear on the consolidated balance sheets as of September 30, 2015 and December 31, 2014 . September 30, 2015 (In millions) Asset Liability Net Asset Balance Sheet Location Fair Value Hedges Interest rate $ 15 $ — $ 15 Other noncurrent assets Total Designated Hedges 15 — 15 Not Designated as Hedges Commodity 55 2 53 Other current assets Commodity 6 1 5 Other noncurrent assets Total Not Designated as Hedges 61 3 58 Total $ 76 $ 3 $ 73 December 31, 2014 (In millions) Asset Liability Net Asset Balance Sheet Location Fair Value Hedges Interest rate $ 8 $ — $ 8 Other noncurrent assets Total $ 8 $ — $ 8 |
Schedule of Interest Rate Derivatives [Table Text Block] | The following table presents, by maturity date, information about our interest rate swap agreements as of September 30, 2015 and December 31, 2014 , including the weighted average, London Interbank Offer Rate (“LIBOR”)-based, floating rate. September 30, 2015 December 31, 2014 Aggregate Notional Amount Weighted Average, LIBOR-Based, Aggregate Notional Amount Weighted Average, LIBOR-Based, Maturity Dates (in millions) Floating Rate (in millions) Floating Rate October 1, 2017 $ 600 4.68 % $ 600 4.64 % March 15, 2018 $ 300 4.54 % $ 300 4.49 % |
Effects of derivatives designated as fair value hedges [Table Text Block] | Gain (Loss) Three Months Ended September 30, Nine Months Ended September 30, (In millions) Income Statement Location 2015 2014 2015 2014 Derivative Interest rate Net interest and other $ 4 $ (6 ) $ 7 $ (3 ) Foreign currency Discontinued operations $ — $ (18 ) $ — $ (29 ) Hedged Item Long-term debt Net interest and other $ (4 ) $ 6 $ (7 ) $ 3 Accrued taxes Discontinued operations $ — $ 18 $ — $ 29 |
Schedule of Notional Amounts of Outstanding Derivative Positions [Table Text Block] | These commodity derivatives were not designated as hedges and are shown in the table below: Financial Instrument Weighted Average Price Barrels per day Remaining Term Three-Way Collars Ceiling $70.34 35,000 October- December 2015 Floor $55.57 Sold put $41.29 Ceiling $60.00 2,000 October 2015- March 2016 (a) Floor $50.00 Sold put $40.00 Ceiling $71.84 12,000 January- December 2016 Floor $60.48 Sold put $50.00 Ceiling $73.13 2,000 January- June 2016 (b) Floor $65.00 Sold put $50.00 Call Options $72.39 10,000 January- December 2016 (c) (a) Counterparties have the option, exercisable on March 31, 2016, to extend these collars through September of 2016 at the same volume and weighted average price as the underlying three-way collars. (b) Counterparty has the option, exercisable on June 30, 2016, to extend these collars through the remainder of 2016 at the same volume and weighted average price as the underlying three-way collars. (c) Call options settle monthly. |
Incentive Based Compensation (T
Incentive Based Compensation (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Incentive Based Compensation Plans [Abstract] | |
Table of Incentive based compensation activity [Table Text Block] | The following table presents a summary of stock option and restricted stock award activity for the first nine months of 2015 : Stock Options Restricted Stock Number of Shares Weighted Average Exercise Price Awards Weighted Average Grant Date Fair Value Outstanding at December 31, 2014 13,427,836 $29.68 3,448,353 $34.04 Granted 724,082 (a) $29.06 2,674,987 $30.52 Options Exercised/Stock Vested (549,926 ) $16.84 (1,135,635 ) $33.25 Canceled (605,760 ) $34.11 (708,380 ) $33.20 Outstanding at September 30, 2015 12,996,232 $29.99 4,279,325 $32.17 (a) The weighted average grant date fair value of stock option awards granted was $6.84 per share. |
Reclassifications out of Accu40
Reclassifications out of Accumulated Other Comprehensive Income Reclassifications out of Accumulated Other Comprehensive Income (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Reclassifications out of AccumulatedOtherComprehensiveIncome [Abstract] | |
Schedule of Amounts Reclassified out of Accumulated Other Comprehensive Income [Table Text Block] | The following table presents a summary of amounts reclassified from accumulated other comprehensive income (loss) to income (loss) from continuing operations in their entirety: Three Months Ended September 30, Nine Months Ended September 30, (In millions) 2015 2014 2015 2014 Income Statement Line Postretirement and postemployment plans Amortization of actuarial loss $ (6 ) $ (7 ) $ (20 ) $ (23 ) General and administrative Net settlement loss (18 ) (22 ) (99 ) (93 ) General and administrative Net curtailment gain (loss) (4 ) — (1 ) — General and administrative (28 ) (29 ) (120 ) (116 ) Income (loss) from operations 10 10 44 38 Benefit for income taxes Other insignificant, net of tax — — — (1 ) Total reclassifications $ (18 ) $ (19 ) $ (76 ) $ (79 ) Income (loss) from continuing operations |
Supplemental Cash Flow Inform41
Supplemental Cash Flow Information (Tables) | 9 Months Ended |
Sep. 30, 2015 | |
Supplemental Cash Flow Information [Abstract] | |
Supplemental Cash Flow Information [Table Text Block] | Supplemental Cash Flow Information Nine Months Ended September 30, (In millions) 2015 2014 Net cash used in operating activities: Interest paid (net of amounts capitalized) $ (200 ) $ (201 ) Income taxes paid to taxing authorities (a) (174 ) (1,514 ) Net cash provided by (used in) financing activities: Commercial paper, net: Issuances $ — $ 2,285 Repayments — (2,420 ) Commercial paper, net $ — $ (135 ) Noncash investing activities, related to continuing operations: Asset retirement costs capitalized, net of revisions $ 12 $ 240 Asset retirement obligations assumed by buyer 23 52 Receivable for disposal of assets — 44 (a) The first nine months of 2014 included $1,195 million related to discontinued operations. |
Variable Interest Entity (Detai
Variable Interest Entity (Details) - Variable Interest Entity, Not Primary Beneficiary [Member] - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2015 | Dec. 31, 2014 | |
Variable Interest Entity [Line Items] | ||
Variable Interest Entity, Qualitative or Quantitative Information, Ownership Percentage | 20.00% | |
Recorded liability related to unconsolidated VIE | $ 2 | $ 3 |
Maximum exposure to loss related to unconsolidated VIE | $ 471 |
Income per Common Share (Detail
Income per Common Share (Details) - USD ($) $ / shares in Units, shares in Millions, $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Earnings Per Share [Abstract] | ||||
Income (Loss) from Continuing Operations Attributable to Parent | $ (749) | $ 304 | $ (1,411) | $ 1,062 |
Income (Loss) from Discontinued Operations, Net of Tax, Attributable to Parent | 0 | 127 | 0 | 1,058 |
Net income (loss) | $ (749) | $ 431 | $ (1,411) | $ 2,120 |
Weighted average common shares outstanding, basic | 677 | 675 | 677 | 681 |
Effect of dilutive securities | 0 | 3 | 0 | 3 |
Weighted average common shares outstanding, diluted | 677 | 678 | 677 | 684 |
Antidilutive Securities Excluded from Computation of Earnings Per Share, Amount | 13 | 2 | 13 | 4 |
Basic: | ||||
Income (loss) from continuing operations per basic share | $ (1.11) | $ 0.45 | $ (2.09) | $ 1.56 |
Discontinued operations per basic share | 0 | 0.19 | 0 | 1.55 |
Net income (loss), per basic share | (1.11) | 0.64 | (2.09) | 3.11 |
Diluted: | ||||
Income (loss) from continuing operations per diluted share | (1.11) | 0.45 | (2.09) | 1.55 |
Discontinued operations per diluted share | 0 | 0.19 | 0 | 1.55 |
Net income (loss), per diluted share | $ (1.11) | $ 0.64 | $ (2.09) | $ 3.10 |
Acquisitions (Details)
Acquisitions (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |
Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Business Acquisition [Line Items] | |||
Payments to Acquire Businesses, Net of Cash Acquired | $ 0 | $ 12 | |
Oklahoma Resource Basins [Member] | |||
Business Acquisition [Line Items] | |||
Payments to Acquire Businesses, Net of Cash Acquired | $ 68 |
Dispositions Dispositions (Deta
Dispositions Dispositions (Details) - USD ($) $ in Millions | 1 Months Ended | 3 Months Ended | 9 Months Ended | |||
Aug. 31, 2015 | Sep. 30, 2015 | Sep. 30, 2014 | Jun. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||||
Proceeds from Sale of Oil and Gas Property and Equipment | $ 105 | $ 2,237 | ||||
East Texas/North Louisiana and Wilburton Assets [Member] | ||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||||
Proceeds from Sale of Oil and Gas Property and Equipment | $ 100 | |||||
Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Pretax | $ (1) | (1) | ||||
Kenya and Ethiopia Assets [Member] | ||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||||
Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Pretax | (109) | (109) | ||||
Williston Basin [Member] | ||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||||
Proceeds from Sale of Oil and Gas Property and Equipment | $ 90 | |||||
Significant Acquisitions and Disposals, Gain (Loss) on Sale or Disposal, Pretax | $ (91) | |||||
Fair Value, Measurements, Nonrecurring [Member] | ||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||||
Assets, Fair Value Adjustment | 337 | $ 109 | $ 381 | $ 130 | ||
East Texas/North Louisiana and Wilburton Assets [Member] | Fair Value, Inputs, Level 3 [Member] | Fair Value, Measurements, Nonrecurring [Member] | ||||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | ||||||
Assets, Fair Value Adjustment | $ 44 |
Dispositions Dispositions - Dis
Dispositions Dispositions - Discontinued Ops (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |||
Sep. 30, 2014 | Mar. 31, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | ||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||
Proceeds from Sale of Oil and Gas Property and Equipment | $ 105 | $ 2,237 | |||
NORWAY | |||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||
Disposal Group, Including Discontinued Operation, Revenue | $ 528 | 1,901 | |||
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, before Income Tax | 487 | 1,617 | |||
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, Net of Tax | $ 127 | 449 | [1] | ||
ANGOLA | |||||
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items] | |||||
Interest Percentage | 10.00% | ||||
Proceeds from Sale of Oil and Gas Property and Equipment | $ 2,000 | ||||
Discontinued Operation, Gain (Loss) on Disposal of Discontinued Operation, Net of Tax | $ 576 | ||||
Disposal Group, Including Discontinued Operation, Revenue | 58 | ||||
Discontinued Operation, Income (Loss) from Discontinued Operation During Phase-out Period, before Income Tax | 51 | ||||
Discontinued Operation, Gain (Loss) from Disposal of Discontinued Operation, before Income Tax | 470 | ||||
Discontinued Operations, Income (Loss) from Discontinued Operations During Phase-out Period Plus Gain (Loss) from Disposal, Net of Tax | $ 609 | ||||
[1] | Includes a tax benefit of $26 million related to a decrease in the valuation allowance on U.S. foreign tax credits from the Norway operations. |
Segment Information (Details)
Segment Information (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||||||||
Sep. 30, 2015 | Jun. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | ||||||
Segment Reporting Information [Line Items] | ||||||||||
Sales and other operating revenues | $ 1,300 | $ 2,316 | $ 3,887 | $ 6,735 | ||||||
Marketing revenues | 84 | 554 | 471 | 1,713 | ||||||
Total revenues | 1,384 | 2,870 | 4,358 | 8,448 | ||||||
Income from equity method investments | 36 | 89 | 98 | 346 | ||||||
Net gain ( loss) on disposal of assets and other income | (97) | 12 | (70) | (33) | ||||||
Production expenses | 406 | 593 | 1,300 | 1,697 | ||||||
Marketing costs | 84 | 554 | 471 | 1,710 | ||||||
Exploration Expenses | 585 | 96 | 786 | 314 | ||||||
Depreciation, depletion and amortization | 717 | 737 | 2,289 | 2,060 | ||||||
Impairment of Oil and Gas Properties | 337 | 109 | 381 | 130 | ||||||
Other expenses | [1] | 218 | 259 | 745 | 789 | |||||
Taxes other than income | 46 | 115 | 191 | 319 | ||||||
Net interest and other | 75 | 55 | 180 | 180 | ||||||
Income tax provision (benefit) | (396) | 149 | (546) | 500 | ||||||
Segment income (loss) /Loss from continuing operations | (749) | 304 | (1,411) | 1,062 | ||||||
Capital expenditures | [2] | 595 | 1,508 | 2,375 | 3,833 | |||||
Workforce reduction | 4 | 47 | ||||||||
Deferred Income Tax Expense (Benefit) | (590) | 337 | ||||||||
North America Exploration and Production [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Sales and other operating revenues | 796 | 1,586 | 2,639 | 4,518 | ||||||
Marketing revenues | 57 | 506 | 345 | 1,486 | ||||||
Total revenues | 853 | 2,092 | 2,984 | 6,004 | ||||||
Income from equity method investments | 0 | 0 | 0 | 0 | ||||||
Net gain ( loss) on disposal of assets and other income | 6 | (1) | 17 | 17 | ||||||
Production expenses | 179 | 233 | 560 | 661 | ||||||
Marketing costs | 56 | 507 | 348 | 1,484 | ||||||
Exploration Expenses | 22 | 55 | 148 | 194 | ||||||
Depreciation, depletion and amortization | 549 | 609 | 1,866 | 1,674 | ||||||
Impairment of Oil and Gas Properties | 0 | 0 | 0 | 21 | ||||||
Other expenses | [1] | 106 | 118 | 322 | 354 | |||||
Taxes other than income | 42 | 109 | 170 | 301 | ||||||
Net interest and other | 0 | 0 | 0 | 0 | ||||||
Income tax provision (benefit) | (34) | 168 | (146) | 496 | ||||||
Segment income (loss) /Loss from continuing operations | (61) | 292 | (267) | 836 | ||||||
Capital expenditures | [2] | 564 | 1,277 | 2,048 | 3,246 | |||||
International Exploration and Production [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Sales and other operating revenues | 182 | 273 | 575 | 1,000 | ||||||
Marketing revenues | 25 | 46 | 81 | 177 | ||||||
Total revenues | 207 | 319 | 656 | 1,177 | ||||||
Income from equity method investments | 48 | 89 | 110 | 346 | ||||||
Net gain ( loss) on disposal of assets and other income | 6 | 12 | 20 | 44 | ||||||
Production expenses | 61 | 108 | 192 | 307 | ||||||
Marketing costs | 25 | 45 | 79 | 176 | ||||||
Exploration Expenses | 10 | 41 | 85 | 120 | ||||||
Depreciation, depletion and amortization | 79 | 55 | 214 | 201 | ||||||
Impairment of Oil and Gas Properties | 0 | 0 | 0 | 0 | ||||||
Other expenses | [1] | 25 | 26 | 67 | 98 | |||||
Taxes other than income | 0 | 0 | 0 | 0 | ||||||
Net interest and other | 0 | 0 | 0 | 0 | ||||||
Income tax provision (benefit) | 32 | 39 | 56 | 178 | ||||||
Segment income (loss) /Loss from continuing operations | 29 | 106 | 93 | 487 | ||||||
Capital expenditures | [2] | 30 | 166 | 275 | 386 | |||||
Oil Sands Mining Segment [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Sales and other operating revenues | 242 | 457 | 614 | 1,217 | ||||||
Marketing revenues | 2 | 2 | 45 | 50 | ||||||
Total revenues | 244 | 459 | 659 | 1,267 | ||||||
Income from equity method investments | 0 | 0 | 0 | 0 | ||||||
Net gain ( loss) on disposal of assets and other income | 0 | 0 | 1 | 3 | ||||||
Production expenses | 166 | 252 | 548 | 729 | ||||||
Marketing costs | 3 | 2 | 44 | 50 | ||||||
Exploration Expenses | 0 | 0 | 0 | 0 | ||||||
Depreciation, depletion and amortization | 76 | 62 | 173 | 152 | ||||||
Impairment of Oil and Gas Properties | 4 | 0 | 4 | 0 | ||||||
Other expenses | [1] | 8 | 14 | 26 | 40 | |||||
Taxes other than income | 5 | 5 | 15 | 16 | ||||||
Net interest and other | 0 | 0 | 0 | 0 | ||||||
Income tax provision (benefit) | (7) | 31 | (43) | 71 | ||||||
Segment income (loss) /Loss from continuing operations | (11) | 93 | (107) | 212 | ||||||
Capital expenditures | [2] | (11) | 49 | 26 | 172 | |||||
Corporate and Other [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Sales and other operating revenues | 80 | [3] | 0 | 59 | [3] | 0 | ||||
Marketing revenues | 0 | 0 | 0 | 0 | ||||||
Total revenues | 80 | 0 | 59 | 0 | ||||||
Income from equity method investments | (12) | [4] | 0 | (12) | [4] | 0 | ||||
Net gain ( loss) on disposal of assets and other income | (109) | [5] | 1 | (108) | [5] | (97) | [6] | |||
Production expenses | 0 | 0 | 0 | 0 | ||||||
Marketing costs | 0 | 0 | 0 | 0 | ||||||
Exploration Expenses | 553 | [7] | 0 | 553 | [7] | 0 | ||||
Depreciation, depletion and amortization | 13 | 11 | 36 | 33 | ||||||
Impairment of Oil and Gas Properties | [8] | 333 | 109 | 377 | 109 | |||||
Other expenses | [1] | 79 | [9] | 101 | [10] | 330 | [11] | 297 | [12] | |
Taxes other than income | (1) | 1 | 6 | 2 | ||||||
Net interest and other | 75 | 55 | 180 | 180 | ||||||
Income tax provision (benefit) | (387) | (89) | (413) | [13] | (245) | |||||
Segment income (loss) /Loss from continuing operations | (706) | (187) | (1,130) | (473) | ||||||
Capital expenditures | [2] | 12 | 16 | 26 | 29 | |||||
United States and Foreign Pension Plans Defined Benefit [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Net settlement loss | [14] | $ 18 | $ 22 | 99 | $ 93 | |||||
Foreign Tax Authority [Member] | Alberta Government [Member] | ||||||||||
Segment Reporting Information [Line Items] | ||||||||||
Deferred Income Tax Expense (Benefit) | $ 135 | $ 135 | ||||||||
[1] | Includes other operating expenses and general and administrative expenses. | |||||||||
[2] | Includes accruals. | |||||||||
[3] | Unrealized gain on crude oil derivative instruments. | |||||||||
[4] | Partial impairment of investment in equity method investee (See Note 15). | |||||||||
[5] | Includes loss on sale of East Africa exploration acreage (See Note 6). | |||||||||
[6] | Primarily related to the sale of non-core acreage (See Note 6). | |||||||||
[7] | Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (See Note 14). | |||||||||
[8] | Proved property impairments (See Note 14). | |||||||||
[9] | Includes pension settlement loss of $18 million and severance related expenses associated with workforce reductions of $4 million (See Note 8). | |||||||||
[10] | Includes pension settlement loss of $22 million (See Note 8) | |||||||||
[11] | Includes pension settlement loss of $99 million and severance related expenses associated with workforce reductions of $47 million (See Note 8). | |||||||||
[12] | Includes pension settlement loss of $93 million (See Note 8) | |||||||||
[13] | Includes $135 million of deferred tax expense related to Alberta provincial corporate tax rate increase (See Note 9). | |||||||||
[14] | Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan's total service and interest cost for that year. |
Defined Benefit Postretiremen48
Defined Benefit Postretirement Plans (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||||
Dec. 31, 2015 | Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | ||
Pension and Other Postretirement Benefit Contributions [Abstract] | ||||||
Pension Contributions | $ 65 | |||||
Defined Benefit Plan, Benefits Paid | 57 | |||||
Other Postretirement Benefits Payments | 13 | |||||
Scenario, Forecast [Member] | ||||||
Pension and Other Postretirement Benefit Contributions [Abstract] | ||||||
Defined Benefit Plan, Estimated Future Employer Contributions in Current Fiscal Year | $ 18 | |||||
United States and Foreign Pension Plans Defined Benefit [Member] | ||||||
Defined Benefit Plan Net Periodic Benefit Cost [Line Items] | ||||||
Service cost | $ 11 | $ 12 | 35 | $ 35 | ||
Interest cost | 12 | 15 | 39 | 46 | ||
Expected return on plan assets | (17) | (16) | (53) | (48) | ||
Amortization: | ||||||
- prior service cost (credit) | (3) | 1 | (4) | 4 | ||
-actuarial loss (gain) | 5 | 7 | 19 | 23 | ||
Net settlement loss | [1] | 18 | 22 | 99 | 93 | |
Defined Benefit Plan, Curtailments | [2] | 4 | 0 | 5 | 0 | |
Net periodic benefit cost | 30 | 41 | 140 | 153 | ||
Other Postretirement Benefit Plans Defined Benefit [Member] | ||||||
Defined Benefit Plan Net Periodic Benefit Cost [Line Items] | ||||||
Service cost | 0 | 0 | 2 | 2 | ||
Interest cost | 3 | 4 | 8 | 10 | ||
Expected return on plan assets | 0 | 0 | 0 | 0 | ||
Amortization: | ||||||
- prior service cost (credit) | (1) | (1) | (3) | (3) | ||
-actuarial loss (gain) | 1 | 0 | 1 | 0 | ||
Net settlement loss | [1] | 0 | 0 | 0 | 0 | |
Defined Benefit Plan, Curtailments | [2] | 0 | 0 | (4) | 0 | |
Net periodic benefit cost | $ 3 | $ 3 | $ 4 | $ 9 | ||
[1] | Settlements are recognized as they occur, once it is probable that lump sum payments from a plan for a given year will exceed the plan's total service and interest cost for that year. | |||||
[2] | Related to workforce reductions, which reduced the future expected years of service for employees participating in the plans and the impact of discontinuing accruals for future benefits under the U.K. pension plan effective December 31, 2015. |
Income Taxes (Details)
Income Taxes (Details) - USD ($) $ in Millions | Jun. 29, 2015 | Jun. 28, 2015 | Jun. 30, 2015 | Sep. 30, 2015 | Sep. 30, 2014 |
Effective Tax Rate Reconciliation [Abstract] | |||||
Effective income tax rate | 28.00% | 32.00% | |||
Effective income tax rate excluding Libya | 27.00% | 32.00% | |||
Deferred Income Tax Expense (Benefit) | $ (590) | $ 337 | |||
Foreign Tax Authority [Member] | Alberta Government [Member] | |||||
Effective Tax Rate Reconciliation [Abstract] | |||||
Provincial corporate tax rate | 12.00% | 10.00% | |||
Deferred Income Tax Expense (Benefit) | $ 135 | $ 135 | |||
CANADA | |||||
Effective Tax Rate Reconciliation [Abstract] | |||||
Earnings of foreign subsidiaries no longer permanently reinvested | $ 1,000 |
Inventories (Details)
Inventories (Details) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Inventory Disclosure [Abstract] | ||
Liquid hydrocarbons natural gas and bitumen | $ 39 | $ 58 |
Supplies and other items | 285 | 299 |
Total inventories, at cost | $ 324 | $ 357 |
Property, Plant and Equipment51
Property, Plant and Equipment (Details) Boe in Millions, $ in Millions | Sep. 30, 2015USD ($) | Dec. 31, 2014USD ($)Boe |
Segment Reporting Information [Line Items] | ||
Property, plant and equipment, net | $ 27,920 | $ 29,040 |
LIBYAN ARAB JAMAHIRIYA | ||
Segment Reporting Information [Line Items] | ||
Property, plant and equipment, net | 775 | |
Proved Developed and Undeveloped Reserves, Net (BOE) | Boe | 243 | |
North America Exploration and Production [Member] | ||
Segment Reporting Information [Line Items] | ||
Property, plant and equipment, net | 15,875 | $ 16,717 |
International Exploration and Production [Member] | ||
Segment Reporting Information [Line Items] | ||
Property, plant and equipment, net | 2,604 | 2,741 |
Oil Sands Mining Segment [Member] | ||
Segment Reporting Information [Line Items] | ||
Property, plant and equipment, net | 9,334 | 9,455 |
Corporate [Member] | ||
Segment Reporting Information [Line Items] | ||
Property, plant and equipment, net | $ 107 | $ 127 |
Property, Plant and Equipment P
Property, Plant and Equipment Property, Plant and Equipment (Details 2) - USD ($) $ in Millions | 9 Months Ended | |
Sep. 30, 2015 | Dec. 31, 2014 | |
Capitalized Exploratory Well Costs [Abstract] | ||
Capitalized Exploratory Well Costs that Have Been Capitalized for Period Greater than One Year After Completion of Drilling | $ 88 | $ 126 |
Capitalized Exploratory Well Cost, Period Increase (Decrease) | $ (38) |
Other Noncurrent Assets (Detail
Other Noncurrent Assets (Details) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Other Noncurrent Assets Disclosure [Abstract] | ||
Deferred tax assets | $ 1,115 | $ 525 |
Intangible assets | 95 | 96 |
Other - Other Noncurrent Assets | 217 | 185 |
Other noncurrent assets | $ 1,427 | $ 806 |
Impairments and Exploration E54
Impairments and Exploration Expenses Impairments (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Impairments [Abstract] | ||||
Impairment of Oil and Gas Properties | $ 337 | $ 109 | $ 381 | $ 130 |
Impairments and Exploration E55
Impairments and Exploration Expenses Exploration Expenses (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |||
Exploration Expenses [Line Items] | ||||||
Exploration Expenses | $ 585 | $ 96 | $ 786 | $ 314 | ||
Corporate and Other [Member] | ||||||
Exploration Expenses [Line Items] | ||||||
Exploration Expenses | 553 | [1] | 0 | 553 | [1] | 0 |
Unproved Property Impairments [Member] | ||||||
Exploration Expenses [Line Items] | ||||||
Exploration Expenses | 563 | 39 | 612 | 140 | ||
Dry Well Costs [Member] | ||||||
Exploration Expenses [Line Items] | ||||||
Exploration Expenses | (3) | 25 | 96 | 80 | ||
Geological and Geophysical [Member] | ||||||
Exploration Expenses [Line Items] | ||||||
Exploration Expenses | 8 | 10 | 23 | 27 | ||
Other Exploration Expenses [Member] | ||||||
Exploration Expenses [Line Items] | ||||||
Exploration Expenses | $ 17 | $ 22 | $ 55 | $ 67 | ||
[1] | Unproved property impairments associated with lower forecasted commodity prices and change in conventional exploration strategy (See Note 14). |
Fair Value Measurements (Detail
Fair Value Measurements (Details-Recurring) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | |
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | $ 76 | $ 8 | |
Derivative Liability | 3 | ||
Commodity Contract [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | [1] | 61 | |
Derivative Liability | [1] | 3 | |
Interest rate [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | 15 | 8 | |
Fair Value, Inputs, Level 1 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | 0 | 0 | |
Derivative Liability | 0 | ||
Fair Value, Inputs, Level 1 [Member] | Commodity Contract [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | [1] | 0 | |
Derivative Liability | [1] | 0 | |
Fair Value, Inputs, Level 1 [Member] | Interest rate [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | 0 | 0 | |
Fair Value Inputs Level 2 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | 76 | 8 | |
Derivative Liability | 3 | ||
Fair Value Inputs Level 2 [Member] | Commodity Contract [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | [1] | 61 | |
Derivative Liability | [1] | 3 | |
Fair Value Inputs Level 2 [Member] | Interest rate [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | 15 | 8 | |
Fair Value, Inputs, Level 3 [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | 0 | 0 | |
Derivative Liability | 0 | ||
Fair Value, Inputs, Level 3 [Member] | Commodity Contract [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | [1] | 0 | |
Derivative Liability | [1] | 0 | |
Fair Value, Inputs, Level 3 [Member] | Interest rate [Member] | |||
Fair Value, Assets and Liabilities Measured on Recurring Basis, Financial Statement [Line Items] | |||
Derivative Assets | $ 0 | $ 0 | |
[1] | Derivative instruments are recorded on a net basis in the company's balance sheet (see Note 16). |
Fair Value Measurements (Deta57
Fair Value Measurements (Details 2-Nonrecurring) - Fair Value, Measurements, Nonrecurring [Member] - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Property, Plant, and Equipment, Fair Value Disclosure, Quarter to Date | $ 41 | $ 43 | $ 41 | $ 43 |
Assets, Fair Value Adjustment | 337 | 109 | 381 | 130 |
Property, Plant, and Equipment, Fair Value Disclosure | 58 | 43 | 58 | 43 |
Colorado Assets [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Property, Plant, and Equipment, Fair Value Disclosure | 41 | 41 | ||
EG Equity Method Investment [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Property, Plant, and Equipment, Fair Value Disclosure | 604 | $ 604 | ||
Gulf of Mexico Assets [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Property, Plant, and Equipment, Fair Value Disclosure | 19 | 19 | ||
Other Domestic Fields [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Property, Plant, and Equipment, Fair Value Disclosure | 24 | 24 | ||
Fair Value, Inputs, Level 3 [Member] | Colorado and Gulf of Mexico [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Assets, Fair Value Adjustment | 333 | |||
Fair Value, Inputs, Level 3 [Member] | East Texas/North Louisiana and Wilburton Assets [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Assets, Fair Value Adjustment | 44 | |||
Fair Value, Inputs, Level 3 [Member] | EG Equity Method Investment [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Assets, Fair Value Adjustment | $ 12 | |||
Fair Value, Inputs, Level 3 [Member] | Assets Held and Used Ozona [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Assets, Fair Value Adjustment | $ 30 | |||
Fair Value, Inputs, Level 3 [Member] | Gulf of Mexico Assets [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Assets, Fair Value Adjustment | 53 | |||
Fair Value, Inputs, Level 3 [Member] | Other Domestic Fields [Member] | ||||
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Financial Statement [Line Items] | ||||
Assets, Fair Value Adjustment | $ 47 |
Fair Value Measurements (Deta58
Fair Value Measurements (Details 3-Reported) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 | |
Fair Value [Member] | |||
Financial Instruments, Financial Assets, Balance Sheet Groupings [Abstract] | |||
Other noncurrent financial assets | $ 109 | $ 132 | |
Total financial assets | 109 | 132 | |
Financial liabilities | |||
Other current financial liabilities | 15 | 13 | |
Long-term debt, including current portion | [1] | 8,302 | 6,887 |
Deferred credits and other financial liabilities | 69 | 69 | |
Financial Liabilities Fair Value Disclosure | 8,386 | 6,969 | |
Carrying Amount [Member] | |||
Financial Instruments, Financial Assets, Balance Sheet Groupings [Abstract] | |||
Other noncurrent financial assets | 116 | 129 | |
Total financial assets | 116 | 129 | |
Financial liabilities | |||
Other current financial liabilities | 14 | 13 | |
Long-term debt, including current portion | [1] | 8,324 | 6,360 |
Deferred credits and other financial liabilities | 64 | 68 | |
Financial Liabilities Fair Value Disclosure | $ 8,402 | $ 6,441 | |
[1] | Excludes capital leases. |
Derivatives (Details-BS)
Derivatives (Details-BS) - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Derivatives Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Gross Asset | $ 76 | |
Derivative Asset, Fair Value, Gross Liability | 3 | |
Derivative Asset, Fair Value, Net | 73 | |
Not Designated as Hedging Instrument [Member] | ||
Derivatives Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Gross Asset | 61 | |
Derivative Asset, Fair Value, Gross Liability | 3 | |
Derivative Asset, Fair Value, Net | 58 | |
Commodity Contract [Member] | Other Noncurrent Assets [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivatives Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Gross Asset | 6 | |
Derivative Asset, Fair Value, Gross Liability | 1 | |
Derivative Asset, Fair Value, Net | 5 | |
Commodity Contract [Member] | Other Current Assets [Member] | Not Designated as Hedging Instrument [Member] | ||
Derivatives Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Gross Asset | 55 | |
Derivative Asset, Fair Value, Gross Liability | 2 | |
Derivative Asset, Fair Value, Net | 53 | |
Fair Value Hedging [Member] | Designated as Hedging Instrument [Member] | ||
Derivatives Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Gross Asset | 15 | $ 8 |
Derivative Asset, Fair Value, Gross Liability | 0 | 0 |
Derivative Asset, Fair Value, Net | 15 | 8 |
Fair Value Hedging [Member] | Interest rate [Member] | Other Noncurrent Assets [Member] | Designated as Hedging Instrument [Member] | ||
Derivatives Fair Value [Line Items] | ||
Derivative Asset, Fair Value, Gross Asset | 15 | 8 |
Derivative Asset, Fair Value, Gross Liability | 0 | 0 |
Derivative Asset, Fair Value, Net | $ 15 | $ 8 |
Derivatives (Details 2-Fair Val
Derivatives (Details 2-Fair Value Hedges) - Fair Value Hedging [Member] - Designated as Hedging Instrument [Member] - Interest Rate Contract [Member] - USD ($) $ in Millions | Sep. 30, 2015 | Dec. 31, 2014 |
Notes Due 2018 [Member] | ||
Derivative [Line Items] | ||
Derivative, Notional Amount | $ 300 | $ 300 |
Weighted-average, LIBOR-based, floating rate | 4.54% | 4.49% |
Debentures Due 2017 [Member] | ||
Derivative [Line Items] | ||
Derivative, Notional Amount | $ 600 | $ 600 |
Weighted-average, LIBOR-based, floating rate | 4.68% | 4.64% |
Derivatives (Details 3-Fair Val
Derivatives (Details 3-Fair Value Hedges IS & OCI) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (Loss) on Fair Value Hedge Ineffectiveness, Net | $ 0 | $ 0 | ||
Net interest and other [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Change in unrealized gain (loss) on hedged item in fair value hedge | $ (4) | $ 6 | (7) | 3 |
Discontinued Operations [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Change in unrealized gain (loss) on hedged item in fair value hedge | 0 | 18 | 0 | 29 |
Interest rate [Member] | Net interest and other [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (loss) on derivative instruments recognized in income | 4 | (6) | 7 | (3) |
Foreign Exchange Contract [Member] | Discontinued Operations [Member] | ||||
Derivative Instruments, Gain (Loss) [Line Items] | ||||
Gain (loss) on derivative instruments recognized in income | $ 0 | $ (18) | $ 0 | $ (29) |
Derivatives Derivatives (Detail
Derivatives Derivatives (Details 4-Non Hedges Commodity) (Details) | Sep. 30, 2015BBL / Days$ / bbl | |
Three-Way Collars Oct-Dec15 [Member] | ||
Derivative [Line Items] | ||
Barrels per day (BBL per day) | BBL / Days | 35,000 | |
Price per barrel ceiling (usd per barrel) | 70.34 | |
Price per barrel floor (usd per barrel) | 55.57 | |
Price per barrel sold put (usd per barrel) | 41.29 | |
Three-Way Collars Oct15-Mar16 [Member] | ||
Derivative [Line Items] | ||
Barrels per day (BBL per day) | BBL / Days | 2,000 | [1] |
Price per barrel ceiling (usd per barrel) | 60 | [1] |
Price per barrel floor (usd per barrel) | 50 | [1] |
Price per barrel sold put (usd per barrel) | 40 | [1] |
Three-Way Collars Jan-Dec16 [Member] [Member] | ||
Derivative [Line Items] | ||
Barrels per day (BBL per day) | BBL / Days | 12,000 | |
Price per barrel ceiling (usd per barrel) | 71.84 | |
Price per barrel floor (usd per barrel) | 60.48 | |
Price per barrel sold put (usd per barrel) | 50 | |
Three-Way Collars Jan-Jun16 [Member] [Member] [Member] | ||
Derivative [Line Items] | ||
Barrels per day (BBL per day) | BBL / Days | 2,000 | [2] |
Price per barrel ceiling (usd per barrel) | 73.13 | [2] |
Price per barrel floor (usd per barrel) | 65 | [2] |
Price per barrel sold put (usd per barrel) | 50 | [2] |
Call Options Jan-Dec16 [Member] | ||
Derivative [Line Items] | ||
Barrels per day (BBL per day) | BBL / Days | 10,000 | [3] |
Derivative, Price Risk Option Strike Price | 72.39 | [3] |
[1] | Counterparties have the option, exercisable on March 31, 2016, to extend these collars through September of 2016 at the same volume and weighted average price as the underlying three-way collars. | |
[2] | Counterparty has the option, exercisable on June 30, 2016, to extend these collars through the remainder of 2016 at the same volume and weighted average price as the underlying three-way collars. | |
[3] | Call options settle monthly. |
Derivatives Derivatives (Deta63
Derivatives Derivatives (Details 5-Non Hedges) (Details) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | |
Sep. 30, 2015 | Jun. 30, 2015 | Sep. 30, 2015 | |
Commodity [Member] | Sales and other operating revenues [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss) on Derivative, Net | $ 108 | $ 91 | |
Treasury Lock [Member] | Net interest and other [Member] | |||
Derivative Instruments, Gain (Loss) [Line Items] | |||
Derivative, Gain (Loss) on Derivative, Net | $ 6 |
Incentive Based Compensation (D
Incentive Based Compensation (Details) | 9 Months Ended | |
Sep. 30, 2015$ / sharesshares | ||
Stock Options | ||
Beginning year stock option awards | shares | 13,427,836 | |
Granted stock option awards | shares | 724,082 | [1] |
Exercised stock option awards | shares | (549,926) | |
Canceled stock option awards | shares | (605,760) | |
End of period stock option awards | shares | 12,996,232 | |
Beginning year weighted average exercise price | $ 29.68 | |
Granted weighted average exercise price | 29.06 | |
Exercises weighted average exercise price | 16.84 | |
Canceled weighted average exercise price | 34.11 | |
End of period weighted average exercise price | 29.99 | |
Stock options weighted average grant date fair value | $ 6.84 | |
[1] | The weighted average grant date fair value of stock option awards granted was $6.84 per share. |
Incentive Based Compensation 65
Incentive Based Compensation (Details 2-Restricted) | 9 Months Ended |
Sep. 30, 2015$ / sharesshares | |
Restricted Stock | |
Beginning year unvested restricted stock | 3,448,353 |
Granted restricted stock | 2,674,987 |
Vested restricted stock | (1,135,635) |
Forfeited restricted stock | (708,380) |
End of period unvested restricted stock | 4,279,325 |
Beginning year weighted average grant date fair value unvested restricted stock | $ / shares | $ 34.04 |
Granted restricted stock weighted average grant date fair value restricted stock | $ / shares | 30.52 |
Vested restricted stock weighted average grant date fair value restricted stock | $ / shares | 33.25 |
Forfeited restricted stock weighted average grant date fair value restricted stock | $ / shares | 33.20 |
End of period weighted average grant date fair value unvested restricted stock | $ / shares | $ 32.17 |
Incentive Based Compensation 66
Incentive Based Compensation (Details 3-Performance) - $ / shares | 9 Months Ended | |
Sep. 30, 2015 | Dec. 31, 2014 | |
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 32.17 | $ 34.04 |
Performance Unit [Member] | ||
Share-based Compensation Arrangement by Share-based Payment Award [Line Items] | ||
Award Instruments Other Than Options Performance Unit Granted | 382,335 | |
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value | $ 31.77 |
Debt - Revolving Credit Facilit
Debt - Revolving Credit Facility (Details) | Sep. 30, 2015 | May. 31, 2015USD ($) | Apr. 30, 2015USD ($) |
Line of Credit Facility [Line Items] | |||
Line of Credit Facility, maximum borrowing capacity | $ 3,000,000,000 | $ 2,500,000,000 | |
Line of Credit Facility, increase in borrowing capacity | 500,000,000 | ||
Line of credit, extended borrowing capacity | 500,000,000 | ||
Ratio of indebtedness to net capital | 0.30 | ||
Letter of Credit [Member] | |||
Line of Credit Facility [Line Items] | |||
Line of Credit Facility, maximum borrowing capacity | 500,000,000 | ||
Bridge Loan [Member] | |||
Line of Credit Facility [Line Items] | |||
Line of Credit Facility, maximum borrowing capacity | $ 100,000,000 | ||
Maximum [Member] | |||
Line of Credit Facility [Line Items] | |||
Ratio of indebtedness to net capital | 0.65 |
Debt (Details)
Debt (Details) - USD ($) | Sep. 30, 2015 | Jun. 10, 2015 |
Debt Instrument [Line Items] | ||
Other Long-term Debt, Noncurrent | $ 2,000,000,000 | |
Senior Unsecured Notes Due 2020 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 2.70% | |
Other Long-term Debt, Noncurrent | $ 600,000,000 | |
Senior Unsecured Notes Due 2025 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 3.85% | |
Other Long-term Debt, Noncurrent | $ 900,000,000 | |
Senior Unsecured Notes Due 2045 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 5.20% | |
Other Long-term Debt, Noncurrent | $ 500,000,000 | |
Senior Notes Due 2015 [Member] | ||
Debt Instrument [Line Items] | ||
Debt Instrument, Interest Rate, Stated Percentage | 0.90% | |
Other Long-term Debt, Noncurrent | $ 1,000,000,000 |
Reclassifications out of Accu69
Reclassifications out of Accumulated Other Comprehensive Income Reclassifications out of Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions | 3 Months Ended | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | Sep. 30, 2015 | Sep. 30, 2014 | |
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||
Provision for income taxes | $ 396 | $ (149) | $ 546 | $ (500) |
Other insignificant, net of tax | (93) | (99) | (281) | (303) |
Total reclassifications | (749) | 431 | (1,411) | 2,120 |
Reclassification out of Accumulated Other Comprehensive Income [Member] | ||||
Reclassification Adjustment out of Accumulated Other Comprehensive Income [Line Items] | ||||
Amortization of actuarial loss | (6) | (7) | (20) | (23) |
Net settlement loss | (18) | (22) | (99) | (93) |
Net curtailment gain (loss) | (4) | 0 | (1) | 0 |
Income before income taxes | (28) | (29) | (120) | (116) |
Provision for income taxes | 10 | 10 | 44 | 38 |
Other insignificant, net of tax | 0 | 0 | 0 | (1) |
Total reclassifications | $ (18) | $ (19) | $ (76) | $ (79) |
Supplemental Cash Flow Inform70
Supplemental Cash Flow Information (Details) - USD ($) $ in Millions | 9 Months Ended | ||
Sep. 30, 2015 | Sep. 30, 2014 | ||
Net cash provided by (used in) operating activities included: | |||
Interest paid (net of amounts capitalized) | $ (200) | $ (201) | |
Income taxes paid to taxing authorities | [1] | (174) | (1,514) |
Income Taxes Paid Net, Discontinued Operations | 1,195 | ||
Commercial paper, net: | |||
Commercial paper - issuances | 0 | 2,285 | |
Commercial paper - repayments | 0 | (2,420) | |
Commercial paper, net | 0 | (135) | |
Noncash investing activities: | |||
Asset retirement costs capitalized | 12 | 240 | |
Asset retirement obligations assumed by buyer | 23 | 52 | |
Receivable Related To Disposal Of Assets | $ 0 | $ 44 | |
[1] | The first nine months of 2014 included $1,195 million related to discontinued operations. |