ConocoPhillips (COP) 10-K 20 Feb 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2017	Jan. 31, 2018
Document And Entity Information [Abstract]
Entity Registrant Name	CONOCOPHILLIPS
Entity Central Index Key	1,163,165
Document Type	10-K
Document Period End Date	Dec. 31, 2017
Amendment Flag	false
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Filer Category	Large Accelerated Filer
Entity Public Float	$ 54
Entity Common Stock, Shares Outstanding		1,174,577,506
Trading Symbol	COP

Consolidated Income Statement

Consolidated Income Statement - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues and Other Income
Sales and other operating revenues	$ 29,106	$ 23,693	$ 29,564
Equity in earnings of affiliates	772	52	655
Gain on dispositions	2,177	360	591
Other Income	529	255	125
Total Revenues and Other Income	32,584	24,360	30,935
Cost and expenses
Purchased commodities	12,475	9,994	12,426
Production and operating expenses	5,173	5,667	7,016
Selling, general and administrative expenses	561	723	953
Exploration expenses	938	1,915	4,192
Depreciation, depletion and amortization	6,845	9,062	9,113
Impairments	6,601	139	2,245
Taxes other than income taxes	809	739	901
Accretion on discounted liabilities	362	425	483
Interest and debt expense	1,098	1,245	920
Foreign currency transaction (gains) losses	35	(19)	(75)
Other Expense	302
Total Costs and Expenses	35,199	29,890	38,174
Income (loss) before income taxes	(2,615)	(5,530)	(7,239)
Income Tax Expense (Benefit)	(1,822)	(1,971)	(2,868)
Net income (loss)	(793)	(3,559)	(4,371)
Less: net income attributable to noncontrolling interests	(62)	(56)	(57)
Net income (loss) attributable to ConocoPhillips	$ (855)	$ (3,615)	$ (4,428)
Net Income (Loss) Attributable to ConocoPhillips Per Share of Common Stock (dollars)
Earnings Per Share, Basic	$ (0.7)	$ (2.91)	$ (3.58)
Earnings Per Share, Diluted	(0.7)	(2.91)	(3.58)
Dividends Paid Per Share of Common Stock (dollars)	$ 1.06	$ 1	$ 2.94
Average Common Shares Outstanding (in thousands)
Basic	1,221,038	1,245,440	1,241,919
Diluted	1,221,038	1,245,440	1,241,919

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Consolidated Statement of Comprehensive Income
Net income (loss)		$ (793)	$ (3,559)	$ (4,371)
Defined benefit plans
Prior service (cost) credit arising during the period		2	23	301
Amortization of prior service cost (credit) included in income		(38)	(35)	(19)
Net change during the period		(36)	(12)	282
Net actuarial gain (loss) arising during the period		19	(481)	592
Reclassification adjustment for amortization of prior service credit included in net income (loss)		247	309	403
Net change during the period		266	(172)	995
Nonsponsored plans	[1]	(2)	2	1
Income taxes on defined benefit plans		(81)	78	(460)
Defined benefit plans, net of tax		147	(104)	818
Unrealized holding gain on securities, before and after tax		(58)	0	0
OCI Unrealized loss on securities, net of tax		(58)	0	0
Foreign currency translation adjustments		586	153	(5,199)
Reclassification adjustment for gain included in net income (loss)		0	5	0
Income taxes on foreign currency translation adjustments		0	0	36
Foreign currency translation adjustments, net of tax		586	158	(5,163)
Other comprehensive income (loss), net of tax		675	54	(4,345)
Comprehensive income (loss)		(118)	(3,505)	(8,716)
Less: comprehensive income attributable to noncontrolling interests		(62)	(56)	(57)
Comprehensive Income (Loss) Attributable to ConocoPhillips		$ (180)	$ (3,561)	$ (8,773)
[1]	Plans for which ConocoPhillips is not the primary obligor—primarily those administered by equity affiliates.

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Assets
Cash and cash equivalents	$ 6,325	$ 3,610
Short-term Investments	1,873	50
Accounts and notes receivable (net of allowance of $4 million in 2017 and $5 million in 2016)	4,179	3,249
Accounts and notes receivable-related parties	141	165
Investment in Cenovus Energy	1,899
Inventories	1,060	1,018
Prepaid expenses and other current assets	1,035	517
Total Current Assets	16,512	8,609
Investments and long-term receivables	9,599	21,091
Loans and advances-related parties	461	581
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $64,748 million in 2017 and $73,075 million in 2016)	45,683	58,331
Other assets	1,107	1,160
Total Assets	73,362	89,772
Liabilities
Accounts payable	4,009	3,631
Accounts payable-related parties	21	22
Short-term debt	2,575	1,089
Accrued income and other taxes	1,038	484
Employee benefit obligations	725	689
Other accruals	1,029	994
Total Current Liabilities	9,397	6,909
Long-term debt	17,128	26,186
Total asset retirement obligations and accrued environmental costs	7,631	8,425
Deferred taxes Included in long-term liabilities	5,282	8,949
Employee benefit obligations	1,854	2,552
Other liabilities and deferred credits	1,269	1,525
Total Liabilities	42,561	54,546
Equity
Common stock (2,500,000,000 shares authorized at $.01 par value)	18	18
Capital in excess of par	46,622	46,507
Treasury stock (at cost: 2017-608,312,034 shares; 2016-544,809,771 shares)	(39,906)	(36,906)
Accumulated other comprehensive income (loss)	(5,518)	(6,193)
Retained earnings	29,391	31,548
Total Common Stockholders' Equity	30,607	34,974
Noncontrolling interests	194	252
Total Equity	30,801	35,226
Total Liabilities and Equity	$ 73,362	$ 89,772

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Consolidated Balance Sheet [Abstract]
Allowance for accounts and notes receivable	$ 4	$ 5
Accumulated depreciation, depletion and amortization	$ 64,748	$ 73,075
Common stock, shares authorized	2,500,000,000	2,500,000,000
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares issued	1,785,419,175	1,782,079,107
Treasury stock, shares	608,312,034	544,809,771

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash Flows From Operating Activities
Net income (loss)	$ (793)	$ (3,559)	$ (4,371)
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	6,845	9,062	9,113
Impairments	6,601	139	2,245
Dry hole costs and leasehold impairments	566	1,184	3,065
Accretion on discounted liabilities	362	425	483
Deferred taxes	(3,681)	(2,221)	(2,772)
Undistributed equity earnings	(232)	299	101
Gain on dispositions	(2,177)	(360)	(591)
Other	(429)	(85)	321
Working capital adjustments
Decrease (increase) in accounts and notes receivable	(886)	820	1,810
Decrease (increase) in inventories	(55)	44	166
Decrease (increase) in prepaid expenses and other current assets	69	105	239
Increase (decrease) in accounts payable	265	(524)	(1,647)
Increase (decrease) in taxes and other accruals	622	(926)	(590)
Net Cash Provided by Operating Activities	7,077	4,403	7,572
Cash Flows From Investing Activities
Capital expenditures and investments	(4,591)	(4,869)	(10,050)
Increase (Decrease) In Capital Accrual Associated With Investing Activities	132	(331)	(968)
Proceeds from asset dispositions	13,860	1,286	1,952
Net Sales (Purchases) of Short-Term Investments	(1,790)	(51)	0
Long-term advances/loans-related parties	0	0
Collection of advances/loans-related parties	115	108	105
Other	36	(2)	306
Net Cash Provided by (Used in) Investing Activities	7,762	(3,859)	(8,655)
Cash Flows From Financing Activities
Issuance of debt	0	4,594	2,498
Repayment of debt	(7,876)	(2,251)	(103)
Change in restricted cash	0	0	0
Issuance of company common stock	(63)	(63)	(82)
Repurchase of company common stock	(3,000)	(126)	0
Dividends paid	(1,305)	(1,253)	(3,664)
Other	(112)	(137)	(78)
Net Cash Used in Financing Activities	(12,356)	764	(1,429)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	232	(66)	(182)
Net Change in Cash and Cash Equivalents	2,715	1,242	(2,694)
Cash and cash equivalents at beginning of period	3,610	2,368	5,062
Cash and Cash Equivalents at End of Period	$ 6,325	$ 3,610	$ 2,368

Consolidated Statement of Chang

Consolidated Statement of Changes in Equity - USD ($) $ in Millions	Total	Common Stock [Member]	Capital in excess of par	Treasury Stock [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Retained Earnings [Member]	Noncontrolling Interest [Member]
Beginning Balance at Dec. 31, 2014	$ 52,273	$ 18	$ 46,071	$ (36,780)	$ (1,902)	$ 44,504	$ 362
Net income (loss)	(4,371)					(4,428)	57
Other comprehensive income (loss)	(4,345)				(4,345)
Dividends paid	(3,664)					(3,664)
Distributions to noncontrolling interests and other	(100)						(100)
Distributed under benefit plans	286		286
Other	3					2	1
Ending Balance at Dec. 31, 2015	40,082	18	46,357	(36,780)	(6,247)	36,414	320
Net income (loss)	(3,559)					(3,615)	56
Other comprehensive income (loss)	54				54
Dividends paid	(1,253)					(1,253)
Repurchase of company common stock	(126)			(126)
Distributions to noncontrolling interests and other	(124)						(124)
Distributed under benefit plans	150		150
Other	2					2
Ending Balance at Dec. 31, 2016	35,226	18	46,507	(36,906)	(6,193)	31,548	252
Net income (loss)	(793)					(855)	62
Other comprehensive income (loss)	675				675
Dividends paid	(1,305)					(1,305)
Repurchase of company common stock	(3,000)			(3,000)
Distributions to noncontrolling interests and other	(120)						(120)
Distributed under benefit plans	115		115
Other	3					3
Ending Balance at Dec. 31, 2017	$ 30,801	$ 18	$ 46,622	$ (39,906)	$ (5,518)	$ 29,391	$ 194

Accounting Policies

Accounting Policies	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Accounting Policies	Note 1 —Accounting Policies Consolidation Principles and Investments — Our consolidated financial statements include the accounts of majority-owned, controlled subsidiaries and variable interest entities where we are the primary beneficiary. The equity method is used to account for investments in affiliates in which we have the ability to exert significant influence over the affiliates’ operating and financial policies. When we do not h ave the ability to exert significant influence, the investment is either classified as available-for-sale if fair value is readily determinable, or the cost method is used if fair value is not readily determinable. Undivided interests in oil and gas joint ventures, pipelines, natural gas plants and terminals are consolidated on a proportionate basis. Other securities and investments are generally carried at cost. We manage our operations through six operating segments, defined by geographic region: Alaska, Lower 48, Canada, Europe and North Africa, Asia Pacific and Middle East, and Other International. For additional information, see Note 23 —Segment Disclosures and Related Information. Foreign Currency Translation — Adjustments resulting from the process of translating foreign functional currency financial statements into U.S. dollars are included in accumulated other comprehensive income in common stockholders’ equity. Foreign currency transaction gains and losses are included in current earn ings. Most of our foreign operations use their local currency as the f unctional currency. Use of Estimates — The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosures of contingent assets and liabilities. Actual results could differ from these estimates. Revenue Recognition — Revenues associated with sales of crude oil, bitumen, natural gas, liquefied natural gas (LNG), natural gas liquids and other items are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occ urs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry. Revenues associated with producing properties in which we have an interest with other producers are recognized based on the actual volumes we sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be nonrecoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropri ate. Cumulative differences between volumes sold and entitlement volumes are generally not significant. Revenues associated with transactions commonly called buy/sell contracts, in which the purchase and sale of inventory with the same counterparty are entered into “in contemplation” of one another, are combined and reported net (i.e., on the same income statement line) . Shipping and Handling Costs — We include shipping and handling costs in production and operating expenses for production activities. Tra nsportation costs related to marketing activities are recorded in purchased commodities. Freight costs billed to customers are recorded as a component of revenue. Cash Equivalents — Cash equivalents are highly liquid, short-term investments that are readily convertible to known amounts of cash and have original maturities of 90 days or less from their date of purchase. They are carried at cost plus accrued interest, which approximates fair value. Short-Term Investments —Investments in bank time deposits and marketable securities (commercial paper and government obligations) with original maturities of greater than 90 days but less than one year are classified as short-term investments. Inventories — We have several valuation methods for our various types of in ventories and consistently use the following methods for each type of inventory. Our c ommodity-related inventories are recorded at cost primarily using the last-in, first-out (LIFO) basis. We measure these inventories at the lower-of-cost-or-market in th e aggregate. Any necessary lower-of-cost-or-market write-downs at year end are recorded as permanent adjustments to the LIFO cost basis. LIFO is used to better match current inventory costs with current revenues. Costs include both direct and indirect e xpenditures incurred in bringing an item or product to its existing condition and location, but not unusual/nonrecurring costs or research and development costs. Materials, supplies and other miscellaneous inventories, such as tubular goods and well equip ment, are valued using various methods, including the weighted-average-cost method, and the first-in, first-out (FIFO) method, consistent with industry practice. Fair Value Measurements — A ssets and liabilities measured at fair value and required to be categ orized within the fair value hierarchy are categorized into one of three different levels depending on the observability of the inputs employed in the measurement . Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Le vel 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting significant modifications to observable related market data or our assumptions about pricing by market participants. Derivative Instruments — Derivative instruments are recorded on the balance sheet at fair value. If the right of offset exists and certain o ther criteria are met, derivative assets and liabilities with the same counterparty are netted on the balance sheet and the collateral payable or receivable is netted against derivative assets and derivative liabilities, respectively. Recognition and classification of the gain or loss that results from recording and adjusting a derivative to fair value depends on the purpose for issuing or holding the derivative. Gains and losses from derivatives not accounted for as hedges are recognized immediately in earnings. Oil and Gas Exploration and Development — Oil and gas exploration and development costs are accounted for using the successful efforts method of accounting. Property Acquisition Costs — Oil and gas leasehold acquisition costs are capitalized and included in the balance sheet caption properties, plants and equipment (PP&E). Leasehold impairment is recognized based on exploratory experience and management’s judgment. Upon achievement of all conditions necessary for reserves to be classified as proved, the associated leasehold costs are re classified to proved properties. Exploratory Costs — Geological and geophysical costs and the costs of carrying and retaining undeveloped properties are expensed as incurred. Exploratory well costs are capitalized, or “suspended,” on the balance sheet pending further evaluation of whether economically recoverable reserves have been found. If economically recoverable reserves are not found, exploratory well costs are expensed as dry holes. If explor atory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For c omplex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on the balance sheet for several years while we perform additional appraisal drilling and seismic work on the potential oil and gas field or while we seek governme nt or co-venturer approval of development plans or seek environmental permitting. Once all required approvals and permits have been obtained, the projects are moved into the development phase, and the oil and gas resources are designated as proved reserve s. Management reviews suspended well balances quarterly, continuously monitors the results of the additional appraisal drilling and seismic work, and expenses the suspended well costs as dry holes when it judges the potential field does not warrant further investment in the near term. See Note 7 —Suspended Wells and Other Exploration Expenses , for additional information on suspended wells. Development Costs — Costs incurred to drill and equip development wells, including unsuccessful development wells, are capitalized. Depletion and Amortization — Leasehold costs of producing properties are depleted using the unit-of-production method based on estimated proved oil and gas reserves. Amortization of intangible development costs is based on the unit-of-production method using estimated proved developed oil and gas reserves. Capitalized Interest — Interest from external borrowings is capitalized on major projects with an expected construction period of one year or longer. Capitalized interes t is added to the cost of the underlying asset and is amortized over the useful lives of the assets in the same manner as the underlying assets. Depreciation and Amortization — Depreciation and amortization of PP&E on producing hydrocarbon properties and cer tain pipeline assets (those which are expected to have a declining utilization pattern), are determined by the unit-of-production method. Depreciation and amortization of all other PP&E are determined by either the individual-unit-straight-line method or the group-straight-line method (for those individual units that are highly integrated with other units). Impairment of Properties, Plants and Equipment — P P&E used in operations are assessed for impairment whenever changes in facts and circumstances indicate a possible significant deterioration in the future cash flows expected to be generated by an asset group and annually in the fourth quarter following updates to corporate planning assumptions. If there is an indication the carrying amount of an asset may not be recovered, the asset is monitored by management through an established process where changes to significant assumptions such as prices, volumes and futur e development plans are reviewed. If, upon review, the sum of the undiscounted before -tax cash flows is less than the carrying value of the asset group, the carrying value is written down to estimated fair value through additional amortization or deprecia tion provisions and reported as impairments in the periods in which the determination of the impairment is made. Individual assets are grouped for impairment purposes at the lowest level for which there are identifiable cash flows that are largely indepen dent of the cash flows of other groups of assets—generally on a field-by-field basis for exploration and production assets. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically deter mined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants or based on a multiple of operating cash flow validated with historical market transactions of s imilar assets where possible. Long-lived assets committed by management for disposal within one year are accounted for at the lower of amortized cost or fair value, less cost to sell, with fair value determined using a binding negotiated price, if availab le, or present value of expected future cash flows as previously described. The expected future cash flows used for impairment reviews and related fair value calculations are based on estimated future production volumes, prices and costs, considering all a vailable evidence at the date of review. The impairment review includes cash flows from proved developed and undeveloped reserves, including any development expenditures necessary to achieve that production. Additionally, when probable and possible reser ves exist, an appropriate risk-adjusted amount of these reserves may be included in the impairment calculation. Impairment of Investments in Nonconsolidated Entities — Investments in nonconsolidated entities are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred and annually following updates to corporate planning assumptions. When such a condition is judgmentally determined to be other than temporary, the carrying value of the investment is writte n down to fair value. The fair value of the impaired investment is based on quoted market prices, if available, or upon the present value of expected future cash flows using discount rates believed to be consistent with those used by principal market part icipants, plus market analysis of comparable assets owned by the investee, if appropriate. Maintenance and Repairs — C osts of ma intenance and repairs, which are not significant improvements, are expensed when incurred. Property Dispositions — When complete units of depreciable property are sold, the asset cost and related accumulated depreciation are eliminated, with any gain or loss reflected in the “Gain on dispositions” line of our consolidated income statement. When less than complete units of depreciab le property are disposed of or retired, the difference between asset cost and salvage value is charged or credited to accumulated depreciation. Asset Retirement Obligations and Environmental Costs — The fair value of legal obligations to retire and remove lo ng-lived assets are recorded in the period in which the obligation is incurred (typically when the asset is installed at the production location). When the liability is initially recorded, we capitalize this cost by increasing the carrying amount of the r elated PP&E. If, in subsequent periods, our estimate of this liability changes, we will record an adjustment to both the liability and PP&E. Over time the liability is increased for the change in its present value, and the capitalized cost in PP&E is dep reciated over the useful life of the related asset. For additional information, see Note 9 —Asset Retirement Obligations and Accrued Environmental C osts . Environmental expenditures are expensed or capitalized, depending upon their future economic be nefit. Expenditures relating to an existing condition caused by past operations, and those having no future economic benefit, are expensed. Liabilities for environmental expenditures are recorded on an undiscounted basis (unless acquired in a purchase bu siness combination , which we record on a discounted basis ) when environmental assessments or cleanups are probable and the costs can be reasonably estimated. Recoveries of environmental remediation costs from other parties are recorded as assets when thei r receipt is probable and estimable. Guarantees — The f air value of a guarantee is determined and recorded as a liability at the time the guarantee is given. The initial liability is subsequently reduced as we are released from exposure under the guarantee. We amortize the guarantee liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of guarantee. In cases where the guarantee term is indefinite, we reverse the liability when we have information indicating the liability is essentially relieved or amortize it over an appropriate time period as the fair value of our guarantee exposure declines over time. We amortize the guarantee liability to the related income statement line item based on the nat ure of the guarantee. When it becomes probable that we will have to perform on a guarantee, we accrue a separate liability if it is reasonably estimable, based on the facts and circumstances at that time. We reverse the fair value liability only when the re is no further exposure under the guarantee. Share -Based Compensation — We recognize share -based compensation expense over the shorter of the service period (i.e., the stated period of time required to earn the award) or the period beginning at the start o f the service period and ending when an employee first becomes eligible for retirement. We have elected to recognize expense on a straight-line basis over the service period for the entire award, whether the award was granted with ratable or cliff vesting . Income Taxes — Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial reporting basis and the tax basis of our assets and liabilities, except for deferred taxes on income and tempor ary differences related to the cumulative translation adjustment considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures. Allowable tax credits are applied currently as reductions of the provision for i ncome taxes. Interest related to unrecognized tax benefits is reflected in interest and debt expense, and penalties related to unrecognized tax benefits are reflected in production and operating expenses. Taxes Collected from Customers and Remitted to Gov ernmental Authorities — S ales and value-added taxes are recorded net. Net Income (Loss) Per Share of Common Stock — Basic net income (loss) per share of common stock is calculated based upon the daily weighted-average number of common shares outstanding during the year. Also, this calculation includes fully vested stock and unit awards that have not yet been issued as common stock, along with an adjustment to net income (loss) for dividend equivalents paid on unvested unit awards that are considered participat ing securities. Diluted net income per share of common stock includes unvested stock, unit or option awards granted under our compensation plans and vested but unexercised stock options, but only to the extent these instruments dilute net income per share , primarily under the treasury-stock method. Diluted net loss per share, which is calculated the same as basic net loss per share, does not assume conversion or exercise of securities that would have an antidilutive effect. Treasury stock is excluded fro m the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the participating securities is immaterial.

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	12 Months Ended
	Dec. 31, 2017
Variable Interest Entity, Not Primary Beneficiary, Disclosures [Abstract]
Variable Interest Entity Disclosure [Text Block]	Note 2 —Variable Interest Entities (VIEs) We hold variable interests in VIEs that have not been consolidated because we are not considered the primary beneficiary. Information on our significant VIEs follows: Australia Pacific LNG Pty Ltd (APLNG) APLNG is considered a VIE, as it has entered into certain contractual arrangements that provide it with additional forms of subordinated financial support. We are not the primary beneficiary of APLNG because we share with Origin Energy and China Petrochem ical Corporation (Sinopec) the power to direct the key activities of APLNG that most significantly impact its economic performance, which involve activities related to the production and commercialization of coalbed methane, as well as LNG processing and e xport marketing. As a result, we do not consolidate APLNG, and it is accounted for as an equity method investment. As of December 31, 2017 , we have not provided any financial support to APLNG other than amounts previously contractually required. Un less we elect otherwise, we have no requirement to provide liquidity or purchase the assets of APLNG. See Note 5 —Investments, Loans and Long-Term Receivables, and Note 11 —Guarantees, for additional information. Marine Well Containment Company, LLC (MWCC) MWCC provides well containment equipment and technology and related services in the deepwater U.S. Gulf of Mexico. Its principal activities involve the development and maintenance of rapid-response hydrocarbon well containment systems that are deployable in the Gulf of Mexico on a call-out basis. We have a 10 percent ownership interest in MWCC, and it is accounted for as an equity method investment because MWCC is a limited liability company in which we are a Founding Member and exercise significant influence through our permanent seat on the ten- member Executive Committee responsible for overseeing the affairs of MWCC. In 2016, MWCC executed a $ 154 million term loan financing arrangement with an exter nal financial institution whose terms required the financing be secured by letters of credit provided by certain owners of MWCC, including ConocoPhillips. In connection with the financing transaction, we issued a letter of credit of $ 22 million which can be drawn upon in the event of a default by MWCC on its obligation to repay the proceeds of the term loan. The fair value of this letter of credit is immaterial and not recognized on our consolidated balance sheet. MWCC is consider ed a VIE, as it has entered into arrangements that provide it with additional forms of subordinated financial support. We are not the primary beneficiary and do not consolidate MWCC because we share the power to govern the business and operation of the co mpany and to undertake certain obligations that most significantly impact its economic performance with nine other unaffiliated owners of MWCC. At December 31, 2017 , the book value of our equity method investment in MWCC was $ 139 mi llion. We have not provided any financial support to MWCC other than amounts previously contractually required. Unless we elect otherwise, we have no requirement to provide liquidity or purchase the assets of MWCC.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2017
Inventories [Abstract]
Inventories	Note 3 —Inventories Inventories at December 31 were: Millions of Dollars 2017 2016 Crude oil and natural gas $ 512 418 Materials and supplies 548 600 $ 1,060 1,018 Inventories valued on the LIFO basis totaled $ 341 million and $ 269 million at December 31, 2017 and 2016 , respectively. The estimated excess of current replacement cost over LIFO cost of inventories was approximately $ 124 million and $ 104 million at December 31, 2017 and December 31, 2016 , respectively . In 2017 , liquidation of LIFO inventory values increased the net loss attributable to ConocoPhillips by $ 1 million.

Assets Held for Sale, Sold or A

Assets Held for Sale, Sold or Acquired	12 Months Ended
	Dec. 31, 2017
Disposal Group Not Discontinued Operation Disposal Disclosures [Abstract]
Long Lived Assets Held For Sale [Text Block]	Note 4 —Assets Held for Sale , Sold or Acquired Assets Held for Sale In the second quarter of 2017, we signed a definitive agreement to sell our interest in the Barnett. We terminated this agreement in the fourth quarter of 2017 and are continuing to market the asset in 2018. In connection with the signing of the definitive agreement, we recorded a before-tax impairment of $ 5 72 million to reduce the carrying value of our investment to estimated fair value. As of December 31, 2 017, our Barnett interests had a net carrying value of approximately $ 29 1 million and were considered held for sale resulting in the reclassification of $ 3 39 million of PP&E to “Prepaid expenses and other current assets” and $ 4 8 million of noncurrent liabilities, primarily asset retirement obligations (ARO) , to “Other accruals” on our consolidated balance sheet. The before-tax loss associated with our interests in the Barnett, including the $ 5 72 million impairment noted above, was $ 5 66 million , $ 66 million , and $ 58 million for the years ended December 31, 2017 , 2016 and 2015, respectively. The Barnett results of operations are reported within our Lower 48 segment. In addition to the Barnett, certain other properties in our Lower 48 segment met the criteria for assets held for sale at December 31, 2017. These properties had a net carrying value of approximately $ 212 million after recording a before-tax impairment of $ 78 million to reduce the carrying value to estimated fair value in the fourth quarter of 2017. W e reclassified $ 238 million of PP&E to “Prepaid expenses and other current assets” and $ 26 million of noncurrent liabilities, primarily AROs, to “Other accruals” on our consolidated balance sheet. In January 2018, we completed the sale of a portion of these properties for net proceeds of $ 112 million. Assets Sold All gains or losses are reported before-tax and are included net in the “Gain on dispositions” line on our consolidated income statement. All cash proceeds are included in the “Cash Flows From Inv esting Activities” section of our consolidated statement of cash flows. 2017 On May 17, 2017, we completed the sale of our 50 percent nonoperated interest in the Foster Creek Christina Lake (FCCL) Partnership, as well as the majority of our western Canada gas assets to Cenovus Energy. C onsideration for the transaction was $ 1 1 . 0 billion in cash after customary adjustments , 208 million Cenovus Energy common shares and a five-year uncapped contingent payment. The value of the shares at closing was $ 1.96 billion based on a price of $ 9.41 per share on the New York Stock Exchange. The contingent payment, calculated and paid on a quarterly basis, is $ 6 million Canadian dollars (CAD) for every $ 1 CAD by which the Western Canada Select (WCS) quarterly average crude price exceeds $ 52 CAD per barrel. At closing, the carrying value of our equity investment in FCCL was $ 8.9 billion. The carrying value of our interest in the western Canada gas assets was $ 1 .9 billion consisting primarily of $ 2.6 billion of PP&E, partly offset by AROs of $ 585 million and approximately $ 100 million of environmental and other accruals . A befor e-tax gain of $ 2. 1 billion was included in the “Gain on disposition” line on our consolidated income statement in 2017. We reported before-tax losses of $ 26 million , $ 572 million and $ 582 million for the western Canada gas producing properties f or the years ended December 31, 2017 , 2016 and 2015, respectively . We reported before-tax equity earnings of $ 197 million , $ 89 million and $ 78 million for FCCL for the same periods, respectively. Both FCCL and the western Canada gas assets were reported within our Canada segment. For more information on the Canada disposition and our investment in Cenovus Energy see Note 6 —Investment in Cenovus E nergy, Note 14 — Fair Value Measurement, and Note 19 — Accumulated Other Comprehensive Loss. On July 31, 2017, we completed the sale of our interests in the San Juan Basin to an affiliate of Hilcorp Energy Company for $ 2.5 billion in cash after customary adjustments, and recognized a loss on disposition of $ 22 million. The transaction includes a contingent payment of up to $ 300 million. The six-year contingent payment , effective beginning January 1, 2018, is due annually for the periods in which the monthly U.S. Henry Hub price is at or above $ 3.20 per million British thermal units. In the second quarter of 2017, we recorded a before-tax impairment of $ 3.3 billion to reduce the carrying value of our interests in the San J uan Basin to fair value. At the time of disposition, the San Juan Basin interests had a net carrying value of approximately $ 2.5 billion, consisting of $ 2.9 billion of PP&E and $ 406 million of liabilities, primarily AROs . The before-tax loss associated w ith our interests in the San Juan Basin, including both the $3.3 billion impairment and $22 million loss on disposition noted above, was $ 3.2 billion , $ 2 39 million and $ 99 million for the years ended December 31 , 2017 , 2 016 and 2015, respectively. The San Juan Basin results of operations were reported within our Lower 48 segment. On September 29, 2017, we completed the sale of our interest in the Panhandle assets for $ 178 million in cash after customary adjustments, and recognized a before-tax loss on disposition of $ 28 million. At the time of the disposition, the carrying value of our interest was $ 206 million, consisting primarily of $ 279 million of PP&E and $ 72 million of AROs . Including the $ 28 million loss on disposition noted above, we reported before-tax losses for the Panhandle properties of $ 1 4 million , $ 2 1 million, and $ 41 million for the years ended December 3 1 , 2017 , 2016 and 2015, respectively. The Panhandle results were reported within our Lower 48 segment . 2016 In April 2016, we sold our interest in the Alaska Beluga River Unit natural gas field in the Cook Inlet for $ 134 million, net of settlement of gas imbalances and customary adjustments, and recognized a gain on disposition of $ 56 million. At the time of dispo sition, the net carrying value of our Beluga River Unit interest, which was included in the Alaska segment, was $ 78 million, consisting primarily of $ 100 million of PP&E and $ 19 million of AROs. In October 2016, we completed an asset exchange with Bonavis ta Energy in which we gave up approximately 141,000 net acres of non core developed properties in central Alberta in exchange for approximately 40,000 net acres of primarily undeveloped properties in northeast British Columbia. The fair value of the trans action was determined to be approximately $ 69 million and a before-tax impairment of $ 57 million was recognized in the third quarter of 2016 when the assets were considered held for sale, to reduce the carrying value to fair value. A loss on disposition o f approximately $ 1 million was recognized upon completion of the transaction. The divested properties were included in the Canada segment. Also in October 2016, we sold ConocoPhillips Senegal B.V., the entity that held our 35 percent interest in three ex ploration blocks offshore Senegal for $ 442 million and recognized a gain on disposition of $ 146 million. At the time of disposition, the carrying value of our interest was $ 286 million, which was primarily PP&E. Senegal results of operations were reporte d within our Other International segment. In November 2016, we completed the sale of our 40 percent interest in South Natuna Sea Block B for $ 225 million and recognized a loss on disposition of $ 26 million. Our interest in Block B was included in the Asi a Pacific and Middle East segment. In 2016, we recognized a before-tax impairment of $ 42 million at the time it was considered held for sale to reduce the carrying value to fair value. At the time of the disposition, t he carrying value of our interest wa s approximately $ 251 million, which included primarily $ 154 million of PP&E, $ 178 million of accounts receivable, $ 25 million of inventory, $ 54 million of deferred tax assets, $ 130 million of accounts payable and other accruals, and $ 38 million of employee benefit obligations. In December 2016, we completed the sale of certain mineral and non-mineral fee lands in northeastern Minnesota, which were included in the Lower 48 segment, for $ 148 million and recorded a gain on disposition of $ 4 million. The majority of the assets sold were acquired during the fourth quarter of 2016 as a result of ConocoPhillips holding a reversionary interest in the Greater Northern Iron Ore Properties Trust (the Trust), a grantor trust that owned mineral and surface interests in the Mesabi Iron Range in northeastern Minnesota and certain other personal property. Pursuant to the terms of the Trust Agreement, the Trust terminated on April 6, 2015. In November 2016, upon completion of the wind-down period, docu ments memorializing ConocoPhillips’ ownership of certain Trust property, including all of the Trust’s mineral properties and active leases, were delivered to us and we recognized the fair value of the net assets resulting in a gain of $ 88 million recorded in the “Other income” line on our consolidated income statement. At the time of the disposition, the carrying value of our interests, which included the assets obtained from the Trust, consisted of $ 144 million of PP&E. 2015 In November 2015, we sold a portion of our western Canadian properties located in British Columbia, Alberta, and Saskatchewan for $ 198 million and recognized a gain on disposition of $ 66 million. At the time of the disposition, t he carrying value of our interest, which was include d in the Canada segment, was $ 132 million, which included primarily $ 379 million of PP&E and $ 248 million of ARO. In December 2015, we sold a portion of our western Canadian properties located in central Alberta for $ 130 million and recognized a loss on disposition of $ 235 million. At the time of the disposition, t he carrying value of our interest, which was included in the Canada segment, was approximately $ 365 million, which included primarily $ 488 million of PP&E and $ 126 million of ARO. Additionally , other December 2015 disposition transactions are summarized below. We sold producing properties in East Texas and North Louisiana for $ 412 million and recognized a gain on disposition of $ 189 million. At the time of the disposition, t he carrying value of our interest, which was included in the Lower 48 segment, was $ 223 million, which included $ 351 million of PP&E and $ 128 million of ARO. We sold certain gas producing properties in South Texas for $ 358 million and recognized a gain on disposition of $ 2 01 million. At the time of the disposition, t he carrying value of our interest, which was included in the Lower 48 segment, was $ 157 million, which included $ 369 million of PP&E and $ 212 million of ARO. We sold certain pipeline and gathering assets in So uth Texas for $ 201 million and recognized a gain on disposition of $ 193 million. At the time of the disposition, t he carrying value of our interest, which was included in the Lower 48 segment, was $ 8 million, which primarily included $ 24 million of PP&E a nd $ 18 million of ARO. We also sold our 50 percent interest in the Russian joint venture, Polar Lights Company, for $ 98 million and recognized a gain on disposition of $ 58 million. At the time of the disposition, the carrying value of our equity method investment in Polar Lights Company, which was included in our Other International segment, was approximately $ 40 million. Acquisition In January 2018, we entered into an agreement to acquire certain oil and gas assets in Alaska for $ 400 million , subject to customary adjustments. The acquisition is subject to regulatory approval.

Investments, Loans and Long-Ter

Investments, Loans and Long-Term Receivables	12 Months Ended
	Dec. 31, 2017
Investments, Loans and Long-Term Receivables and Joint Venture Acquisition Obligation [Abstract]
Investments, Loans and Long-Term Receivables	Note 5 —Investments, Loans and Long-Term Receivables Components of investments, loans and long-term receivables at December 31 were: Millions of Dollars 2017 2016 Equity investments $ 9,129 20,364 Loans and advances—related parties 461 581 Long-term receivables 375 631 Other investments 95 96 $ 10,060 21,672 Equity Investments Affiliated companies in which we had a significant equity investment at December 31, 2017 , included: APLNG— 37.5 percent owned joint venture with Origin Energy ( 37.5 percent) and Sinopec ( 25 percent)—to develop coalbed methane production from the Bowen and Surat basins in Queensland, Australia, as well as process and export LNG. Qatar Liquefied Gas Company Limited (3) (QG3)— 30 percent owned joint venture with affiliates of Qatar Petroleum ( 68.5 percent) and Mitsui & Co., Ltd. ( 1.5 percent)—produces and liquefies natural gas from Qatar’s North Field, as well as exports LNG. Summarized 100 percent earnings information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2017 2016 2015 Revenues $ 11,554 10,149 11,003 Income (loss) before income taxes (2,875) 660 1,866 Net income (loss) (1,431) 799 1,801 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2017 2016 Current assets $ 2,920 3,578 Noncurrent assets 42,693 60,243 Current liabilities 2,453 2,352 Noncurrent liabilities 25,522 23,764 Our share of income taxes incurred directly by an equity company is reported in equity in earnings of affiliates, and as such is not included in income taxes in our consolidated financial statements. At December 31, 2017 , retained earnings included $ 20 million related to the undistributed earnings of affiliated companies. Dividends received from affiliates were $ 605 million , $ 398 million and $ 876 million in 2017 , 2016 and 2015 , respectively. APL NG APLNG is focused on coalbed methane production from the Bowen and Surat basins in Queensland, Australia, to supply the domestic gas market and on LNG processing and export sales. Our investment in APLNG gives us access to coalbed methane resources in Australia and enhances our LNG positi on. The majority of APLNG LNG is sold under two long - term sales and purchase agreements, supplemented with sales of additional LNG spot cargoes targeting the Asia Pacific markets. Origin Energy, an integrated Australian energy company, is the operator of APLNG’s production and pipeline system, while we operate the LNG facility. APLNG executed project financing agreem ents for an $ 8.5 billion project finance facility in 2012. The $ 8.5 billion project finance facility is composed of financing agreements executed by APLNG with the Export-Import Bank of the United States for approximately $ 2.9 billion, the Export-Import Bank of China for approximately $ 2.7 billion, and a syndicate of Australian and international commercial banks for approximately $ 2.9 billion. At December 31, 2017 , all amounts have been drawn from the facility. APLNG made its first principal and interest repayment in March 2017, and will continue to make bi-annual payments until March 2029. At December 31, 2017 , a balance of $ 7.9 billion was outstanding on the facility. In c onnection with the execution of the project financing, we provided a completion guarantee for our pro-rata share of the project finance facility until the project achieves financial completion. In October 2016, we reached financial completion for Train 1, which reduced our associated guarantee by 60 percent. In August 2017, we reached financial completion for Train 2, which removed the remaining guarantee. See Note 11 — Guarantees, for additional information . APLNG is considered a VIE, as it has entered into certain contractual arrangements that provide it with additional forms of subordinated financial support . See Note 2 — Variable Interest Entities (VIEs) for additional information. On July 1, 2016, APLNG chan ged its tax functional currency from Australian dollar to U.S. dollar and translated all APLNG assets and liabilities into U.S. dollar, utilizing the exchange rate as of that date. As a result of this change, we recorded a reduction to our investment in A PLNG for the deferred tax effect of $ 174 million in the “Equity in earnings of affiliates” line of our consolidated income statement. During the fourth quarter of 2015, due to the outlook for crude oil and natural gas prices at that tim e, the estimated fair value of our investment in APLNG declined to an amount below book value. Accordingly, we recorded a noncash $ 1,502 million before- and after-tax impairment, in our fourth-quarter 2015 results. During the first and second quarters of 2017, the outlook for crude oil prices deteriorated, and as a result of significantly reduced price outlooks, the estimated fair value of our investment in APLNG declined to an amount below carrying value. Based on a review of the facts and c ircumstances surrounding this decline in fair value, we concluded in the second quarter of 2017 the impairment was other than temporary under the guidance of Financial Accounting Standards Board (FASB) Accounting Standards Codification (ASC) Topic 323, “In vestments – Equity Method and Joint Ventures,” and the recognition of an impairment of our investment to fair value was necessary. Accordingly, we recorded a noncash $ 2,384 million, before- and after- tax impairment in our second-quarter 20 17 results. Fair value was estimated based on an internal discounted cash flow model using estimated future production, an outlook of future prices from a combination of exchanges (short-term) and pricing service companies (long-term), costs, a market out look of foreign exchange rates provided by a third party, and a discount rate believed to be consistent with those used by principal market participants. The impairment was included in the “Impairments” line on our consolidated income statement. At Decem ber 31, 2017 , the carrying value of our equity method investment in APLNG was $ 7,669 million . The historical cost basis of our 37.5 percent share of net assets on the books of APLNG was $ 7,213 million, resulting in a basis difference of $ 456 million on our books. The basis difference , which is substantially all associated with PP&E and subject to amortization , has been allocated on a relative fair value basis to individual expl oration and production license areas owned by APLNG, some of which are not currently in production. Any future additional payments are expected to be allocated in a similar manner. Each exploration license area will periodically be reviewed for any indic ators of potential impairment, which, if required, would result in acceleration of basis difference amortization. As the joint venture produces natural gas from each license, we amortize the basis difference allocated to that license using the unit-of-pro duction method. Included in net loss attributable to ConocoPhillips for 2017 , 2016 and 2015 was after-tax expense of $ 100 million, $ 92 million and $ 21 million, respectively, representing t he amortization of this basis difference on currently producing licenses. FCCL FCCL Partnership, a Canadian upstream 50 / 50 general partnership with Cenovus Energy Inc. , produces bitumen in the Athabasca oil sands in northeastern Alberta and sells the bitumen blend . Cenovus is the operator and managing partner of FCCL. On May 17, 2017, we completed the sale of our 50 percent nonoperated interest in the FCCL Partnership, as well as the majority of our western Canada gas assets to Cenovus Energy. Financial information presented within this footnote includes our historical interest up to the date of sale. For additional information on the Canada disposition and our investment in Cenovus Energy, see Note 4 — Assets Held for Sale, Sold or Acquired and Note 6 — Investment in Cenovus Energy. QG3 QG3 is a joint venture that owns an integrated large-scale LNG project located in Qatar . We provided project financing, with a current outstanding balance of $ 581 million as describ ed below under “Loans and Long-T erm Receivables.” At December 31, 2017 , the book value of our equity method investment in QG3 , excluding the project financing , was $ 886 million. We have terminal and pipeline use agreements with Golden Pass LNG Terminal and affiliated Golden Pass Pipeline near Sabine Pass, Texas, in which we have a 12.4 percent interest, intended to provide us wit h terminal and pipeline capacity for the receipt, storage and regasification of LNG purchased from QG3. However, currently the LNG from QG3 is being sold to markets outside of the United States . Loans and Long- T erm Receivables As part of our normal ongo ing business operations and consistent with industry practice, we enter into numerous agreements with other parties to pursue business opportunities. Included in such activity are loans and long-term receivables to certain affiliated and non-affiliated co mpanies. Loans are recorded when cash is transferred or seller financing is provided to the affiliated or non-affiliated company pursuant to a loan agreement. The loan balance will increase as interest is earned on the outstanding loan balance and will d ecrease as interest and principal payments are received. Interest is earned at the loan agreement’s stated interest rate. Loans and long-term receivables are assessed for impairment when events indicate the loan balance may not be fully recovered. At December 31 , 2017 , significant loans to affiliated companies include $ 581 million in project financing to QG3. We own a 30 percent interest in QG3, for which we use the equity method of accounting. The other participants in the project are affiliates of Qatar Petroleum and Mitsui. QG3 secured project financing of $ 4.0 billion in December 2005, consisting of $ 1.3 billion of loans from export credit agencies ( ECA), $ 1.5 billion from commercial banks, and $ 1.2 billion from ConocoPhillips. The ConocoPhillips loan facilities have substantially the same terms as the ECA and commercial bank facilities. On December 15, 2011, QG3 achieved financia l completion and all project loan facilities became nonrecourse to the project participants. Semi-annual repayments began in January 2011 and will extend through July 2022. The long-term portion of these loans is included in the “Loans and advances—relat ed parties” line on our consolidated balance sheet, while the short-term portion is in “Accounts and notes receivable—related parties.”

Investment in Cenovus Energy

Investment in Cenovus Energy	12 Months Ended
	Dec. 31, 2017
Investment in Cenovus Energy [Abstract]
Investments in Debt and Marketable Equity Securities (and Certain Trading Assets) Disclosure [Text Block]	Note 6 — Investment in Cenovus Energy On May 17, 2017, we completed the sale of our 50 percent nonoperated interest in the FCCL P artnership, as well as the majority of our western Canada gas assets to Cenovus Energy. Con sideration for the transaction included 208 million Cenovus Energy common shares , which approximated 16.9 percent of issued and outstanding Cenovus common shares at closing . See Note 4 — Assets Held for Sale, Sold or Acquired , for additional information on the Canada disposition . At closing, the fair value and cost basis of our investment in 208 million Cenovus Energy common shares was $ 1.96 billion based on a price of $ 9.41 per share on the New York Stock Exchange . We have classified our investment as an available-for-sale equ ity security on our consolidated balance sheet and, as of December 31, 2017, our investment is carried at fair value of $ 1.90 billion , reflecting the closing price of Cenovus Energy shares on the New York Stock Exchange of $ 9.13 per share. The carrying va lue reflects a before-tax and after-tax unrealized loss of $ 58 million over our cost basis of $ 1 .96 billion . The unrealized loss is reported as a component of accumu lated other comprehensive loss . See Note 14 —Fair Value Measurement , for additional information. We intend to decrease our investment over time through market transactions, private agreements or otherwise .

Suspended Wells

Suspended Wells	12 Months Ended
	Dec. 31, 2017
Suspended Wells [Abstract]
Suspended Wells	Note 7 —Suspended Wells and Other Exploration Expenses The following table reflects the net changes in suspended exploratory well costs during 2017, 2016 and 2015: Millions of Dollars 2017 2016 2015 Beginning balance at January 1 $ 1,063 1,260 1,299 Additions pending the determination of proved reserves 118 225 331 Reclassifications to proved properties (66) (27) (28) Sales of suspended well investment - (247) - Charged to dry hole expense (262) (148) (342) Ending balance at December 31 $ 853 1,063 1,260 The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2017 2016 2015 Exploratory well costs capitalized for a period of one year or less $ 67 132 235 Exploratory well costs capitalized for a period greater than one year 786 931 1,025 Ending balance $ 853 1,063 1,260 Number of projects with exploratory well costs capitalized for a period greater than one year 23 26 28 The following table provides a further aging of those exploratory well costs that have been capitalized for more than one year since the completion of drilling as of December 31, 2017: Millions of Dollars Suspended Since Total 2014–2016 2011–2013 2004–2010 Greater Poseidon—Australia (2) 177 63 102 12 Greater Clair—UK (2) 144 99 45 - Surmont—Canada (1) 117 34 59 24 NPRA—Alaska (1) 114 66 42 6 Barossa/Caldita—Australia (2) 77 - - 77 Middle Magdalena Basin—Colombia (1) 48 48 - - Bohai—China (2) 19 19 - - Kamunsu East—Malaysia (2) 19 - 19 - NC 98—Libya (2) 15 11 - 4 Sunrise—Australia (2) 13 - - 13 Other of $10 million or less each (1)(2) 43 20 6 17 Total $ 786 360 273 153 (1)Additional appraisal wells planned. (2)Appraisal drilling complete; costs being incurred to assess development. I n line with our July 2015 announcement of plans to reduce future deepwater exploration spending, we recognized before-tax cancellation costs of $ 335 million and wrote off $ 48 million of before-tax capitalized rig costs in rel ation to the termination of our Gulf of Mexico deepwater drillship contract with Ensco in the Lower 48 segment in 2015. In July 2016, we entered into an agreement to terminate our final Gulf of Mexico deepwater drillship contract. The drillship, used to drill our operated deepwater well inventory in the Gulf of Mexico through April 2016 , was contracted on a shared, three-year term. Accordingly, we recorded before-tax rig cancellation charges and third - party costs of $ 146 million in our Lower 4 8 segment in 2016. In February 2017, we reached a settlement agreement on our contract for the Athena drilling rig, initially secured for our four-well commitment program in Angola. As a result of the cancellation, we recognize d a before-tax charge of $ 43 million net in the first quarter of 2017 . These charges are included in the “Exploration expenses” line on our consolidated income statement.

Impairments

Impairments	12 Months Ended
	Dec. 31, 2017
Impairment Of Long Lived Assets [Abstract]
Impairments	Note 8 —Impairments During 2017, 2016 and 2015, we recognized the following before-tax impairment charges: Millions of Dollars 2017 2016 2015 Alaska $ 180 1 10 Lower 48 3,969 149 (2) Canada 22 88 4 Europe and North Africa 46 (160) 724 Asia Pacific and Middle East 2,384 44 1,508 Corporate - 17 1 $ 6,601 139 2,245 2017 In Alaska, we recorded impairments of $180 million primarily for the associated PP&E carrying value of our small interest in the Point Thomson unit. In the Lower 48, we recorded impairments of $3,969 million primarily due to certain developed properties which were written down to fair value less costs to sell. See Note 4 — Assets Held for Sale, Sold or Acquired , for additional information on our dispositions. In Canada, we recorded impairments of $22 million primarily due to cancelled projects. In Europe and North Africa, we recorded impairments of $46 million primarily due to reduced volume forecasts for a field in the United Kingdom and restructured ownership and a change in commercial premis es for a gas processing plant in Norway, partly offset by decreased ARO estimates on fields at or nearing the end of life which were impaired in prior years. In Asia Pacific and Middle East, we recorded impairments of $2,384 million, including the imp airm ent of our APLNG investment. For more information, see the “APLNG” section of Note 5 —Investments, Loans and Long-Term Receivables. The charges discussed below, within this section, are included in the “Exploration expenses” line on our consolid ated income statement and are not reflected in the table above. In our Lower 48 segment, we recorded a before-tax impairment of $ 51 million for the associated carrying value of capitalized undeveloped leasehold costs of Shenandoah in deepwater Gulf of Mexico following the suspension of appraisal activity by the operator. Additionally, we recorded a $38 million before-tax impairment f or mineral assets primarily due to plan of development changes. 2016 In the Lower 48, we recorded impairments of $149 million primarily due to cancelled projects associated with plan of development changes for Eagle Ford infrastructure, as well as lowe r natural gas prices and increased ARO estimates. In Canada, we recorded impairments of $88 million mainly due to plan of development changes, as well as certain developed properties being written down to fair value less costs to sell. In Europe and North Africa, we recorded a credit to impairment of $160 million, primarily in the United Kingdom, due to decreased ARO estimates on fields at or nearing the end of life which were impaired in prior years, partly offset by asset impairments due to lower natura l gas prices in the United Kingdom. In Asia Pacific and Middle East, we recorded impairments of $44 million, mainly due to a write-down to fair value less costs to sell of our developed properties in Block B, offshore Indonesia, in the third quarter of 2016. In Corporate, we recorded impairments of $17 million due to cancelled projects in our Houston and Bartlesville offices. The charges discussed below, within this section, are included in the “Exploration expenses” line on our consolidated income st atement and are not reflected in the table above. Charges recorded in e xploration expenses in 2016 were related to our decision announced in 2015 to reduce d eepwater exploration spending. In our Lower 48 segment, w e recorded a $203 million before-tax impairment for the associated carrying value of our Gibson and Tiber undeveloped leaseholds in deepwater Gulf of Mexico. Additionally, we recorded a $95 million before-tax impairment for the associated carrying value o f capitalized undeveloped leasehold costs of the Melmar prospect and a $79 million before-tax impairment, primarily as a result of changes in the estimated market value following the completion of marketing effort s . In our Canada segment, we recorded befo re-tax unproved property impairments of $31 million, primarily due to decisions to discontinue additional testing of undeveloped leaseholds. 2015 See the “APLNG” section of Note 5 —Investments, Loans and Long-Term Receivables, for information on the impairment of our APLNG investment included within the Asia Pacific and Middle East segment. In Europe and North Africa, we recorded impairments of $724 million, primarily in the United Kingdom as a result of lower natural gas prices and increases to AROs. The charges discussed below, within this section, are included in the “Exploration expenses” line on our consolidated income statement and are not reflected in the table above. In our Other International segment, we decided not to pursue fu rther evaluation of our Block 36 and Block 37 leases in Angola due to lack of commerciality of wells. Accordingly, we recorded before-tax impairments of $ 377 million and $ 116 million, respectively, for the associated carrying values of capitalized undeveloped leasehold costs. In our Lower 48 segment, we decided not to conduct further activity on certain Gulf of Mexico leases, given our strategic plans to reduce deepwater exploration spending, and accordingly recorded before-tax impairment s of $ 399 million for the associated carrying value of certain capitalized undeveloped leasehold cost s . In our Asia Pacific and Middle East segment, we decided to relinquish our Palangkaraya PSC in Indonesia. Accordingly, we recorded a before-tax impairment of $ 105 million for the associated carrying values of capitalized undeveloped leasehold cost. In our Alaska segment, we recorded a before-tax impairment of $ 575 million for the associated carrying value of capitalized undeveloped leasehold cost in the Chukchi Sea in Alaska . In our Canada segment , we recorded a before-tax impairment of $ 102 million for the Duvernay, Thornbury, Saleski and Crow Lake areas driven primarily by the lack of commerciality of wells .

Asset Retirement Obligations an

Asset Retirement Obligations and Accrued Environmental Costs	12 Months Ended
	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations and Accrued Environmental Costs	Note 9 —Asset Retirement Obligations and Accrued Environmental Costs Asset retirement obligations and accrued environmental costs at December 31 were: Millions of Dollars 2017 2016 Asset retirement obligations $ 7,798 8,405 Accrued environmental costs 180 247 Total asset retirement obligations and accrued environmental costs 7,978 8,652 Asset retirement obligations and accrued environmental costs due within one year* (347) (227) Long-term asset retirement obligations and accrued environmental costs $ 7,631 8,425 *Classified as a current liability on the balance sheet under "Other accruals." Asset Retirement Obligations We record the fair value of a liability for an ARO when it is incurred (typically when the asset is installed at the production location). When the liability is initially recorded, we capitalize the associated asset retirement cost by increasing the carrying amount of the related PP&E. If, in subsequent periods, our estimate of this liability changes, we will record an adjustment to both the liability and PP&E. Over time, the liability increases for the change in its present value, while the capitalized cost depreciates over the useful life of the related asset. We have numerous AROs we are required to perform under law or contract once an asset is permanently taken out of service. Most of these obligations are not expected to be paid until several years, or decades, in the future and will be funded from general company resources at the time of removal. Our largest individual obligations involve plugging and abandonment of wells and removal and disposal of offshore oil and gas platforms around the world, as well as oil and gas production facilities and pipelines in Alaska. During 2017 and 2016, our overall ARO changed as follows: Millions of Dollars 2017 2016 Balance at January 1 $ 8,405 9,911 Accretion of discount 358 420 New obligations 113 180 Changes in estimates of existing obligations (150) (1,197) Spending on existing obligations (152) (314) Property dispositions (1,065) (150) Foreign currency translation 289 (445) Balance at December 31 $ 7,798 8,405 Accrued Environmental Costs Total accrued environmental costs at December 31, 2017 and 2016 , were $ 180 million and $ 247 million, respectively. We had accrued environmental costs of $ 105 million and $ 183 million at December 31, 2017 and 2016 , respectively, related to remediation activities in the United States and Canada. We had also accrued in Corporate and Other $ 60 million and $ 51 million o f environmental c osts associated with sites no longer in operation at December 31, 2017 and 2016 , respectively. In addition, $ 15 million and $ 13 million were included at both December 31, 2017 and 2016 , respective ly, where the c ompany has been named a potentially responsible party under the Federal Comprehensive Environmental Response, Compensation and Liability Act, or similar state laws. Accrued environmental liabilities are expected to be paid over periods exte nding up to 30 years. Expected expenditures for environmental obligations acquired in various business combinations are discounted using a weighted-average 5 percent discount factor, resulting in an accrued balance for acquired environmental liabilities of $ 96 million at December 31, 2017 . The expected future undiscounted payments related to the portion of the accrued environmental costs that have been discounted are: $ 12 million in 2018 , $ 10 million in 2019 , $ 5 million in 2020 , $ 10 million in 2021 , $ 3 million in 2022 , and $ 106 million for all future years after 2022 .

Debt

Debt	12 Months Ended
	Dec. 31, 2017
Debt [Abstract]
Debt	Note 10 —Debt Long-term debt at December 31 was: Millions of Dollars 2017 2016 9.125% Debentures due 2021 $ 150 150 8.20% Debentures due 2025 150 150 8.125% Notes due 2030 600 600 7.9% Debentures due 2047 100 100 7.8% Debentures due 2027 300 300 7.65% Debentures due 2023 88 88 7.40% Notes due 2031 500 500 7.375% Debentures due 2029 92 92 7.25% Notes due 2031 500 500 7.20% Notes due 2031 575 575 7% Debentures due 2029 200 200 6.95% Notes due 2029 1,549 1,549 6.875% Debentures due 2026 67 67 6.65% Debentures due 2018 - 297 6.50% Notes due 2039 2,750 2,750 6.00% Notes due 2020 - 1,000 5.951% Notes due 2037 645 645 5.95% Notes due 2036 500 500 5.95% Notes due 2046 500 500 5.90% Notes due 2032 505 505 5.90% Notes due 2038 600 600 5.75% Notes due 2019 - 2,250 5.20% Notes due 2018 - 500 4.95% Notes due 2026 1,250 1,250 4.30% Notes due 2044 750 750 4.20% Notes due 2021 1,000 1,250 4.15% Notes due 2034 500 500 3.35% Notes due 2024 1,000 1,000 3.35% Notes due 2025 500 500 2.875% Notes due 2021 750 750 2.4% Notes due 2022 1,000 1,000 2.2% Notes due 2020 500 500 1.5% Notes due 2018 - 750 1.05% Notes due 2017 - 1,000 Floating rate term loan due 2019 at 2.31% – 2.75% during 2017 and 1.94% – 2.31% during 2016 - 1,450 Floating rate notes due 2018 at 1.24% – 1.75% during 2017 and 0.69% – 1.24% during 2016 250 250 Floating rate notes due 2022 at 1.81% – 2.32% during 2017 and 1.26% – 1.81% during 2016 500 500 Industrial Development Bonds due 2017 through 2038 at 0.64% – 1.74% during 2017 and 0.01% – 0.91% during 2016 18 18 Marine Terminal Revenue Refunding Bonds due 2031 at 0.64% – 1.74% during 2017 and 0.01% – 0.95% during 2016 265 265 Other 23 24 Debt at face value 18,677 26,175 Capitalized leases 774 852 Net unamortized premiums, discounts and debt issuance costs 252 248 Total debt 19,703 27,275 Short-term debt (2,575) (1,089) Long-term debt $ 17,128 26,186 Maturities of long-term borrowings, inclusive of net unamortized premiums and discounts, in 2018 through 2022 are: $ 2,575 million, $ 113 million, $ 97 million, $ 236 million and $ 1,602 million, respectively. We have a revolving credit facility totaling $ 6.75 billion , expiring in June 2019 . Our revolving credit facility may be used for direct bank borrowings, the issuance of letters of credit totaling up to $ 500 million, or as support for our commercial paper programs. The revolving credit facility is broadly syndicated among financial institutions and does not contain any material adverse change provisions or any covenants requiring maintenance of specifi ed financial ratios or credit ratings. The facility agreement contains a cross-default provision relating to the failure to pay principal or interest on other debt obligations of $ 200 million or more by ConocoPhillips, or any of its consolidated subsidiaries. Credit facility borrowings may bear interest at a margin above rates offered by certain designated banks in the London interbank market or at a margin above the overnight federal funds rate or prime rates offered by certain designated banks in the United States. The agreement calls for commitment fees on available, but unused, amounts. The agreement also contains early termination rights if our current directors or their approved successors cease to be a majority of the Board of Directors. We have two commercial paper programs. The ConocoPhillips $ 6.25 billion commercial paper program is available to fund short-term working capital needs. We also have the ConocoPhillips Qatar Funding Ltd. $ 500 million commercial paper program , which is used to fund commitments relating to QG3. Commercial paper maturities are generally limited to 90 days. W e had no commercial paper outstandin g at December 31, 2017 or 2016 , under either the ConocoPhillips or the ConocoPhillips Qatar Funding Ltd. commercial paper program. We had no direct borrowings or letters of credit issued under the revolving credit facility. Since we had no commercial paper outstanding and had issued no letters of credit, we had access to $ 6.75 billion in borrowing capacity under our revolving credit facility at December 31, 2017 . In 2017 , two notes totaling $ 1,001 million were paid at maturity , including the $ 1.0 billion 1.05% Notes due 2017 . Also i n 2017, we prepaid the $ 1,450 million term loan facility due in 2019. We also redeemed a total $ 5.0 billion of debt, described below, incurring $ 301 million in premiums above book va lue, which are reported in the “Other expense” line on our consolidated income statement. 6.65% Debentures due 2018 with principal of $297 million. 5.20% Notes due 2018 with principal of $ 500 million. 1.5 % Notes due 2018 with principal of $ 750 million. 5.75% Notes due 2019 with principal of $ 2.25 billion. 6.00% Notes due 2020 with principal of $ 1.0 billion. 4.20% Notes due 2021 with principal of $ 1. 25 b illion (partial redemption of $250 million ) . In the fourth quarter of 2017, we gave notice to redeem t he following debt instruments totaling $ 2.25 billion. 2.2% Notes due 2020 with principal of $ 500 million. 4.20% Notes due 2021 with remaining principal of $ 1.0 billion. 2.875% Notes due 2021 with principal of $ 750 million . The prepayments occurred on January 22, 2018, and we incurred premiums above book value of $ 75 million. At both December 31, 2017 and 2016 , we had $ 283 million of certain variable rate demand bonds (VRDBs) outstanding with maturities ranging through 2035. The VRDBs ar e redeemable at the option of the bondholders on any business day. The VRDBs are included in the “Long-term debt” line on our consolidated balance sheet. During 2013 , a lease of a semi-submersible floating production system (FPS) commenced for the Gumusut development, located in Malaysia, in which we are a co-venturer. The FPS lease provides for an initial noncancelable term of 15 years, a subsequent 5 -year cancelable term with no required lease payments, and an additional 5 -year term with terms and conditions to be agreed at a later date. The lease has no ongoing purchase options or escalation clauses. Adjustments to provis ional contingent rental payments may occur due to the finalization of actual commissioning costs. The lease does not impose any significant restrictions concerning dividends, debt or further leasing activities. A capital lease asset and capital lease ob ligation were recognized for our proportionate interest in the FPS of $ 906 million, based on the present value of the future minimum lease payments using our before-tax incremental borrowing rate of 3.58 percent for debt with similar terms. Our proportionate interest in the FPS is 29 percent as of December 31, 2017 . The net carrying value of the capital lease asset was approximately $ 434 million and $ 540 million a s of December 31, 2017 and 2016 , respectively. T he capital lease asset is being depreciated over a period consistent with the estimated proved reserves of Gumusut using the unit-of-production method with the associated depreciation included in the “Depreciation, depletion and amortiz ation” line on our consolidated income statement. As of December 31, 2017 and 2016 , accumulated depreciation of the capital lease asset amounted to approximately $ 381 million and $ 268 million, respectively. At December 31, 2017, future minimum payments due under capital leases were: Millions of Dollars 2018 $ 108 2019 106 2020 106 2021 88 2022 88 Remaining years 487 Total 983 Less: portion representing imputed interest (209) Capital lease obligations $ 774

Guarantees

Guarantees	12 Months Ended
	Dec. 31, 2017
Guarantees [Abstract]
Guarantees	Note 11 —Guarantees At December 31, 2017 , we were liable for certain contingent obligations under various contractual arrangements as described below. We recognize a liability, at inception, for the fair value of our obligation as a guarantor for newly issued or modified guarantees. Unless the carrying amount of the liability is noted below, we have not recognized a liability because the fair value of the obligation is immaterial. In addition, unless otherwise stated, we are not currently per forming with any significance under the guarantee and expect future performance to be either immaterial or have only a remote chance of occurrence. APLNG Guarantees At December 31, 2017 , we had outstanding multiple guarantees in connection with our 37. 5 percent ownership interest in APLNG. The following is a description of the guarantees with values calculated utilizing December 2017 exchange rates: We guaranteed APLNG’s performance with regard to a construction contract executed in connection with APLNG’s issuance of the Train 1 and Train 2 Notices to Proceed. Our maximum potential amount of future payments related to this guarantee became immaterial in the second quarter of 2017. We issued a con struction completion guarantee related to the third-party project financing secured by APLNG. In October 2016, we reached financial completion for Train 1, releasing a portion of our guarantee. In August 2017 , the two-train project finance lenders’ test was completed, releasing the remaining guarantee. During the third quarter of 2016, we issued a guarantee to facilitate the withdrawal of our pro-rata portion of the funds in a project finance reserve account. We estimate the remaining term of this guaran tee is 12 years . Our maximum exposure under this guarantee is approximately $ 200 million and may become payable if an enforcement action is commenced by the project finance lenders against APLNG. At December 3 1 , 201 7 , the carrying value of this guarantee is approximately $ 14 million. In conjunction with our original purchase of an ownership interest in APLNG from Origin Energy in October 2008, we agreed to reimburse Origin Energy for our share of the existing contingent liability arising under guarantees of an existing obligation of APLNG to deliver natural gas under several sales agreements with remaining terms of up to 24 years . Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $ 96 0 m illion ($ 1.71 billion in the event of intentional or reckless breach) and would become payable if APLNG fails to meet its obligations under these agreements and the obligations cannot otherwise be mitigated. Future payments are considered unli kely, as the payments, or cost of volume delivery, would only be triggered if APLNG does not have enough natural gas to meet these sales commitments and if the co-venturers do not make necessary equity contributions into APLNG. We have guaranteed the perf ormance of APLNG with regard to certain other contracts executed in connection with the project’s continued development. The guarantees have remaining terms of up to 28 years or the life of the venture. Our maximum potential amount of future payments rel ated to these guarantees is approximately $ 150 million and would become payable if APLNG does not perform. Other Guarantees We have other guarantees with maximum future potential payment amounts totaling approximately $ 780 million, which consist primarily of guarantees of the residual value of leased office buildings, guarantees of the residual value of leased corporate aircraft, and a guarantee for our portion of a joint venture’s project finance reserve accounts . These guarantees have remaining terms of up to 5 years and would become payable if, upon sale, certain asset values are lower than guaranteed amounts, business conditions decline at guaranteed entities, or as a result of nonperformance of contractual terms by guaranteed parties. Indemnifications Over the years, we have entered into agreements to sell ownership interests in certain corporations, joint ventures and assets that gave rise to qualifying indemnifications. These agreements include indemnifications for taxes, environmental liabilities, employee claims and litigation. The terms of th ese indemnifications vary greatly. The majority of these indemnifications are related to environmental issues, the term is generally indefinite and the maximum amount of future payments is generally unlimited. The carrying amount recorded for these indem nifications at December 31, 2017 , was approximately $ 100 million. We amortize the indemnification liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of indemnity. In cases where the indemnif ication term is indefinite, we will reverse the liability when we have information the liability is essentially relieved or amortize the liability over an appropriate time period as the fair value of our indemnification exposure declines. Although it is r easonably possible future payments may exceed amounts recorded, due to the nature of the indemnifications, it is not possible to make a reasonable estimate of the maximum potential amount of future payments. Included in the recorded carrying amount at Dec ember 31, 2017 , were approximately $ 40 million of environmental accruals for known contamination that are included in the “Asset retirement obligations and accrued environmental costs” line on our consolidated balance sheet. For additional information abo ut environmental liabilities, see Note 12 —Contingencies and Commitments. In 2012 , we completed the separation of our downstream business, creating two independent energy companies: ConocoPhillips and Phillips 66. On March 1, 2015 , a supplier to one o f the refineries included in Phillips 66 as part of the separation of our downstream business formally registered Phillips 66 as a party to the supply agreement, thereby triggering a guarantee we provided at the time of separation. Our maximum potential l iability for future payments under this guarantee, which would become payable if Phillips 66 does not perform its contractual obligations under the supply agreement, is approximately $ 1. 31 billion. At December 31, 2017 , the carrying value of this guarante e is approximately $ 98 million and the remaining term is seven years . Because Phillips 66 has indemnified us for losses incurred under this guarantee, we have recorded an indemnification asset from Phillips 66 of approximately $ 98 million. The recorded i ndemnification asset amount represents the estimated fair value of the guarantee; however, if we are required to perform under the guarantee, we would expect to recover from Phillips 66 any amounts in excess of that value, provided Phillips 66 is a going c oncern.

Contingencies and Commitments

Contingencies and Commitments	12 Months Ended
	Dec. 31, 2017
Contingencies and Commitments [Abstract]
Contingencies and Commitments	Note 12 —Contingencies and Commitments A number of lawsuits involving a variety of claims arising in the ordinary course of business have been filed against ConocoPhillips . We also may be required to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various active and inactive sites. We regularly assess the need for accounting recognition or disclosure of these contingencies. In the case of all kn own contingencies (other than those related to income taxes), we accrue a liability when the loss is probable and the amount is reasonably estimable. If a range of amounts can be reasonably estimated and no amount within the range is a better estimate tha n any other amount, then the minimum of the range is accrued. We do not reduce these liabilities for potential insurance or third-party recoveries. If applicable, we accrue receivables for probable insurance or other third-party recoveries. With respect to income tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is less than certain. See Note 18 —Income Taxes, for additional information about income tax-related contingencies. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statement s. As we learn new facts concerning contingencies, we reassess our position both with respect to accrued liabilities and other potential exposures. Estimates particularly sensitive to future changes include contingent liabilities recorded for environment al remediation, tax and legal matters. Estimated future environmental remediation costs are subject to change due to such factors as the uncertain magnitude of cleanup costs, the unknown time and extent of such remedial actions that may be required, and t he determination of our liability in proportion to that of other responsible parties. Estimated future costs related to tax and legal matters are subject to change as events evolve and as additional information becomes available during the administrative and litigation processes. Environmental We are subject to international, federal, state and local environmental laws and regulations. When we prepare our consolidated financial statements, we record accruals for environmental liabilities based on managem ent’s best estimates, using all information that is available at the time. We measure estimates and base liabilities on currently available facts, existing technology, and presently enacted laws and regulations, taking into account stakeholder and busines s considerations. When measuring environmental liabilities, we also consider our prior experience in remediation of contaminated sites, other companies’ cleanup experience, and data released by the U.S. Environmental Protection Agency (EPA) or other organ izations. We consider unasserted claims in our determination of environmental liabilities, and we accrue them in the period they are both probable and reasonably estimable. Although liability of those potentially responsible for environmental remediation costs is generally joint and several for federal sites and frequently so for other sites, we are usually only one of many companies cited at a particular site. Due to the joint and several liabilities, we could be responsible for all cleanup costs relate d to any site at which we have been designated as a potentially responsible party. We have been successful to date in sharing cleanup costs with other financially sound companies. Many of the sites at which we are potentially responsible are still under investigation by the EPA or the agency concerned. Prior to actual cleanup, those potentially responsible normally assess the site conditions, apportion responsibility and determine the appropriate remediation. In some instances, we may have no liability or may attain a settlement of liability. Where it appears that other potentially responsible parties may be financially unable to bear their proportional share, we consider this inability in estimating our potential liability, and we adjust our accruals a ccordingly. As a result of various acquisitions in the past, we assumed certain environmental obligations. Some of these environmental obligations are mitigated by indemnifications made by others for our benefit , and some of the indemnifications are subject to dollar limits and time limits. We are currently participating in environmental assessments and cleanups at numerous federal Superfund and comparable state and international sites. After an assessment of environmental exposures for cleanup and other costs, we make accruals on an undiscounted basis (except those acquired in a purchase business combination, which we record on a discounted basis) for planned investigation and remediation activities for sites where it is probable future costs will be incurred and these costs can be reasonably estimated. We have not reduced these accruals for possible insurance recoveries. In the future, we may be involved in additional environmental assessments, cleanups and proceedings. See Note 9 —Asset Retirement Obligations and Accrued Environmental Costs, for a summary of our accrued environmental liabilities. Legal Proceedings We are subject to various lawsuits and claims including but not limited to matters invo lving oil and gas royalty and severance tax payments, gas measurement and valuation methods, contract disputes, environmental damages, personal injury, and property damage. Our primary exposures for such matters relate to alleged royalty and tax underpaym ents on certain federal, state and privately owned properties and claims of alleged environmental contamination from historic operations. We will continue to defend ourselves vigorously in these matters. Our legal organization applies its knowledge, expe rience and professional judgment to the specific characteristics of our cases, employing a litigation management process to manage and monitor the legal proceedings against us. Our process facilitates the early evaluation and quantification of potential e xposures in individual cases. This process also enables us to track those cases that have been scheduled for trial and/or mediation. Based on professional judgment and experience in using these litigation management tools and available information about current developments in all our cases, our legal organization regularly assesses the adequacy of current accruals and determines if adjustment of existing accruals, or establishment of new accruals, is required. Other Contingencies We have contingent liab ilities resulting from throughput agreements with pipeline and processing companies not associated with financing arrangements. Under these agreements, we may be required to provide any such company with additional funds through advances and penalties for fees related to throughput capacity not utilized. In addition, at December 31, 2017 , we had performance obligations secured by letters of credit of $ 338 million (issued as direct bank letters of credit) related to various purchase commitments f or materials, supplies, commercial activities and services incident to the ordinary conduct of business. In 2007, we announced we had been unable to reach agreement with respect to our migration to an empresa mixta structure mandated by the Venezuelan government’s Nationalization Decree. As a result, Venezuela’s national oil company, Petróleos de Venezuela S.A. (PDVSA), or its affiliates, directly assumed control over ConocoPhillips’ interests in the Petrozuata and Hamaca heavy oil ventures and the offshore Corocoro development project. In response to this expropriation, we filed a request for international arbitration on November 2, 2007, with the World Bank’s International Centre for Settlement of Investment Disp utes (ICSID). An arbitration hearing was held before an ICSID tribunal during the summer of 2010. On September 3, 2013, an ICSID arbitration tribunal held that Venezuela unlawfully expropriated ConocoPhillips’ significant oil investments in June 2007. O n January 17, 2017, the Tribunal reconfirmed the decision that the expropriation was unlawful. A separate arbitration phase is currently proceeding to determine the damages owed to ConocoPhillips for Venezuela’s actions. Separate arbitrations for contrac tual compensation against PDVSA are also pending before an In ternational Chamber of Commerce (ICC) arbitration tribunal. In addition, ConocoPhillips broug ht fraudulent transfer actions in the U.S. District Court of Delaware, alleging that PDVSA has taken actions to improperly expatriate assets from the United States to Venezuela in an effort to avoid judgment creditors. In 2008, Burlington Resources, Inc., a wholly owned subsidiary of ConocoPhillips, initiated arbitration before ICSID against The Republic of Ecuador challenging a windfall profits tax and subsequent expropriation of Blocks 7 and 21. On April 24, 2012, Ecuador filed environmental and infrastructure counterclaims against Burlington relating to alleged impacts to Blocks 7 and 21. Ecuador also filed the environmental and infrastructure counterclaims relating to Blocks 7 and 21 in a separate, parallel ICSID arbitration brought by Perenco Ecuador Limited, Burlington's co-venturer and consortium operator. Perenco and Burlington each have joint lia bility for the counterclaims under their joint operating agreements. On December 14, 2012, the ICSID tribunal issued a decision in favor of Burlington, finding that Ecuador's seizure of Blocks 7 and 21 was an unlawful expropriation in violation of the Ecua dor-U.S. Bilateral Investment Treaty. In February 2017, the ICSID tribunal unanimously awarded Burlington $ 380 million for Ecuador’s unlawful expropriation and breach of the U.S.-Ecuador bilateral investment treaty. The tribunal also issued a separate decision finding Ecuador to be entitled to $ 42 million for environmental and infrastructure impacts to Blocks 7 and 21. In December 2017, Burlington and Ecuador entered into a settlement agreement by which Ecuador agreed t o pay Burlington $ 337 million in two installments. The first installment of $ 75 million was timely paid on December 1, 2017. The second installment of $ 262 million is to be paid by April 2018. The sett lement includes an offset for the counterclaims decision, of which Burlington is entitled to a $ 24 million contribution from Perenco pursuant to the joint operating agreement. The ICSID arbitration between Perenco and Ecuador remains pending. In December 2016, ConocoPhillips Angola filed a notice of arbitration against Sonangol E.P. under the Block 36 Production Sharing Contract relating to disputes arising thereunder. The arbitration is being conducted under the United Nations Commission on International Trade Laws (UNCITRAL) rules using a three - person tribunal. In June 2017, FAR Ltd. initiated arbitration before the ICC against ConocoPhillips Senegal B.V. in connection with the sale of ConocoPhillips Senegal B.V. to Woodside E nergy Holdings (Senegal) Limited in 2016. The arbitral tribunal is in the process of being constituted. In 2017 and early 2018, cities and/or counties in California and New York have filed lawsuits against oil and gas companies, including ConocoPhillips, seeking compensatory damages and equitable relief to abate alleged climate change impacts. ConocoPhillips will be vigorously defending against these lawsuits. Long-Term Throughput Agreements and Take-or-Pay Agreements We have certain throughput agreement s and take-or-pay agreements in support of financing arrangements. The agreements typically provide for natural gas or crude oil transportation to be used in the ordinary course of the company’s business. The aggregate amounts of estimated payments under these various agreements are: 2018 —$ 21 million; 2019 —$ 7 million; 2020 —$ 7 million; 2021 —$ 7 million; 2022 —$ 7 million; and 2023 and after—$ 74 million. Total payments under the agreements were $ 43 million in 2017 , $ 42 million in 2016 and $ 27 million in 2015 .

Derivative and Financial Instru

Derivative and Financial Instruments	12 Months Ended
	Dec. 31, 2017
Derivative and Financial Instruments [Abstract]
Derivative and Financial Instruments	Note 13 —Derivative and Financial Instruments We use futures, forwards, swaps and options in various markets to meet our customer needs and capture market opportunities. Our commodity business primarily consists of natural gas, crude oil, bitumen, LNG and natural gas liquids. Our derivative instru ments are held at fair value on our consolidated balance sheet. Where these balances have the right of setoff, they are presented on a net basis. Related cash flows are recorded as operating activities on our consolidated statement of cash flows. On our consolidated income statement, realized and unrealized gains and losses are recognized either on a gross basis if directly related to our physical business or a net basis if held for trading. Gains and losses related to contracts that meet and are design ated with the normal purchase normal sale exception are recognized upon settlement. We generally apply this exception to eligible crude contracts. We do not use hedge accounting for our commodity derivatives. The following table presents the gross fair values of our commodity derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet: Millions of Dollars 2017 2016 Assets Prepaid expenses and other current assets $ 275 268 Other assets 36 44 Liabilities Other accruals 282 300 Other liabilities and deferred credits 28 34 The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars 2017 2016 2015 Sales and other operating revenues $ 77 (198) 231 Other income - (1) 2 Purchased commodities (61) 161 (201) The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts: Open Position Long/(Short) 2017 2016 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (29) (31) Basis 12 2 Foreign Currency Exchange Derivatives We have foreign currency exchange rate risk resulting from international operations. Our foreign currency exchange derivative activity primarily relates to managing our cash-related foreign currency exchange rate exposures, such as firm commitments for capital pro gram s or local c urrency tax payments, dividends and cash returns from net investments in foreign affiliates , and investments in available-for-sale securities . We do not elect hedge accounting on our forei gn currency exchange derivatives. The following table presents the gross fair values of our foreign currency exchange derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet: Millions of Dollars 2017 2016 Assets Prepaid expenses and other current assets $ 1 1 Other assets 6 - Liabilities Other accruals - 168 Other liabilities and deferred credits 15 - In December 2017, we entered into foreign exchange zero cost collars buying the right to sell $1.25 billion CAD at $0.707 CAD and selling the right to buy $1.25 billion CAD at $0.842 CAD against the U.S. dollar. The (gains) losses from foreign currency exchange derivatives incurred and the line item where they appear on our consolidated income statement were: Millions of Dollars 2017 2016 2015 Foreign currency transaction (gains) losses $ 13 247 (33) We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency 2017 2016 Foreign Currency Exchange Derivatives Sell U.S. dollar, buy other currencies (1) USD - 13 Buy U.S. dollar, sell other currencies (2) USD - 25 Buy British pound, sell other currencies (3) GBP - 1,069 Sell British pound, buy other currencies (4) GBP 1 51 Sell Canadian dollar, buy U.S. dollar CAD 1,225 - (1)Primarily Canadian dollar. (2)Primarily British pound. (3)Primarily Canadian dollar. (4)Primarily euro and Norwegian krone. Financial Instruments We invest excess cash in financial instruments with maturities based on our cash forecasts for the various currency pools we manage. The maturities of these investments may from time to time extend beyond 90 days. The types of financial instruments that we currently invest include: Time deposits: Interest bearing deposits placed with approved financial institutions. Commercial paper: Unsecured promissory notes issued by a corporation, commercial bank or gov ernment agency purchased at a discount to mature at par. These financial instruments appear in the “Cash and cash equivalents” line of our consolidated balance sheet if the maturities at the time we made the investments were 90 days or less; otherwise, th ese financial instruments are included in the “Short - term investments” line on our consolidated balance sheet . Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments 2017 2016 2017 2016 Cash $ 948 623 - - Time deposits Remaining maturities from 1 to 90 days 5,004 2,987 821 39 Remaining maturities from 91 to 180 days - - - 11 Commercial paper Remaining maturities from 1 to 90 days 373 - 978 - Remaining maturities from 91 to 180 days - - 74 - $ 6,325 3,610 1,873 50 Credit Risk Financial instruments potentially exposed to concentrations of credit risk consist primarily of cash equivalents, short-term investments, over-the-counter (OTC) derivative contracts and trade receivables. Our cash equivalents and short-term investments are placed in high-quality commercial paper, government money market funds, government debt securities and time deposits with major international banks and financial institutions. The credit risk from our OTC derivative contracts, such as fo rwards , swaps and options , derives from the counterparty to the transaction. Individual counterparty exposure is managed within predetermined credit limits and includes the use of cash-call margins when appropriate, thereby reducing the risk of significan t nonperformance. We also use futures, swaps and option contracts that have a negligible credit risk because these trades are cleared with an exchange clearinghouse and subject to mandatory margin requirements until settled; however, we are exposed to the credit risk of those exchange brokers for receivables arising from daily margin cash calls, as well as for cash deposited to meet initial margin requirements. Our trade receivables result primarily from our petroleum operations and reflect a broad natio nal and international customer base, which limits our exposure to concentrations of credit risk. The majority of these receivables have payment terms of 30 days or less , and we continually monitor this exposure and the creditworthiness of the counterpar ties. We do not generally require collateral to limit the exposure to loss; however, we will sometimes use letters of credit, prepayments and master netting arrangements to mitigate credit risk with counterparties that both buy from and sell to us, as the se agreements permit the amounts owed by us or owed to others to be offset against amounts due to us. Certain of our derivative instruments contain provisions that require us to post collateral if the derivative exposure exceeds a threshold amount. We ha ve contracts with fixed threshold amounts and other contracts with variable threshold amounts that are contingent on our credit rating. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically revert to zero if we fall below investment grade. Cash is the primary collateral in all contracts; however, many also permit us to post letters of credit as collateral, such as transactions administered through the New York Mercantile Ex change. The aggregate fair value of all derivative instruments with such credit risk-related contingent features that were in a liability position on December 31, 2017 and December 31, 2016 , was $ 55 million and $ 42 million, respectively. For these instruments , no collateral was posted as of December 31, 2017 , or December 31, 2016 . If our credit rating had been downgraded below investment grade on December 31, 2017 , we would be required to post $ 55 million of additional collateral, either with cash or letters of credit.

Fair Value Measurement

Fair Value Measurement	12 Months Ended
	Dec. 31, 2017
Fair Value Measurement [Abstract]
Fair Value Measurement	Note 14 —Fair Value Measurement We carry a portion of our assets and liabilities at fair value that are measured at a reporting date using an exit price (i.e., the price that would be received to sell an asset or paid to transfer a liability) and disclosed according to the quality of valuation inputs under the following hierarchy: Level 1: Quoted prices (unadjusted) in an active market for identical assets or liabilities. Level 2: Inputs other than quoted prices that are directly or indirectly obs ervable. Level 3: Unobservable inputs that are significant to the fair value of assets or liabilities. The classification of an asset or liability is based on the lowest level of input significant to its fair value. Those that are initially classified as Level 3 are subsequently reported as Level 2 when the fair value derived from unobservable inputs is inconsequential to the overall fair value, or if corroborated market data becomes available. Assets and liabilities initially reported as Level 2 are sub sequently reported as Level 3 if corroborated market data is no longer available. Transfers occur at the end of the reporting period. At the end of the fourth quarter of 2017, our $ 1,899 million investment in Cenovus Energy was transferred from Level 2 t o Level 1 due to the lapsing of trading restrictions . There were no other material transfers in or out of Level 1 during 2017 or 2016 . Recurring Fair Value Measurement Financial assets and liabilities reported at fair value on a recurring basis primarily include commodity derivatives. Level 1 derivative assets and liabilities primarily represent exchange-traded futures and options that are valued using unadjusted prices available from the underlying exchange. This also includes our investment in common shares of Cenovus Energy, which is valued using quotes for shares on the New York Stock Exchange. Level 2 derivative assets and liabiliti es primarily represent OTC swaps, options and forward purchase and sale contra cts that are valued using adjusted exchange prices, prices provided by brokers or pricing service companies that are all corroborated by market data. Level 3 derivative assets a nd liabilities consist of OTC swaps, options and forward purchase and sale contracts where a significant portion of fair value is calculated from underlying market data that is not readily available. The derived value uses industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results in management’s best estimate of fair value. Level 3 act ivity was not material for all periods presented. The following table summarizes the fair value hierarchy for gross financial assets and liabilities (i.e., unadjusted where the right of setoff exists for commodity derivatives accounted for at fair value o n a recurring basis): Millions of Dollars December 31, 2017 December 31, 2016 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ 1,899 - - 1,899 - - - - Commodity derivatives 175 106 30 311 194 96 22 312 Total assets $ 2,074 106 30 2,210 194 96 22 312 Liabilities Commodity derivatives $ 158 111 41 310 207 105 22 334 Total liabilities $ 158 111 41 310 207 105 22 334 The following table summarizes those commodity derivative balances subject to the right of setoff as presented on our consolidated balance sheet. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements when a legal right of offset exists. Millions of Dollars Gross Gross Net Gross Amounts Amounts Amounts Amounts Cash without Net Recognized Offset Presented Collateral Right of Setoff Amounts December 31, 2017 Assets $ 311 186 125 - 4 121 Liabilities 310 186 124 7 5 112 December 31, 2016 Assets $ 312 221 91 - 5 86 Liabilities 334 221 113 12 12 89 At December 31, 2017, and December 31, 2016, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff. Non-Recurring Fair Value Measurement The following table summarizes the fair value hierarchy by major category and date of remeasurement for assets accounted for at fair value on a non-recurring basis: Millions of Dollars Fair Value Measurements Using Fair Value Level 1 Inputs Level 3 Inputs Before-Tax Loss Year ended December 31, 2017 Net PP&E (held for use) December 31, 2017 $ 75 - 75 154 Net PP&E (held for sale) June 30, 2017 2,830 2,830 - 3,882 December 31, 2017 113 113 - 78 Cost and equity method investments June 30, 2017 7,656 - 7,656 2,384 Year ended December 31, 2016 Net PP&E (held for use) March 31, 2016 $ 217 - 217 129 June 30, 2016 23 - 23 53 December 31, 2016 13 - 13 29 Net PP&E (held for sale) September 30, 2016 217 217 - 99 Cost and equity method investments December 31, 2016 90 4 86 40 Net PP&E (held for use) Net PP&E held for use is comprised of various producing properties impaired to their individual fair values less costs to sell. The fair values were determined by internal discounted cash flow models using estimates of future production, prices from futures exchanges and pricing service companies, costs, and a discount rate believed to be consistent with those used by principal market participants. Net PP&E (held for sale) Net PP&E held for sale was written down to fair value, less costs to sell. The fair value of each asset was determined by its negotiated selling price. Equity Method Investments Certain cost and equity method investments were determined to have fair values below their carrying amounts, and the impairments were considered to be other than temporary under the guidance of FASB ASC Topic 323. During 2017, this included our investment in APLNG, which was written down to its fair value of $ 7,656 million, resulting in a before-tax-charge of $ 2,384 million. For additional information on APLNG, see Note 5 —Investments, Loans and Long-Term Receivables . During 2016, an investment using Level 1 inputs was written down to fair value, less costs to sell, determined by its negotiated selling price. Investme nts using Level 3 inputs had fair values determined primarily by internal discounted cash flow models using estimates of future production, prices from futures exchanges and pricing service companies, costs, and a discount factor believed to be consistent with those used by principal market participants. Reported Fair Values of Financial Instruments We used the following methods and assumptions to estimate the fair value of financial instruments: Cash and c ash equivalents and short-term investments : The carrying amount reported on the balance sheet approximates fair value. Accounts and notes receivable (including long-term and related parties): The carrying amount reported on the balance sheet approximates fair value. The valuation technique and methods used to estimate the fair value of the current portion of fixed-rate related party loans is consistent with Loans and advances—related parties. Investment in Cenovus Energy shares: See Note 6 — Investment in Cenovus Energy for a discussion of the carrying value and fair value of our investment in Cenovus Energy shares. Loans and advances—related parties: The carrying amount of floating-rate loans approximates fair value. The fair value of fixed-rate loan activity is measured using market observable data and is categorized as Level 2 in the fair v alue hierarchy. See Note 5 —Investments, Loans and Long-Term Receivables, for additional information. Accounts payable (including related parties) and floating-rate debt: The carrying amount of accounts payable and floating-rate debt reported on the balance sheet approximates fair value. Fixed-rate debt: The estimated fair value of fixed-rate debt is mea sured using prices available from a pricing service that is corroborated by market data; therefore, these liabilities are categorized as Level 2 in the fair value hierarchy. The following table summarizes the net fair value of financial instruments (i.e., adjusted where the right of setoff exists for commodity derivatives): Millions of Dollars Carrying Amount Fair Value 2017 2016 2017 2016 Financial assets Investment in Cenovus Energy $ 1,899 - 1,899 - Commodity derivatives 125 91 125 91 Total loans and advances—related parties 586 701 586 701 Financial liabilities Total debt, excluding capital leases 18,929 26,423 22,435 29,307 Commodity derivatives 117 101 117 101 Commodity D erivatives At December 31, 201 7 , commodity derivative assets and liabilities appear net with no obligations to return cash collateral and $ 7 million of rights to reclaim cash collateral, respectively. At December 31, 201 6 , commodity derivative assets and liabilities appear net with no obligations to re turn cash collateral and $ 1 2 million of rights to reclaim cash collateral , respectively.

Equity

Equity	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Equity	Note 15 —Equity Common Stock The changes in our shares of common stock, as categorized in the equity section of the balance sheet, were: Shares 2017 2016 2015 Issued Beginning of year 1,782,079,107 1,778,226,388 1,773,583,368 Distributed under benefit plans 3,340,068 3,852,719 4,643,020 End of year 1,785,419,175 1,782,079,107 1,778,226,388 Held in Treasury Beginning of year 544,809,771 542,230,673 542,230,673 Repurchase of common stock 63,502,263 2,579,098 - End of year 608,312,034 544,809,771 542,230,673 Preferred Stock We have authorized 500 million shares of preferred stock, par value $ .01 per share, none of which was issued or outstanding at December 31, 2017 or 2016 . Noncontrolling Interests At December 31, 2017 and 2016 , we had $ 194 million and $ 252 million outstanding , respectively, of equity in less-than-wholly owned consolidated subsidiaries held by noncontrolling interest owners . For both periods, the amount s were related to the Darwin LNG and Bayu-Darwin Pipeline operating joint venture s we control. Repurchase of Common Stock On November 10, 2016, we announced plans to purchase up to $ 3 billion of our common stock through 2019. On March 29, 2017, we announced plans to double our share repurchase program to $6 billion of common stock through 2019, with $3 billion allocated and purchased in 2017 , and the remainder allocated evenly to 2018 and 2019. On February 1, 2018, we announced the acceleration of our previously sta ted 2018 share repurchases from $1.5 billion to $2.0 billion , with the remaining balance to be repurchased in 2019 . Repurchase of shares began in November 2016, and totaled 66,081,361 shares at a cost of $ 3,126 million, throug h December 31, 2017 .

Non Mineral Leases

Non Mineral Leases	12 Months Ended
	Dec. 31, 2017
Leases [Abstract]
Non-Mineral Leases	Note 16 —Non-Mineral Leases The company primarily leases drilling equipment and office buildings, as well as ocean transport vessels, tugboats, barges, corporate aircraft, computers and other facilities and equipment. Certain leases include escalation clauses for adjusting rental payments to reflect changes in price indices, as well as renewal options and/or opt ions to purchase the leased property for the fair market value at the end of the lease term. There are no significant restrictions imposed on us by the leasing agreements with regard to dividends, asset dispositions or borrowing ability. For additional i nformation on leased assets under capital leases , see Note 10 —Debt. At December 31, 2017, future minimum rental payments due under noncancelable leases were: Millions of Dollars 2018 $ 278 2019 214 2020 414 2021 126 2022 307 Remaining years 209 Total 1,548 Less: income from subleases (11) Net minimum operating lease payments $ 1,537 Operating lease rental expense for the years ended December 31 was: Millions of Dollars 2017 2016 2015 Total rentals $ 264 537 432 Less: sublease rentals (20) (10) * (9) $ 244 527 423 *Amount updated to reflect additional sublease income in 2016.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2017
Compensation And Retirement Disclosure [Abstract]
Employee Benefit Plans	Note 17 —Employee Benefit Plans Pension and Postretirement Plans An analysis of the projected benefit obligations for our pension plans and accumulated benefit obligations for our postretirement health and life insurance plans follows: Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 3,416 3,445 3,772 3,321 286 352 Service cost 89 77 108 76 2 2 Interest cost 118 103 133 120 9 13 Plan participant contributions - 2 - 3 23 24 Plan amendments - - - - - (27) Actuarial (gain) loss 244 52 247 466 12 (14) Benefits paid (631) (117) (872) (148) (68) (68) Curtailment - - 14 10 - 3 Settlement - - - (46) - - Recognition of termination benefits - - 14 1 - - Foreign currency exchange rate change - 283 - (358) 1 1 Benefit obligation at December 31* $ 3,236 3,845 3,416 3,445 265 286 *Accumulated benefit obligation portion of above at 3,076 3,404 3,246 3,067 December 31: $ Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 2,081 3,068 2,606 3,063 - - Actual return on plan assets 336 313 133 397 - - Company contributions 755 114 214 125 45 44 Plan participant contributions - 2 - 3 23 24 Benefits paid (631) (117) (872) (148) (68) (68) Foreign currency exchange rate change - 267 - (372) - - Fair value of plan assets at December 31 $ 2,541 3,647 2,081 3,068 - - Funded Status $ (695) (198) (1,335) (377) (265) (286) Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 205 - 164 - - Current liabilities (38) (4) (101) (7) (45) (44) Noncurrent liabilities (657) (399) (1,234) (534) (220) (242) Total recognized $ (695) (198) (1,335) (377) (265) (286) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 3.55 % 2.80 3.95 3.00 3.30 3.60 Rate of compensation increase 4.00 3.75 4.00 3.85 - - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.80 % 3.00 3.90 3.95 3.60 3.75 Expected return on plan assets 6.55 5.05 7.00 5.45 - - Rate of compensation increase 4.00 3.85 4.00 4.05 - - For both U.S. and international pensions, the overall expected long-term rate of return is developed from the expected future return of each asset class, weighted by the expected allocation of pension assets to that asset class. We rely on a variety of independent market forecasts in developing the expected rate of return for each class of assets. Included in accumulated other comprehensive income (loss) at December 31 were the following before-tax amounts that had not been recognized in net periodic benefit cost: Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial (gain) loss $ 588 358 748 479 (12) (27) Unrecognized prior service cost (credit) - (16) 4 (20) (249) (285) Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ (40) 71 (263) (232) (12) 14 Amortization of (gain) loss included in income (loss)* 200 50 288 26 (3) (5) Net change during the period $ 160 121 25 (206) (15) 9 Prior service credit (cost) arising during the period $ - 2 - (4) - 27 Amortization of prior service cost (credit) included in income (loss) 4 (6) 5 (6) (36) (34) Net change during the period $ 4 (4) 5 (10) (36) (7) *Includes settlement losses recognized in 2017 and 2016. During the year ended December 31, 2016 , there was an amendment to the U.S. other postretirement benefit plan. The benefit obligation decreased by $ 27 million for changes in the plan made to post-65 retiree medical benefits related to updated cost sharing a ssumption changes for retirees. The $ 27 million decrease in the benefit obligation resulted in a corresponding increase in other comprehensive income . Included in accumulated other comprehensive loss at December 31, 2017, were the following before-tax amounts that are expected to be amortized into net periodic benefit cost during 2018: Millions of Dollars Pension Other Benefits Benefits U.S. Int’l. Unrecognized net actuarial (gain) loss $ 59 36 (1) Unrecognized prior service credit - (5) (34) For our tax-qualified pension plans with projected benefit obligations in excess of plan assets, the projected benefit obligation, the accumulated benefit obligation, and the fair value of plan assets were $ 5,634 million, $ 5,226 million, and $ 5,113 million, respectively, at December 31, 2017 , and $ 5,498 million, $ 5,145 million, and $ 4,208 million, respectively, at December 31, 2016 . For our unfunded nonqualified key employee supplemental pension plans, the projected benefit obligation and the accumulated benefit obligation were $ 578 million and $ 503 million, respectively, at December 31, 2017 , and were $ 586 million and $ 496 million, respectively, at December 31, 2016 . The components of net periodic benefit cost of all defined benefit plans are presented in the following table: Millions of Dollars Pension Benefits Other Benefits 2017 2016 2015 2017 2016 2015 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 89 77 108 76 138 124 2 2 4 Interest cost 118 103 133 120 161 135 9 13 22 Expected return on plan assets (132) (158) (149) (147) (201) (164) - - - Amortization of prior service cost (credit) 4 (6) 5 (6) 6 (7) (36) (34) (17) Recognized net actuarial loss (gain) 69 50 86 26 115 82 (3) (2) 2 Settlements 131 - 202 - 197 7 - - - Curtailment (gain) loss - - 14 - 35 (4) - 1 2 Net periodic benefit cost $ 279 66 399 69 451 173 (28) (20) 13 We recognized pension settlement losses of $ 131 million in 2017 , $ 202 million in 2016 a nd $ 204 million in 2015 a s lump-sum benefit payments from certain U.S. and international pension plans exceeded the sum of service and interest costs for those plans and led to recognition of settlement losses. As part of the 2016 and 2015 restructuring programs, we concluded tha t actions taken during those years resulted in a significant reduction of future services of active employees primarily in the U.S. qualified pension plan and a U.S. nonqualified supplemental retirement plan. As a result, we recognized an increase in the benefit obligation and a proportionate share of prior service cost from other comprehensive income (loss) as curtailment losses of $ 15 million and $ 33 million during the years ended December 31, 2016 and 2015 , respec tively . Also as part of the 2016 and 2015 restructuring programs in the U.S. and Europe, we recognized expense for special termination benefits of $ 15 million during the year ended December 31, 2016 , consisting of $ 14 million in the U.S. and $ 1 million in Europe, and $ 124 million during the year ended December 31, 2015 , consisting of $ 46 million in the U.S. and $ 78 million in Europe. Approximately 62 percent of the 2015 Europe amount was recovered from joint venture partners. In determining net pension and other postretirement benefit costs, we amortize prior service costs on a straight-line basis over the average remaining service period of employees expected to receive benefits under the plan. For net actuarial gains and losses, we amortize 10 percent of the unamortized balance each year. We have multiple nonpension postretirement benefit plans for health and life insurance. The health care plans are contributory and subject to various cost sharing features, with participant and company contributions adjusted annually; the life insurance plans are noncontributory. The measurement of the U.S. pre-65 retiree medical accumulated postretirement benefit obligation assumes a health care cost trend rate of 6.25 percent in 2018 that declines to 5 percent by 2023 . T he measurement of the U.S. post-65 retiree medical accumulated postretirement benefit obligation assumes a n ultimate health care cost trend rate of 5 percent achieved in 2018 . A one-percentage-point change in the assumed health care cost trend rate would be immaterial to ConocoPhillips. Plan Assets — We follow a policy of broadly diversifying pension plan assets across ass et classes and individual holdings. As a result, our plan assets have no significant concentrations of credit risk. Asset classes that are considered appropriate include U.S. equities, non-U.S. equities, U.S. fixed income, non-U.S. fixed income, real estate and private equity investments. Plan fiduciaries may consider and add other asset classes to the investment program from time to time. The target allocations for plan assets are 43 percent equity securities, 50 percent debt securities , 6 percent real estate and 1 percent other . Generally, the plan investments are publicly tra ded, therefore minimizing liquidity risk in the portfolio. The following is a description of the valuation methodologies used for the pension plan assets. There have been no changes in the methodologies used at December 31, 2017 and 2016 . Fair values of equity securities and government debt securities categorized in Level 1 are primarily based on quoted market prices in active markets for identical assets and liabilities. Fair values of corporate debt securities, agency and mortgage-backed secur ities and government debt securities categorized in Level 2 are estimated using recently executed transactions and quoted market prices for similar assets and liabilities in active markets and for identical assets and liabilities in markets that are not ac tive. If there have been no market transactions in a particular fixed income security, its fair value is calculated by pricing models that benchmark the security against other securities with actual market prices. When observable quoted market prices are not available, fair value is based on pricing models that use something other than actual market prices (e.g., observable inputs such as benchmark yields, reported trades and issuer spreads for similar securities), and these securities are categorized in Level 3 of the fair value hierarchy. Fair values of investments in common/collective trusts are determined by the issuer of each fund based on the fair value of the underlying assets. Fair values of mutual funds are based on quoted market prices, which re present the net asset value of shares held. Time deposits are valued at cost, which approximates fair value. Cash is valued at cost, which approximates fair value. Fair values of international cash equivalents categorized in Level 2 are valued using observable yield curves, discounting and interest rates. U.S. cash ba lances held in the form of short-term fund units that are redeemable at the measurement date are categorized as Level 2. Fair values of exchange-traded derivatives classified in Level 1 are based on quoted market prices. For other derivatives classified i n Level 2, the values are generally calculated from pricing models with market input parameters from third-party sources. Fair values of insurance contracts are valued at the present value of the future benefit payments owed by the insurance company to the plans’ participants. Fair values of real estate investments are valued using real estate valuation techniques and other methods that include reference to third-party sources and sales comparables where available. A portion of U.S. pension plan assets is h eld as a participating interest in an insurance annuity contract, which is calculated as the market value of investments held under this contract, less the accumulated benefit obligation covered by the contract. The participating interest is classified as Level 3 in the fair value hierarchy as the fair value is determined via a combination of quoted market prices, recently executed transactions, and an actuarial present value computation for contract obligations. At December 31, 2017 , the participating interest in the annuity contract was valued at $ 99 million and consisted of $ 265 million in debt securities, less $ 166 million for the accumulated benefit obligation covered by the contract. At December 31, 2016 , the participating interest in the annuity contract was valued at $ 121 million and consisted of $ 288 million in debt securities, less $ 167 million for the accumulated benefit obligation covered by the contract. The net change from 2016 to 2017 is due to a decrease in the fair value of the underlying investments of $ 23 million offset by a decrease in the present value of the contract obligation of $ 1 million. The participating interest is not available for meeting general pension benefit obligations in the near term. No future company contributions are required and no new benefits are being accrued under this insurance annuity contract. The fair values of our pension plan assets at December 31, by asset class were as follows: Millions of Dollars U.S. International Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total 2017 Equity securities U.S. $ 161 - 14 175 440 - - 440 International 178 - - 178 315 - - 315 Common/collective trusts - - - - - 183 - 183 Mutual funds 146 - - 146 292 165 - 457 Debt securities Government - - - - 902 - - 902 Corporate - 2 - 2 - - - - Common/collective trusts - - - - - 648 - 648 Mutual funds - - - - 144 - - 144 Cash and cash equivalents - - - - 111 - - 111 Time deposits - - - - 3 - - 3 Derivatives - - - - 5 - - 5 Real estate - - - - - - 123 123 Total in fair value hierarchy $ 485 2 14 501 2,212 996 123 3,331 Investments measured at net asset value* Equity securities Common/collective trusts $ - - - 805 - - - - Debt securities Corporate - - - - - - - 172 Agency and mortgage-backed securities - - - - - - - 15 Common/collective trusts - - - 1,042 - - - - Cash and cash equivalents - - - 17 - - - 24 Real estate - - - 74 - - - 94 Total** $ 485 2 14 2,439 2,212 996 123 3,636 *In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets. **Excludes the participating interest in the insurance annuity contract with a net asset value of $99 million and net receivables related to security transactions of $14 million. The fair values of our pension plan assets at December 31, by asset class were as follows: Millions of Dollars U.S. International Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total 2016 Equity securities U.S. $ 632 - 14 646 628 - - 628 International 342 - - 342 428 - - 428 Common/collective trusts - - - - - 156 - 156 Mutual funds 62 - - 62 268 139 - 407 Debt securities Government - 38 - 38 470 - - 470 Corporate - 54 3 57 - - - - Common/collective trusts - - - - - 385 - 385 Mutual funds - - - - 137 - - 137 Cash and cash equivalents - - - - 48 - - 48 Derivatives - - - - 18 - - 18 Real estate - - - - - - 111 111 Total in fair value hierarchy $ 1,036 92 17 1,145 1,997 680 111 2,788 Investments measured at net asset value* Equity securities Common/collective trusts $ - - - 410 - - - - Debt securities Corporate - - - - - - - 155 Agency and mortgage-backed securities - - - - - - - 27 Common/collective trusts - - - 312 - - - - Cash and cash equivalents - - - 36 - - - 11 Real estate - - - 69 - - - 76 Total** $ 1,036 92 17 1,972 1,997 680 111 3,057 *In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets. **Excludes the participating interest in the insurance annuity contract with a net asset value of $121 million and net payables related to security transactions of $1 million. Level 3 activity was not material for all periods . Our funding policy for U.S. plans is to contribute at least the minimum required by the Employee Retirement Income Security Act of 1974 and the Internal Revenue Code of 1986, as amended. Contributions to foreign plans are dependent upon local laws and tax regulations. In 2018 , we expect to contribute approximately $ 80 million to our domestic nonqualified pension and postretirement benefit plans and $ 130 million to our international qualified and nonqualified pension and postretirement benef it plans. The following benefit payments, which are exclusive of amounts to be paid from the insurance annuity contract and which reflect expected future service, as appropriate, are expected to be paid: Millions of Dollars Pension Other Benefits Benefits U.S. Int’l. 2018 $ 383 122 40 2019 302 141 37 2020 290 135 34 2021 286 144 31 2022 291 144 28 2023–2027 1,247 780 91 Severance Accrual As a result of selling our 50 percent nonoperated interest in the FCCL Partnership and the majority of our western Canada gas assets, as well as our interest in the San Juan Basin , a reduction in our overall employee workforce occurred during 2017 . Severance accruals of $ 65 million were recorded in 2017 . The following table summarizes our severance accrual activity for the year ended December 31, 2017 : Millions of Dollars Balance at December 31, 2016 $ 80 Accruals 65 Benefit payments (93) Foreign currency translation adjustments 1 Balance at December 31, 2017 $ 53 Of the remaining balance at December 31, 2017 , $ 30 million is classified as short-term. Defined Contribution Plans Most U.S. employees are eligible to participate in the ConocoPhillips Savings Plan (CPSP). Employees can deposit up to 75 percent of their eligible pay , subject to statutory limits, in the CPSP to a choice of approximately 34 investment options . E mployees who participate in the CPSP and contribute 1 percent of their eligible pay receive a 6 percent company cash match with a potential compan y discretionary cash contribution of up to 6 percent. Company contributions charged to expense for the CPSP and predecessor plans were $ 51 million in 2017 , $ 58 million in 2016 , and $ 109 mill ion in 2015 . We have several defined contribution plans for our international employees, each with its own terms and eligibility depending on location. Total compensation expense recognized for these international plans was approximately $ 35 million in 2017 , $ 44 million in 2016 , and $ 55 million in 2015 . Share-Based Compensation Plans The 2014 Omnibus Stock and Performance Incentive Plan of ConocoPhillips (the Plan) was appr oved by shareholders in May 2014 . Over its 10 -year life, the Plan allows the issuance of up to 79 million shares of our common stock for compensation to our employ ees and directors; however, as of the effective date of the Plan, (i) any shares of common stock available for future awards under the prior plans and (ii) any shares of common stock represe nted by awards granted under the prior plans that are forfeited, expire or are cancel l ed without delivery of shares of common stock or which result in the forfeiture of shar es of common stock back to the c ompany shall be available for awards under the Plan , and no new awards shall be granted under the prior plans. Of the 79 million shares available for issuance under the Plan, no more than 40 million shares of common stock are available for incentive stock options. The Human Resources and Compensation Committee of our Board of Directors is authorized to determi ne the types, terms, conditions and limitations of awards granted. Awards may be granted in the form of, but not limited to, stock options, restricted stock unit s and performance share units to employees and non - employee d irectors who contribute to the c ompany’s continued success and profitability. Total share-based compensation expense is measured using the grant date fair value for our equity-classified awards an d the settlement date fair value for our liability-classified awards. We recognize share-based compensation expense over the shorter of the service period (i.e., the stated period of time required to earn the award); or the period beginning at the start o f the service period and ending when an employee first becomes eligible for retirement, but not less than six months, as this is the minimum period of time required for an award to not be subject to forfeiture. Our share-based compensation programs genera lly provide accelerated vesting (i.e., a waiver of the remaining period of service required to earn an award) for awards held by employees at the time of their retirement. Some of our share-based awards vest ratably (i.e., portions of the award vest at di fferent times) while some of our awards cliff vest (i.e., all of the award vests at the same time). We recognize expense on a straight-line basis over the service period for the entire award, whether the award was granted with ratable or cliff vesting. Compensation Expense — Total share-based compensation expense recognized in loss and the associated tax benefit for the years ended December 31 were as follows: Millions of Dollars 2017 2016 2015 Compensation cost $ 227 272 362 Tax benefit 76 92 123 Stock Options —Stock options granted under the provisions of the Plan and prior plans permit purchase of our common stock at exercise prices equivalent to the average market price of ConocoPhillips common stock on the date the options were granted. The options have terms of 10 years and generally vest ratably, with one-third of the options awarded vesting and becoming exercisable on each anniversary date following the date of grant. Options awarded to certain employees already eligible for retirement vest within six months of the grant date, but those options do not become exercisable until the end of the normal vesting period. The fair market values of the options granted over the past three years were measured on the date of grant using the Black-Scholes-Merton option-pricing model. The weighted-average assumptions used were as follows: 2017 2016 2015 Assumptions used Risk-free interest rate 2.24 % 1.55 1.79 Dividend yield 4.00 % 4.00 4.00 Volatility factor 28.12 % 26.80 23.32 Expected life (years) 6.39 6.37 5.79 There were no ranges in the assumptions used to determine the fair market values of our options granted over the past three years. We believe our historical volatility for periods prior to the 2012 separation of our Downstream businesses is no longer relevant in estimating expected volatility. For 2015 through 2017, expected volatility was based on the weighted- average blend of the company’s historical stock price volatility from May 1, 2012 (the d ate of separation of our Downstream businesses) through the stock option grant date and the average historical stock price volatility of a group of peer companies for the expected term of the options. The following summarizes our stock option activity for the year ended December 31, 2017: Weighted- Weighted- Average Millions of Dollars Average Grant Date Aggregate Options Exercise Price Fair Value Intrinsic Value Outstanding at December 31, 2016 23,712,112 $ 52.14 $ 128 Granted 2,670,200 49.76 $ 9.18 Exercised (360,396) 37.24 4 Forfeited (50,696) 48.55 Expired or cancelled (1,248,417) 50.61 Outstanding at December 31, 2017 24,722,803 $ 52.18 $ 177 Vested at December 31, 2017 23,424,010 $ 52.52 $ 162 Exercisable at December 31, 2017 18,074,088 $ 54.34 $ 101 The weighted-average remaining contractual term of outstanding options, vested options and exercisable options at December 31, 2017 , was 5.52 years , 5.36 years and 4.50 years, respectively . The weighted-average grant date fair value of stock option awards granted during 2016 and 2015 was $ 5.39 and $ 9.54 , respectively. The aggregate intrinsic value of options exercised was zero in 2016 and $ 10 million in 2015 . During 2017 , we received $ 13 million in cash and realized a tax benefit of $ 12 million from the exercise of options. At December 31, 2017 , the remaini ng unrecognized compensation expense from unvested options was $ 5 million, which will be recognized over a weighted-average period of 1.33 years , the longest period being 2.12 years. B eginning in 2018, stock option grants will be discontinued and replaced with three-year, time-vested restricted stock units which will be cash-settled. Stock Unit Program— Generally, restricted stock units are granted annually under the provisions of the Plan . Restricted stock units granted prior to 2013 generally vest ratably in three equal annual installments beginning on the third anniversary of the grant date . Beginning in 2013 , restricted stock units granted will vest in an aggregate installment on the third anniversary of the grant date. In addition , beginning in 2012, restricted stock units granted under the Plan for a variab le long-term incentive program vest ratably in three equal annual installments beginning on the first anniversary of the grant date. R estricted stock units are also granted ad hoc to attract or retain key personnel, and the terms and conditions under whic h these restricted stock units vest vary by award. Upon vesting, the restricted stock units are settled by issuing one share of ConocoPhillips common stock per unit. Units awarded to retirement eligible employees vest six months from the grant date ; howe ver, those units are not issued as common stock until the earlier of separation from the company or the end of the regularly scheduled vesting period. Until issued as stock, most recipients of the restricted stock units receive a quarterly cash payment of a dividend equivalent that is charged to retained earnings. The grant date fair market value of these restricted stock units is deemed equal to the average ConocoPhillips stock price on the grant date . The grant date fair market value of units that do n ot receive a dividend equivalent while unvested is deemed equal to the average ConocoPhillips stock price on the grant date, less the net present value of the dividends that will not be received. The following summarizes our stock unit activity for the year ended December 31, 2017: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2016 8,507,504 $ 48.65 Granted 3,011,903 48.77 Forfeited (372,871) 45.99 Issued (3,319,684) $ 159 Outstanding at December 31, 2017 7,826,852 $ 45.75 Not Vested at December 31, 2017 5,396,027 $ 45.58 At December 31, 2017 , the remaining unrecognized compensation cost from the unvested units was $ 93 million, which will be recognized over a weighted-average period of 1.67 years , the longest period being 2.75 years . The weighted - average grant date fair value of stock unit awards granted during 2016 and 2015 was $ 32.15 and $ 65.40 , respectively. The total fair value of stock units issued during 2016 and 2015 was $ 191 million and $ 316 million , respectively. Performance Share Program — Under the Plan, we also annually grant restricted performance share units (PSUs) to senior management. These PSUs are authorized three years prior to their effective grant date (the performance period). Compensation expense is initially measured using the average fair market value of ConocoPhillips common stock and is subsequently adjusted, based on changes in the ConocoPhillips stock price through the end of each subsequent reporting period, through the grant date for stock-settled awards and the settlement date for cash-settled awards. Stock-Settled For performance periods beginning before 2009, PSUs do not vest until the employee becomes eligible for retirement by reaching age 55 with five years of se rvice, and restrictions do not lapse until the employee separates from the company. With respect to awards for performance periods beginning in 2009 through 2012, PSUs do not vest until the earlier of the date the employee becomes eligible for retirement by reaching age 55 with five years of service or five years after the grant date of the award, and restrictions do not lapse until the earlier of the employee’s separation from the company or five years after the grant date (although recipients can elect t o defer the lapsing of restrictions until separation). We recognize compensation expense for these awards beginning on the grant date and ending on the date the PSUs are scheduled to vest. Since these awards are authorized three years prior to the grant date, for employees eligible for retirement by or shortly after the grant date, we recognize compensation expense over the period beginning on the date of authorization and ending on the date of grant. Until issued as stock, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to retained earnings. Beginning in 2013, PSUs authorized for future grants will vest, absent employee election to defer, upon settlement following the conclusion of the three-year performa nce period. We recognize compensation expense over the period beginning on the date of authorization and ending on the conclusion of the performance period. PSUs are settled by issuing one share of ConocoPhillips common stock per unit. The following summarizes our stock-settled Performance Share Program activity for the year ended December 31, 2017: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2016 3,889,524 $ 51.93 Granted 30,953 49.76 Issued (1,167,012) $ 57 Outstanding at December 31, 2017 2,753,465 $ 50.79 Not Vested at December 31, 2017 67,083 $ 48.17 At December 31, 2017 , the remaining unrecognized compensation cost from unvested stock-settled performance share awards was $ 1 million, which will be recognized over a weighted-average period of 2.00 years, the longest period being 3.00 years. The weighted-average grant date fair value of stock-settled PSUs granted during 2016 and 2015 was $ 33.13 and $ 69.25 , respectively. The total fair v alue of stock-settled PSUs issued during 2016 and 2015 was $ 17 million and $ 25 million, respectively . Cash-Settled In connection with and immediately following the separation of our Downstream businesses in 2012, grants of new PSUs, subject to a shortened performance period, were authorized. Once granted, these PSUs vest, absent employee election to defer, on the earlier of five years after the grant date of the award or the date the employee becomes eligible for retirement. For employees eligible for retirement by or shortly after the grant date, we recognize compensation expense over the period beginning on the date of authorization and ending on the date of grant. Otherwise, we recognize compensation expense b eginning on the grant date and ending on the date the PSUs are scheduled to vest. These PSUs are settled in cash equal to the fair market value of a share of ConocoPhillips common stock per unit on the settlement date and thus are classified as liabilitie s on the balance sheet. Until settlement occurs, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to compensation expense. Beginning in 2013, PSUs authorized for future grants will vest upon settlement fol lowing the conclusion of the three-year performance period. We recognize compensation expense over the period beginning on the date of authorization and ending at the conclusion of the performance period. These PSUs will be settled in cash equal to the f air market value of a share of ConocoPhillips common stock per unit on the settlement date and are classified as liabilities on the balance sheet. During the performance period, recipients of the PSUs do not receive a quarterly cash payment of a dividend equivalent, but after the performance period ends, until settlement in cash occurs, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to compensation expense. The following summarizes our cash-settled Performance Share Program activity for the year ended December 31, 2017: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2016 1,274,762 $ 50.39 Granted 456,909 49.76 Settled (517,138) $ 24 Outstanding at December 31, 2017 1,214,533 $ 55.19 Not Vested at December 31, 2017 122,228 $ 55.19 At December 31, 2017 , the remaini

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2017
Income Taxes [Abstract]
Income Taxes	Note 18 —Income Taxes Income tax benefits included in net loss were: Millions of Dollars 2017 2016 2015 Income Taxes Federal Current $ 79 (9) (718) Deferred (3,046) (1,634) (1,443) Foreign Current 1,729 393 745 Deferred (510) (519) (1,315) State and local Current 51 (135) 8 Deferred (125) (67) (145) $ (1,822) (1,971) (2,868) Deferred income taxes reflect the net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for tax purposes. Major components of deferred tax liabilities and assets at December 31 were: Millions of Dollars 2017 2016 Deferred Tax Liabilities PP&E and intangibles $ 9,692 15,099 Investments in joint ventures - 933 Inventory 61 36 Deferred state income tax 178 203 Other 464 486 Total deferred tax liabilities 10,395 16,757 Deferred Tax Assets Benefit plan accruals 786 1,280 Asset retirement obligations and accrued environmental costs 3,060 3,514 Investments in joint ventures 57 - Other financial accruals and deferrals 166 317 Loss and credit carryforwards 2,310 3,522 Other 152 250 Total deferred tax assets 6,531 8,883 Less: valuation allowance (1,254) (675) Net deferred tax assets 5,277 8,208 Net deferred tax liabilities $ 5,118 8,549 A t December 31, 2017 , noncurrent assets and liabilities included deferred taxes of $ 164 million and $ 5,282 million , respectively . At December 31, 2016 , noncurrent assets and liabilities included deferred taxes of $ 400 million and $ 8,949 million , respectively . At December 31, 2017, the components of our loss and credit carryforwards before and after consideration of the applicable valuation allowances are: Millions of Dollars Net Deferred Expiration of Gross Deferred Tax Asset After Net Deferred Tax Asset Valuation Allowance Tax Asset U.S. foreign tax credits $ 856 567 2025-2027 U.S. general business credits 227 227 2036-2037 State net operating losses and tax credits 420 - Foreign net operating losses and tax credits 807 786 Post 2025 $ 2,310 1,580 Valuation allowances have been established to reduce deferred tax assets to an amount that will, more likely than not, be realized. During 2017 , valuation allowances increased a total of $ 579 million. This increase primarily relates to the expected realization of certain deferred tax assets, including foreign tax credits; U.S. tax basis associated with foreign assets; and state net operating losses and tax credits not expected to be realized. Based on our historica l taxable income, expectations for the future, and available tax-planning strategies, management expects deferred tax assets, net of valuation allowance, will primarily be realized as offsets to reversing deferred tax liabilities. At December 31, 2017, unremitted income considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures totaled approximately $ 2,600 million. Deferred income taxes have not been provided on this amount, as we do not plan to initiate any action that would require the payment of income taxes. The estimated amount of additional tax that would be payable on this income if distributed is approximately $ 130 million . The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2017, 2016 and 2015: Millions of Dollars 2017 2016 2015 Balance at January 1 $ 381 459 442 Additions based on tax positions related to the current year 612 32 54 Additions for tax positions of prior years 109 19 4 Reductions for tax positions of prior years (129) (118) (37) Settlements (5) (9) (4) Lapse of statute (86) (2) - Balance at December 31 $ 882 381 459 Included in the balance of unrecognized tax benefits for 2017 , 2016 and 2015 were $ 882 million, $ 359 million and $ 354 million, respectively, which, if recognized, would impact our effective tax rate. The balance of unrecognized tax benefits increased in 2017 mainly due to the recognition of a U.S. worthless securities deduction that we do not believe will generate a cash tax benefit. At December 31, 2017 , 2016 and 2015 , accrued liabilities for interest and penalties totaled $ 54 million, $ 54 million and $ 79 million, respectively, net of accrued income taxes. Interest and penalties result ed in no impact to earnings in 2017 , a ben efit to earnings of $ 18 million in 2016 , and a reduction to earnings of $ 11 million in 2015 . We and our subsidiaries file tax returns in the U.S. federal jurisdiction and in many foreign and state jurisdictions. Aud its in major jurisdictions are generally complete as follows: United Kingdom (201 4 ), Canada (2009), United States (2010) and Norway (201 6 ) . Issues in dispute for audited years and audits for subsequent years are ongoing and in various stages of completion in the many jurisdictions in which we operate around the world. As a consequence, the balance in unrecognized tax benefits can be expected to flu ctuate from period to period. It is reasonably possible such changes could be significant when compared with our total unrecognized tax benefits, but the amount of change is not estimable. The amounts of U.S. and foreign income (loss) before income taxes, with a reconciliation of tax at the federal statutory rate with the provision for income taxes, were: Millions of Dollars Percent of Pre-Tax Income (Loss) 2017 2016 2015 2017 2016 2015 Loss before income taxes United States $ (5,250) (4,410) (4,150) 200.8 % 79.7 57.3 Foreign 2,635 (1,120) (3,089) (100.8) 20.3 42.7 $ (2,615) (5,530) (7,239) 100.0 % 100.0 100.0 Federal statutory income tax $ (915) (1,936) (2,534) 35.0 % 35.0 35.0 Non-U.S. effective tax rates 625 361 301 (23.9) (6.5) (4.2) Impact of U.S. tax legislation (852) - - 32.6 - - Canada disposition (1,277) - - 48.8 - - Recovery of outside basis (962) (60) (491) 36.8 1.1 6.8 Adjustment to tax reserves 881 55 42 (33.7) (1.0) (0.6) APLNG impairment 834 - 525 (31.9) - (7.3) State income tax (84) (122) (85) 3.2 2.2 1.2 Enhanced oil recovery credit (68) (62) - 2.6 1.1 - U.K. rate change - (161) (555) - 2.9 7.7 Canada rate change - - 129 - - (1.8) U.S. fair value election - - (185) - - 2.6 Other (4) (46) (15) 0.2 0.8 0.2 $ (1,822) (1,971) (2,868) 69.7 % 35.6 39.6 The increase in the effective tax rate for 2017 was primarily due to the impact of the Tax Cuts and Jobs Act (Tax Legislation) and the impact of the Canada disposition, partially offset by the impact of the APLNG impairment and our mix of income among taxing jurisdictions. The Tax Legislation, enacted on December 22, 2017 , reduces the U . S . federal corporate tax rate from 35 percent to 21 percent , requires companies to pay a one-time transition tax on earnings of certain fo reign subsidiaries that were previously tax deferred and creates new taxes on certain foreign-sourced earnings. At December 31, 2017, we have not completed our accounting for the tax effects of enactment of the Tax Legislation ; however, as described below , we have made a reasonable estimate of the effects on our existing deferred tax balances and the one-time transition tax and recorded a provisional tax benefit of $ 852 million . Provisional Amount — Deferred tax assets and liabilities In the fourth quarter of 2017, w e remeasured certain U.S. deferred tax assets and liabilities based on the rates at which they are expected to reverse in the future, which is generally 21 percent . However, we are still analyzing certain aspects of the Tax Legislation and refi ning our calculations, which could potentially affect the measurement of these balances or potentially give rise to new deferred tax amounts. The provisional amount recorded related to the remeasurement of our U.S. deferred tax balance was a tax benefit of $ 908 million. Provisional Amount—Foreign tax effects The one-time transition tax is based on our total post- 1986 earnings and profits which we have previously deferred from U . S . income taxes. We reasonably estimate that we will not incur a one-time t ransition tax. This a ssumption may change when we finalize the ca lculation of post-1986 foreign earnings and profits, previously deferred from U . S . federal taxation , and finalize the amounts held in cash or other specified assets. As a result of the Tax Legislation , we have removed the indefinite reinvestment assertion on one of our foreign subsidiaries and recorded a tax expense of $ 56 million in the fourth quarter of 2017 . Our effective tax rate in 2017 was favorably impacted by a tax benefit of $ 1,27 7 million related to the Canada disposition. This tax benefit was primarily associated with a deferred tax recovery related to the Canadian capital gains exclusion component of the 2017 Canada disposition and the recognition of previously unrealizable Can adian capital asset tax basis. The Canada disposition, along with the associated restructuring of our Canadian operations, may generate an additional tax benefit of $ 822 million . However, since we believe it is not likely we will receive a corresponding cash tax savings, th is $ 822 million benefit has been offset by a full tax reserve . See Note 4 —Assets Held for Sale, Sold or Acquired for additional information on our Canada disposition. The impairment of our APLNG investment in the second quarter of 2017 did not generate a tax benefit. See the “APLNG” section of Note 5 —Investments, Loans and Long-Term Receivables, for information on the impairment of our APLNG investment. The decrease in the effective tax rate for 2016 was primarily due to our mix of income among taxing jurisdictions, reduced net tax benefit from the tax law changes discussed below, and the absence of a tax benefit associated with electing the fair market value method of apportioning interest expense fo r prior years. In the United Kingdom, legislation was enacted on September 15, 2016, to decrease the overall U.K. upstream corporatio n tax rate from 50 percent to 40 percent effective Janu ary 1, 2016. As a result, we recorded a $ 161 million net tax benefit related to the remeasurement of our U.K. deferred tax balance in 2016 . In the United Kingdom, legislation was enacted on March 26, 2015, to decrease the overall U.K. upstream corporation tax rate from 62 percent to 50 percent effective January 1, 2015. As a result, we recorded a $ 555 million net tax benefit related to the remeasurement of our U.K. deferred tax balance in 2015. In Canada, legislation was enacted on June 29, 2015 , to increase the overall Canadian corporation tax rate from 25 percent to 27 percent effective July 1, 2015 . As a result, we recorded a $ 129 million net tax expense related to the remeasurement of our Canadian de ferred tax balance in 2015. In December 2015, we filed refund claims for prior years electing the fair market value method of apportioning interest in the United States. As a result, we recorded a $ 185 million tax benefit associated with thes e refund claims in 2015. Certain operating losses in jurisdictions outside of the U.S. only yield a tax benefit in the U.S. as a worthless security deduction. For 2017 , 2016 and 2015 the amount of the tax benefit was $ 962 million, $ 60 million and $ 491 million, respectively.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2017
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Income	Note 19 —Accumulated Other Comprehensive Loss Accumulated other comprehensive loss in the equity section of the balance sheet included: Millions of Dollars Defined Benefit Plans Net Unrealized Loss on Securities Foreign Currency Translation Accumulated Other Comprehensive Loss December 31, 2014 $ (1,261) - (641) (1,902) Other comprehensive income (loss) 818 - (5,163) (4,345) December 31, 2015 (443) - (5,804) (6,247) Other comprehensive income (loss) (104) - 158 54 December 31, 2016 (547) - (5,646) (6,193) Other comprehensive income (loss) 147 (58) 586 675 December 31, 2017 $ (400) (58) (5,060) (5,518) There were no items within accumulated other comprehensive loss related to noncontrolling interests. The following table summarizes reclassifications out of accumulated other comprehensive loss during the years ended December 31: Millions of Dollars 2017 2016 Defined Benefit Plans $ 135 179 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 74 95 See Note 17—Employee Benefit Plans, for additional information.

Cash Flow Information

Cash Flow Information	12 Months Ended
	Dec. 31, 2017
Cash Flow Information [Abstract]
Cash Flow Information	Note 20 —Cash Flow Information Millions of Dollars 2017 2016 2015 Noncash Investing Activities Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations $ (37) (1,017) 402 Cash Payments (Receipts) Interest $ 1,163 1,151 920 Income taxes 1,168 (318) * 523 * Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ (6,617) (1,753) - Short-term investments sold 4,827 1,702 - $ (1,790) (51) - *Net of $585 million and $642 million in 2016 and 2015, respectively, related to refunds received from the Internal Revenue Service.

Other Financial Information

Other Financial Information	12 Months Ended
	Dec. 31, 2017
Other Financial Information [Abstract]
Other Financial Information	Note 21 —Other Financial Information Millions of Dollars 2017 2016 2015 Interest and Debt Expense Incurred Debt $ 1,114 1,279 1,130 Other 103 123 84 1,217 1,402 1,214 Capitalized (119) (157) (294) Expensed $ 1,098 1,245 920 Other Income Interest income $ 112 57 45 Other, net 417 198 80 $ 529 255 125 Research and Development Expenditures —expensed $ 100 116 222 Shipping and Handling Costs* $ 1,058 1,139 1,181 *Amounts included in production and operating expenses. Foreign Currency Transaction (Gains) Losses —after-tax Alaska $ - - - Lower 48 - - - Canada 3 1 - Europe and North Africa 7 (7) (22) Asia Pacific and Middle East 23 (9) (78) Other International 1 7 (9) Corporate and Other (3) (18) 45 $ 31 (26) (64) Millions of Dollars 2017 2016 Properties, Plants and Equipment Proved properties $ 102,044 119,970 Unproved properties 4,491 5,150 Other 3,896 6,286 Gross properties, plants and equipment 110,431 131,406 Less: Accumulated depreciation, depletion and amortization (64,748) (73,075) Net properties, plants and equipment $ 45,683 58,331

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2017
Related Party Transactions [Abstract]
Related Party Transactions	Note 22 —Related Party Transactions Our related parties primarily include equity method investments and certain trusts for the benefit of employees. Significant transactions with our equity affiliates were: Millions of Dollars 2017 2016 2015 Operating revenues and other income $ 107 133 118 Purchases 99 101 97 Operating expenses and selling, general and administrative expenses 59 63 62 Net interest (income) expense* (13) (12) (9) *We paid interest to, or received interest from, various affiliates. See Note 5 —Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies. The table above includes transactions with the FCCL Partnership through the date of the sale. See Note 5 —Investments, Loans and Long-Term Receivables, for additional information.

Segment Disclosures and Related

Segment Disclosures and Related Information	12 Months Ended
	Dec. 31, 2017
Segment Disclosures and Related Information [Abstract]
Segment Disclosures and Related Information	Note 23 —Segment Disclosures and Related Information We explore for, produce, transport and market crude oil, bitumen, natural gas, LNG and natural gas liquids on a worldwide basis. We manage our operations through six operating segments, which are primarily defined by geographic region: Alaska, Lower 48, Canada, Europe and North Africa , Asia Pacific and Middle East, and Other International. Corporate and Other represents costs not directly associated with an operating segment, suc h as most intere st expense, premiums on early retirement of debt, corporate overhead and certain technology activities, including licensing revenues. Corporate assets include all cash and cash equivalents and short-term investments . We evaluate performance and allocate resources based on net income (loss) attributab le to ConocoPhillips. Segment accounting policies are the same as those in Note 1 —Accounting Policies. Intersegment sales are at prices that approximate market. Analysis of Results by Operating Segment Millions of Dollars 2017 2016 2015 Sales and Other Operating Revenues Alaska $ 4,224 3,681 4,351 Lower 48 12,968 10,719 11,976 Intersegment eliminations (4) (17) (63) Lower 48 12,964 10,702 11,913 Canada 3,178 2,192 2,454 Intersegment eliminations (559) (218) (318) Canada 2,619 1,974 2,136 Europe and North Africa 5,181 3,462 6,110 Intersegment eliminations - - (4) Europe and North Africa 5,181 3,462 6,106 Asia Pacific and Middle East 4,014 3,705 4,746 Intersegment eliminations - - (1) Asia Pacific and Middle East 4,014 3,705 4,745 Other International - - 1 Corporate and Other 104 169 312 Consolidated sales and other operating revenues $ 29,106 23,693 29,564 Depreciation, Depletion, Amortization and Impairments Alaska $ 1,026 868 690 Lower 48 6,693 4,358 4,227 Canada 461 975 788 Europe and North Africa 1,313 1,253 2,565 Asia Pacific and Middle East 3,819 1,606 2,981 Other International - 1 - Corporate and Other 134 140 107 Consolidated depreciation, depletion, amortization and impairments $ 13,446 9,201 11,358 In 2017, sales by our Lower 48, Alaska and Canada segments to a certain refining company accounted for approximately $3 billion or 11 percent of our total consolidated sales and other operating revenues. Millions of Dollars 2017 2016 2015 Equity in Earnings of Affiliates Alaska $ 7 9 4 Lower 48 5 (6) (5) Canada 197 89 78 Europe and North Africa 10 22 23 Asia Pacific and Middle East 553 (51) 550 Other International - - 8 Corporate and Other - (11) (3) Consolidated equity in earnings of affiliates $ 772 52 655 Income Taxes Alaska $ (689) (59) (71) Lower 48 (2,453) (1,328) (1,119) Canada (616) (383) (223) Europe and North Africa 1,165 (46) (854) Asia Pacific and Middle East 351 306 467 Other International 21 (40) (456) Corporate and Other 399 (421) (612) Consolidated income taxes $ (1,822) (1,971) (2,868) Net Income (Loss) Attributable to ConocoPhillips Alaska $ 1,466 319 4 Lower 48 (2,371) (2,257) (1,932) Canada 2,564 (935) (1,044) Europe and North Africa 553 394 409 Asia Pacific and Middle East (1,098) 209 (463) Other International 167 (16) (593) Corporate and Other (2,136) (1,329) (809) Consolidated net loss attributable to ConocoPhillips $ (855) (3,615) (4,428) Investments In and Advances To Affiliates Alaska $ 56 58 61 Lower 48 402 426 455 Canada - 8,784 8,165 Europe and North Africa 55 62 70 Asia Pacific and Middle East 9,077 11,611 11,780 Other International - - - Corporate and Other - 4 15 Consolidated investments in and advances to affiliates $ 9,590 20,945 20,546 Millions of Dollars 2017 2016 2015 Total Assets Alaska $ 12,108 12,314 12,555 Lower 48 14,632 22,673 26,932 Canada 6,214 17,548 17,221 Europe and North Africa 11,870 11,727 13,703 Asia Pacific and Middle East 16,985 20,451 22,318 Other International 97 97 282 Corporate and Other 11,456 4,962 4,473 Consolidated total assets $ 73,362 89,772 97,484 Capital Expenditures and Investments Alaska $ 815 883 1,352 Lower 48 2,136 1,262 3,765 Canada 202 698 1,255 Europe and North Africa 872 1,020 1,573 Asia Pacific and Middle East 482 838 1,812 Other International 21 104 173 Corporate and Other 63 64 120 Consolidated capital expenditures and investments $ 4,591 4,869 10,050 Interest Income and Expense Interest income Corporate $ 101 47 36 Lower 48 - - - Europe and North Africa 2 2 2 Asia Pacific and Middle East 9 8 6 Other International - - 1 Interest and debt expense Corporate $ 1,098 1,245 920 Sales and Other Operating Revenues by Product Crude oil $ 13,260 10,801 12,830 Natural gas 10,773 9,401 11,888 Natural gas liquids 1,102 837 952 Other* 3,971 2,654 3,894 Consolidated sales and other operating revenues by product $ 29,106 23,693 29,564 *Includes LNG and bitumen. Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2017 2016 2015 2017 2016 2015 United States $ 17,204 14,400 16,284 23,623 32,949 37,445 Australia (3) 1,448 1,353 2,127 9,657 12,259 12,788 Canada 2,619 1,974 2,136 5,613 16,846 16,766 China 712 551 782 1,275 1,372 1,647 Indonesia 757 938 1,165 758 856 1,191 Malaysia 1,103 735 598 2,736 3,323 3,599 Norway 2,348 1,645 2,107 6,154 6,228 6,933 United Kingdom 2,248 1,816 4,005 3,335 3,209 4,154 Other foreign countries 667 281 360 2,122 2,234 2,469 Worldwide consolidated $ 29,106 23,693 29,564 55,273 79,276 86,992 (1)Sales and other operating revenues are attributable to countries based on the location of the selling operation. (2)Defined as net PP&E plus investments in and advances to affiliated companies. (3)Includes amounts related to the joint petroleum development area with shared ownership held by Australia and Timor-Leste.

New Accounting Standards

New Accounting Standards	12 Months Ended
	Dec. 31, 2017
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Standards [Text Block]	Note 24 —New Accounting Standards In May 2014, the FASB issued Accounting Standards Update (ASU) No. 2014-09, “Revenue from Contracts with Customers” (ASU No. 2014-09), which outlines a single comprehensive model for entities to use in accounting for revenue arising from contracts with customers. This ASU supersedes the revenue recognition requirements in FASB ASC Topic 605, “Revenue Recognition,” and most industry-specific guidance. This ASU sets forth a five-step model for determining when and how revenue is recognized. Under the model, an entity will be required to recognize revenue to depict the transfer of goods or services to a customer at an amount reflecting the consideration it expects to receive in exchange for those goods or services. Add itional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. In August 2015, the FASB issued ASU No. 2015-14, “Deferral of the Effective Date,” which defers the ef fective date of ASU No. 2014-09. The ASU is now effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted for interim and annual periods beginning after December 15, 2016. Entities may choose to adopt the st andard using either a full retrospective approach or a modified retrospective approach. ASU No. 2014-09 was amended in March 2016 by the provisions of ASU No. 2016-08, “Principal versus Agent Considerations (Reporting Revenue Gross versus Net),” in Apr il 2016 by the provisions of ASU No. 2016-10, “Identifying Performance Obligations and Licensing,” in May 2016 by the provisions of ASU No. 2016-12, “Narrow-Scope Improvements and Practical Expedients,” and in December 2016 by the provisions of ASU No. 201 6-20, “Technical Corrections and Improvements to Topic 606, Revenue From Contracts With Customers.” We will adopt the provisions of ASU No. 2014-09, as amended, with effect from January 1, 2018, and have elected not to early adopt the standard. We will adopt the new standard using the modified retrospective approach which we will apply only to contracts within the scope of the standard that are not complete at the date of initial application. Under this approach, we will apply the guidance retrospective ly only to the most current period presented in the financial statements. The impact to our financial statements is immaterial but will include a cumulative effect reduction of $ 220 million to retained earnings from initially applying the new revenue stan dard relating to licensing revenues previously recognized. Under the new revenue standard licensing revenue will be recognized when the customer can utilize and benefit from their right to use the license. In January 2016, the FASB issued ASU No. 2016-01 , “Recognition and Measurement of Financial Assets and Financial Liabilities” (ASU No. 2016-01), to meet its objective of providing more decision-useful information about financial instruments. The ASU, among other things, requires entities to record the changes in fair value of equity investments, other than investments accounted for using the equity method, within net income. Under this ASU, entities will no longer be able to recognize unrealized holding gains and losses on available-for-sale securities in other comprehensive income. The ASU also requires additional disclosures relating to fair value measurement categories for financial assets and liabilities and eliminates certain disclosure requirements related to financial instruments measured at amo rtized cost. ASU No. 2016-01 is effective for interim and annual periods beginning after December 15, 2017, and the ASU should be adopted using a cumulative-effect adjustment to retained earnings as of the date of adoption. Upon adoption of the standard , we will make a cumulative-effect adjustment to reclassify the accumulated unrealized holding gains and losses of $ 58 million related to our investment in Cenovus Energy from other comprehensive income to retained earnings. From January 1, 2018, we will begin reporting the changes in the fair value of our investment within net income. For additional information on our investment in Cenovus Energy, see Note 6 — Investment in Cenovus Energy, Note 14 — Fair Value Measurement, and Note 19 — Accumulated Other Comprehensive Loss. In February 2016, the FASB issued ASU No. 2016-02, “Leases” (ASU No. 2016-02), which establishes comprehensive accounting and financial reporting requirements for leasing arrangements. This ASU supersedes the exist ing requirements in FASB ASC Topic 840, “Leases,” and requires lessees to recognize substantially all lease assets and lease liabilities on the balance sheet. The provisions of ASU No. 2016-02 also modify the definition of a lease and outline requirements for recognition, measurement, presentation and disclosure of leasing arrangements by both lessees and lessors. The ASU is effective for interim and annual periods beginning after December 15, 2018, and early adoption of the standard is permitted. Entiti es are required to adopt the ASU using a modified retrospective approach, subject to certain optional practical expedients, and apply the provisions of ASU No. 2016-02 to leasing arrangements existing at or entered into after the earliest comparative perio d presented in the financial statements. In January 2018, ASU No. 2016-02 was amended by the provisions of ASU No. 2018-01, “Land Easement Practical Expedient for Transition to Topic 842.” We plan to adopt ASU No. 2016-02, as amended, effective January 1 , 2019, and continue to evaluate the ASU to determine the impact of adoption on our consolidated financial statements and disclosures, accounting policies and systems, business processes, and internal controls . We also continue to monitor proposals issued by the FASB to clarify the ASU and certain industry implementation issues. While our evaluation of ASU No. 2016-02 and related implementation activities are ongoing, we expect the adoption of the ASU to have a material impact on our consolidated financia l statements and disclosures. In June 2016, the FASB issued ASU No. 2016-13, “Measurement of Credit Losses on Financial Instruments” (ASU No. 2016-13), which sets forth the current expected credit loss model, a new forward-looking impairment model for c ertain financial instruments based on expected losses rather than incurred losses. The ASU is effective for interim and annual periods beginning after December 15, 2019, and early adoption of the standard is permitted. Entities are required to adopt ASU No. 2016-13 using a modified retrospective approach, subject to certain limited exceptions. We are currently evaluating the impact of the adoption of this ASU .

Supplementary Information - Con

Supplementary Information - Condensed Consolidating Financial Information	12 Months Ended
	Dec. 31, 2017
Supplementary Information - Condensed Consolidating Financial Information [Abstract]
Supplementary Information - Condensed Consolidating Financial Information	Supplementary Information— Condensed Consolidating Financial Information We have various cross guarantees among ConocoPhillips, ConocoPhillips Company and ConocoPhillips Canada Funding Company I, with respect to publicly held debt securities. ConocoPhillips Company is 100 percent owned by ConocoPhillips. ConocoPhillips Canada Funding Company I is an indirect, 100 percent owned subsidiary of ConocoPhillips Company. ConocoPhillips and ConocoPhillips Company have fully and unconditionally guaranteed the payment obligations of ConocoPhillips Canada Funding Company I, with respect to their publicly held debt securities. Similarly, ConocoPhillips has fully and unconditionally guaranteed the payment obligations of ConocoPhillips Company with respect to its publicly held debt securities. In addition, ConocoPhillips Company has fully and unconditionally guaranteed the payment obligations of ConocoPhillips with re spect to its publicly held debt securities. All guarantees are joint and several. The following condensed consolidating financial information presents the results of operations, financial position and cash flows for: ConocoPhillips, ConocoPhillips Compa ny and ConocoPhillips Canada Funding Company I (in each case, reflecting investments in subsidiaries utilizing the equity method of accounting). All other nonguarantor subsidiaries of ConocoPhillips. The consolidating adjustments necessary to present Conoc oPhillips’ results on a consolidated basis. In 20 15, ConocoPhillips received a $ 3.5 billion return of capital from ConocoPhillips Company to settle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial sta tements. In 2016, ConocoPhillips received a $ 2.3 billion return of capital from ConocoPhillips Company to settle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial statements. In 2016, ConocoPhillips Canada Funding Company I repaid $1.25 billion of external debt. This transaction was reflected in the full-year 2016 condensed consolidating financial statements. In 2017, ConocoPhillips Company received a $ 9.8 billion return of capital fr om a nonguarantor subsidiary to settle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial statements. In 2017, ConocoPhillips received a $5.0 billion return of capital from ConocoPhillips Company to set tle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial statements. In 2017, ConocoPhillips received a $3.0 billion distribution from ConocoPhillips Company to settle certain accumulated intercompany bal ances. This consisted of a $2.8 billion return of capital and a $0.2 billion return of earnings. This transaction had no impact on our consolidated financial statements. In 2017, ConocoPhillips Company received a $1.4 billion loan repayment from a non guarantor subsidiary to settle certain accumulated intercompany balances. This transaction had no impact on our consolidated financial statements. This condensed consolidating financial information should be read in conjunction with the accompanying consolidated financial statements and notes. Millions of Dollars Year Ended December 31, 2017 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 12,433 - 16,673 - 29,106 Equity in earnings (losses) of affiliates (454) 2,047 - 630 (1,451) 772 Gain on dispositions - 916 - 1,261 - 2,177 Other income 2 35 - 492 - 529 Intercompany revenues 48 291 170 3,405 (3,914) - Total Revenues and Other Income (404) 15,722 170 22,461 (5,365) 32,584 Costs and Expenses Purchased commodities - 11,145 - 4,580 (3,250) 12,475 Production and operating expenses - 832 - 4,358 (17) 5,173 Selling, general and administrative expenses 9 476 - 82 (6) 561 Exploration expenses - 544 - 394 - 938 Depreciation, depletion and amortization - 855 - 5,990 - 6,845 Impairments - 1,159 - 5,442 - 6,601 Taxes other than income taxes - 140 - 669 - 809 Accretion on discounted liabilities - 32 - 330 - 362 Interest and debt expense 420 664 147 508 (641) 1,098 Foreign currency transaction (gains) losses (43) 11 156 (89) - 35 Other expense 267 35 - - - 302 Total Costs and Expenses 653 15,893 303 22,264 (3,914) 35,199 Income (Loss) before income taxes (1,057) (171) (133) 197 (1,451) (2,615) Income tax provision (benefit) (202) 283 7 (1,910) - (1,822) Net income (loss) (855) (454) (140) 2,107 (1,451) (793) Less: net income attributable to noncontrolling interests - - - (62) - (62) Net Income (Loss) Attributable to ConocoPhillips $ (855) (454) (140) 2,045 (1,451) (855) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (180) 221 23 2,703 (2,947) (180) Income Statement Year Ended December 31, 2016 Revenues and Other Income Sales and other operating revenues $ - 10,352 - 13,341 - 23,693 Equity in earnings (losses) of affiliates (3,351) (1,051) - (91) 4,545 52 Gain on dispositions - 120 - 240 - 360 Other income 1 (11) - 265 - 255 Intercompany revenues 88 277 220 3,036 (3,621) - Total Revenues and Other Income (3,262) 9,687 220 16,791 924 24,360 Costs and Expenses Purchased commodities - 9,144 - 3,562 (2,712) 9,994 Production and operating expenses - 779 - 5,131 (243) 5,667 Selling, general and administrative expenses 8 581 - 140 (6) 723 Exploration expenses - 1,231 - 684 - 1,915 Depreciation, depletion and amortization - 1,178 - 7,884 - 9,062 Impairments - 67 - 72 - 139 Taxes other than income taxes - 162 - 577 - 739 Accretion on discounted liabilities - 46 - 379 - 425 Interest and debt expense 506 622 207 570 (660) 1,245 Foreign currency transaction (gains) losses (19) 2 174 (176) - (19) Total Costs and Expenses 495 13,812 381 18,823 (3,621) 29,890 Loss before income taxes (3,757) (4,125) (161) (2,032) 4,545 (5,530) Income tax benefit (142) (774) (9) (1,046) - (1,971) Net loss (3,615) (3,351) (152) (986) 4,545 (3,559) Less: net income attributable to noncontrolling interests - - - (56) - (56) Net Loss Attributable to ConocoPhillips $ (3,615) (3,351) (152) (1,042) 4,545 (3,615) Comprehensive Loss Attributable to ConocoPhillips $ (3,561) (3,297) (27) (952) 4,276 (3,561) Millions of Dollars Year Ended December 31, 2015 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 11,473 - 18,091 - 29,564 Equity in earnings (losses) of affiliates (4,081) (1,950) - 1,364 5,322 655 Gain on dispositions - 332 - 259 - 591 Other income - 12 - 113 - 125 Intercompany revenues 74 341 246 3,365 (4,026) - Total Revenues and Other Income (4,007) 10,208 246 23,192 1,296 30,935 Costs and Expenses Purchased commodities - 9,905 - 5,838 (3,317) 12,426 Production and operating expenses - 1,469 - 5,585 (38) 7,016 Selling, general and administrative expenses 9 744 1 209 (10) 953 Exploration expenses - 2,093 - 2,099 - 4,192 Depreciation, depletion and amortization - 1,201 - 7,912 - 9,113 Impairments - 15 - 2,230 - 2,245 Taxes other than income taxes - 173 - 728 - 901 Accretion on discounted liabilities - 58 - 425 - 483 Interest and debt expense 485 423 226 447 (661) 920 Foreign currency transaction (gains) losses 114 1 (708) 518 - (75) Total Costs and Expenses 608 16,082 (481) 25,991 (4,026) 38,174 Income (loss) before income taxes (4,615) (5,874) 727 (2,799) 5,322 (7,239) Income tax provision (benefit) (187) (1,793) 21 (909) - (2,868) Net income (loss) (4,428) (4,081) 706 (1,890) 5,322 (4,371) Less: net income attributable to noncontrolling interests - - - (57) - (57) Net Income (Loss) Attributable to ConocoPhillips $ (4,428) (4,081) 706 (1,947) 5,322 (4,428) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (8,773) (8,426) 71 (6,705) 15,060 (8,773) Millions of Dollars At December 31, 2017 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Assets Cash and cash equivalents $ - 234 4 6,087 - 6,325 Short-term investments - - - 1,873 - 1,873 Accounts and notes receivable 24 2,255 35 4,870 (2,864) 4,320 Investment in Cenovus Energy - 1,899 - - - 1,899 Inventories - 163 - 897 - 1,060 Prepaid expenses and other current assets 1 278 6 779 (29) 1,035 Total Current Assets 25 4,829 45 14,506 (2,893) 16,512 Investments, loans and long-term receivables* 29,400 47,974 2,533 15,050 (84,897) 10,060 Net properties, plants and equipment - 4,230 - 41,930 (477) 45,683 Other assets 15 1,146 186 1,302 (1,542) 1,107 Total Assets $ 29,440 58,179 2,764 72,788 (89,809) 73,362 Liabilities and Stockholders’ Equity Accounts payable $ - 3,094 1 3,799 (2,864) 4,030 Short-term debt (5) 2,505 7 77 (9) 2,575 Accrued income and other taxes - 107 - 931 - 1,038 Employee benefit obligations - 554 - 171 - 725 Other accruals 85 314 48 612 (30) 1,029 Total Current Liabilities 80 6,574 56 5,590 (2,903) 9,397 Long-term debt 3,787 9,321 1,703 2,794 (477) 17,128 Asset retirement obligations and accrued environmental costs - 432 - 7,199 - 7,631 Deferred income taxes - - - 6,263 (981) 5,282 Employee benefit obligations - 1,335 - 519 - 1,854 Other liabilities and deferred credits* 1,528 5,229 926 9,215 (15,629) 1,269 Total Liabilities 5,395 22,891 2,685 31,580 (19,990) 42,561 Retained earnings 22,867 13,317 (681) 11,958 (18,070) 29,391 Other common stockholders’ equity 1,178 21,971 760 29,056 (51,749) 1,216 Noncontrolling interests - - - 194 - 194 Total Liabilities and Stockholders’ Equity $ 29,440 58,179 2,764 72,788 (89,809) 73,362 Balance Sheet At December 31, 2016 Assets Cash and cash equivalents $ - 358 13 3,239 - 3,610 Short-term investments - - - 50 - 50 Accounts and notes receivable 22 1,968 23 6,103 (4,702) 3,414 Inventories - 84 - 934 - 1,018 Prepaid expenses and other current assets 2 116 8 415 (24) 517 Total Current Assets 24 2,526 44 10,741 (4,726) 8,609 Investments, loans and long-term receivables* 37,901 64,434 2,296 31,643 (114,602) 21,672 Net properties, plants and equipment - 6,301 - 52,030 - 58,331 Other assets 40 2,194 220 1,240 (2,534) 1,160 Total Assets $ 37,965 75,455 2,560 95,654 (121,862) 89,772 Liabilities and Stockholders’ Equity Accounts payable $ - 4,683 1 3,671 (4,702) 3,653 Short-term debt (10) 999 6 94 - 1,089 Accrued income and other taxes - 85 - 399 - 484 Employee benefit obligations - 489 - 200 - 689 Other accruals 171 271 40 536 (24) 994 Total Current Liabilities 161 6,527 47 4,900 (4,726) 6,909 Long-term debt 8,975 12,635 1,710 2,866 - 26,186 Asset retirement obligations and accrued environmental costs - 925 - 7,500 - 8,425 Deferred income taxes - - - 10,972 (2,023) 8,949 Employee benefit obligations - 1,901 - 651 - 2,552 Other liabilities and deferred credits* 417 10,391 748 17,832 (27,863) 1,525 Total Liabilities 9,553 32,379 2,505 44,721 (34,612) 54,546 Retained earnings 25,025 14,015 (541) 12,883 (19,834) 31,548 Other common stockholders’ equity 3,387 29,061 596 37,798 (67,416) 3,426 Noncontrolling interests - - - 252 - 252 Total Liabilities and Stockholders’ Equity $ 37,965 75,455 2,560 95,654 (121,862) 89,772 *Includes intercompany loans. Millions of Dollars Year Ended December 31, 2017 Statement of Cash Flows ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ 71 1,183 (74) 8,931 (3,034) 7,077 Cash Flows From Investing Activities Capital expenditures and investments - (1,663) - (3,795) 867 (4,591) Working capital changes associated with investing activities - 194 - (62) - 132 Proceeds from asset dispositions 7,765 11,146 - 12,796 (17,847) 13,860 Net purchases of short-term investments - - - (1,790) - (1,790) Long-term advances/loans—related parties - (214) - (85) 299 - Collection of advances/loans—related parties 658 1,527 - 2,196 (4,266) 115 Intercompany cash management 1,151 101 - (1,252) - - Other - (8) - 44 - 36 Net Cash Provided by Investing Activities 9,574 11,083 - 8,052 (20,947) 7,762 Cash Flows From Financing Activities Issuance of debt - 20 65 214 (299) - Repayment of debt (5,459) (4,411) - (2,272) 4,266 (7,876) Issuance of company common stock 115 - - - (178) (63) Repurchase of company common stock (3,000) - - - - (3,000) Dividends paid (1,305) (235) - (2,977) 3,212 (1,305) Other 4 (7,765) - (9,331) 16,980 (112) Net Cash Provided by (Used in) Financing Activities (9,645) (12,391) 65 (14,366) 23,981 (12,356) Effect of Exchange Rate Changes on Cash and Cash Equivalents - 1 - 231 - 232 Net Change in Cash and Cash Equivalents - (124) (9) 2,848 - 2,715 Cash and cash equivalents at beginning of period - 358 13 3,239 - 3,610 Cash and Cash Equivalents at End of Period $ - 234 4 6,087 - 6,325 Statement of Cash Flows Year Ended December 31, 2016 Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (306) (322) (2) 5,903 (870) 4,403 Cash Flows From Investing Activities Capital expenditures and investments - (989) - (4,281) 401 (4,869) Working capital changes associated with investing activities - (126) - (205) - (331) Proceeds from asset dispositions 2,300 266 - 1,114 (2,394) 1,286 Net purchases of short-term investments - - - (51) - (51) Long-term advances/loans—related parties - (812) - - 812 - Collection of advances/loans—related parties - 391 1,250 272 (1,805) 108 Intercompany cash management (2,214) 1,433 - 781 - - Other - 1 - (3) - (2) Net Cash Provided by (Used in) Investing Activities 86 164 1,250 (2,373) (2,986) (3,859) Cash Flows From Financing Activities Issuance of debt 1,600 2,994 - 812 (812) 4,594 Repayment of debt (150) (164) (1,250) (2,492) 1,805 (2,251) Issuance of company common stock 148 - - - (211) (63) Repurchase of company common stock (126) - - - - (126) Dividends paid (1,253) - - (1,081) 1,081 (1,253) Other 1 (2,315) - 184 1,993 (137) Net Cash Provided by (Used in) Financing Activities 220 515 (1,250) (2,577) 3,856 764 Effect of Exchange Rate Changes on Cash and Cash Equivalents - (3) - (63) - (66) Net Change in Cash and Cash Equivalents - 354 (2) 890 - 1,242 Cash and cash equivalents at beginning of period - 4 15 2,349 - 2,368 Cash and Cash Equivalents at End of Period $ - 358 13 3,239 - 3,610 Millions of Dollars Year Ended December 31, 2015 Statement of Cash Flows ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (225) 245 9 7,519 24 7,572 Cash Flows From Investing Activities Capital expenditures and investments - (3,064) - (8,386) 1,400 (10,050) Working capital changes associated with investing activities - (4) - (964) - (968) Proceeds from asset dispositions 3,500 826 - 1,225 (3,599) 1,952 Long-term advances/loans—related parties - (278) - (2,245) 2,523 - Collection of advances/loans—related parties - - - 205 (100) 105 Intercompany cash management 102 46 - (148) - - Other - 304 - 1 1 306 Net Cash Provided by (Used in) Investing Activities 3,602 (2,170) - (10,312) 225 (8,655) Cash Flows From Financing Activities Issuance of debt - 4,743 - 278 (2,523) 2,498 Repayment of debt - (100) - (103) 100 (103) Issuance of company common stock 283 - - (2) (363) (82) Dividends paid (3,664) - - (339) 339 (3,664) Other 4 (3,484) - 1,204 2,198 (78) Net Cash Provided by (Used in) Financing Activities (3,377) 1,159 - 1,038 (249) (1,429) Effect of Exchange Rate Changes on Cash and Cash Equivalents - - (1) (181) - (182) Net Change in Cash and Cash Equivalents - (766) 8 (1,936) - (2,694) Cash and cash equivalents at beginning of period - 770 7 4,285 - 5,062 Cash and Cash Equivalents at End of Period $ - 4 15 2,349 - 2,368

Schedule ll

Schedule ll	12 Months Ended
	Dec. 31, 2017
Valuation and Qualifying Accounts [Abstract]
VALUATION AND QUALIFYING ACCOUNTS	SCHEDULE II—VALUATION AND QUALIFYING ACCOUNTS (Consolidated) ConocoPhillips Millions of Dollars Balance at Charged to Balance at Description January 1 Expense Other (a) Deductions December 31 2017 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 5 2 - (3) (b) 4 Deferred tax asset valuation allowance 675 560 (c) 19 - 1,254 Included in other liabilities: Restructuring accruals 80 65 1 (93) (d) 53 2016 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 7 3 (1) (4) (b) 5 Deferred tax asset valuation allowance 734 (31) (12) (16) 675 Included in other liabilities: Restructuring accruals 156 129 1 (206) (d) 80 2015 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 5 4 (2) - (b) 7 Deferred tax asset valuation allowance 970 6 (21) (221) 734 Included in other liabilities: Restructuring accruals 61 303 (8) (200) (d) 156 (a)Represents acquisitions/dispositions/revisions and the effect of translating foreign financial statements. (b)Amounts charged off less recoveries of amounts previously charged off. (c)Includes an adjustment to the U.S. tax basis due to U.S. Tax Legislation. (d)Benefit payments.

Accounting Policies (Policies)

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Consolidation Principles and Investments	Consolidation Principles and Investments — Our consolidated financial statements include the accounts of majority-owned, controlled subsidiaries and variable interest entities where we are the primary beneficiary. The equity method is used to account for investments in affiliates in which we have the ability to exert significant influence over the affiliates’ operating and financial policies. When we do not h ave the ability to exert significant influence, the investment is either classified as available-for-sale if fair value is readily determinable, or the cost method is used if fair value is not readily determinable. Undivided interests in oil and gas joint ventures, pipelines, natural gas plants and terminals are consolidated on a proportionate basis. Other securities and investments are generally carried at cost. We manage our operations through six operating segments, defined by geographic region: Alaska, Lower 48, Canada, Europe and North Africa, Asia Pacific and Middle East, and Other International. For additional information, see Note 23 —Segment Disclosures and Related Information.
Foreign Currency Translation	Foreign Currency Translation — Adjustments resulting from the process of translating foreign functional currency financial statements into U.S. dollars are included in accumulated other comprehensive income in common stockholders’ equity. Foreign currency transaction gains and losses are included in current earn ings. Most of our foreign operations use their local currency as the f unctional currency.
Use of Estimates	Use of Estimates — The preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosures of contingent assets and liabilities. Actual results could differ from these estimates.
Revenue Recognition	Revenue Recognition — Revenues associated with sales of crude oil, bitumen, natural gas, liquefied natural gas (LNG), natural gas liquids and other items are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occ urs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry. Revenues associated with producing properties in which we have an interest with other producers are recognized based on the actual volumes we sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be nonrecoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropri ate. Cumulative differences between volumes sold and entitlement volumes are generally not significant. Revenues associated with transactions commonly called buy/sell contracts, in which the purchase and sale of inventory with the same counterparty are entered into “in contemplation” of one another, are combined and reported net (i.e., on the same income statement line) .
Shipping and Handling Costs	Shipping and Handling Costs — We include shipping and handling costs in production and operating expenses for production activities. Tra nsportation costs related to marketing activities are recorded in purchased commodities. Freight costs billed to customers are recorded as a component of revenue.
Cash Equivalents	Cash Equivalents — Cash equivalents are highly liquid, short-term investments that are readily convertible to known amounts of cash and have original maturities of 90 days or less from their date of purchase. They are carried at cost plus accrued interest, which approximates fair value.
Short-Term Investments	Short-Term Investments —Investments in bank time deposits and marketable securities (commercial paper and government obligations) with original maturities of greater than 90 days but less than one year are classified as short-term investments.
Inventories	Inventories — We have several valuation methods for our various types of in ventories and consistently use the following methods for each type of inventory. Our c ommodity-related inventories are recorded at cost primarily using the last-in, first-out (LIFO) basis. We measure these inventories at the lower-of-cost-or-market in th e aggregate. Any necessary lower-of-cost-or-market write-downs at year end are recorded as permanent adjustments to the LIFO cost basis. LIFO is used to better match current inventory costs with current revenues. Costs include both direct and indirect e xpenditures incurred in bringing an item or product to its existing condition and location, but not unusual/nonrecurring costs or research and development costs. Materials, supplies and other miscellaneous inventories, such as tubular goods and well equip ment, are valued using various methods, including the weighted-average-cost method, and the first-in, first-out (FIFO) method, consistent with industry practice.
Fair Value Measurements	Fair Value Measurements — A ssets and liabilities measured at fair value and required to be categ orized within the fair value hierarchy are categorized into one of three different levels depending on the observability of the inputs employed in the measurement . Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Le vel 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting significant modifications to observable related market data or our assumptions about pricing by market participants.
Derivative Instruments	Derivative Instruments — Derivative instruments are recorded on the balance sheet at fair value. If the right of offset exists and certain o ther criteria are met, derivative assets and liabilities with the same counterparty are netted on the balance sheet and the collateral payable or receivable is netted against derivative assets and derivative liabilities, respectively. Recognition and classification of the gain or loss that results from recording and adjusting a derivative to fair value depends on the purpose for issuing or holding the derivative. Gains and losses from derivatives not accounted for as hedges are recognized immediately in earnings.
Oil and Gas Exploration and Development	Oil and Gas Exploration and Development — Oil and gas exploration and development costs are accounted for using the successful efforts method of accounting. Property Acquisition Costs — Oil and gas leasehold acquisition costs are capitalized and included in the balance sheet caption properties, plants and equipment (PP&E). Leasehold impairment is recognized based on exploratory experience and management’s judgment. Upon achievement of all conditions necessary for reserves to be classified as proved, the associated leasehold costs are re classified to proved properties. Exploratory Costs — Geological and geophysical costs and the costs of carrying and retaining undeveloped properties are expensed as incurred. Exploratory well costs are capitalized, or “suspended,” on the balance sheet pending further evaluation of whether economically recoverable reserves have been found. If economically recoverable reserves are not found, exploratory well costs are expensed as dry holes. If explor atory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For c omplex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on the balance sheet for several years while we perform additional appraisal drilling and seismic work on the potential oil and gas field or while we seek governme nt or co-venturer approval of development plans or seek environmental permitting. Once all required approvals and permits have been obtained, the projects are moved into the development phase, and the oil and gas resources are designated as proved reserve s. Management reviews suspended well balances quarterly, continuously monitors the results of the additional appraisal drilling and seismic work, and expenses the suspended well costs as dry holes when it judges the potential field does not warrant further investment in the near term. See Note 7 —Suspended Wells and Other Exploration Expenses , for additional information on suspended wells. Development Costs — Costs incurred to drill and equip development wells, including unsuccessful development wells, are capitalized. Depletion and Amortization — Leasehold costs of producing properties are depleted using the unit-of-production method based on estimated proved oil and gas reserves. Amortization of intangible development costs is based on the unit-of-production method using estimated proved developed oil and gas reserves.
Capitalized Interest	Capitalized Interest — Interest from external borrowings is capitalized on major projects with an expected construction period of one year or longer. Capitalized interes t is added to the cost of the underlying asset and is amortized over the useful lives of the assets in the same manner as the underlying assets.
Depreciation and Amortization	Depreciation and Amortization — Depreciation and amortization of PP&E on producing hydrocarbon properties and cer tain pipeline assets (those which are expected to have a declining utilization pattern), are determined by the unit-of-production method. Depreciation and amortization of all other PP&E are determined by either the individual-unit-straight-line method or the group-straight-line method (for those individual units that are highly integrated with other units).
Impairment of Properties, Plants and Equipment	Impairment of Properties, Plants and Equipment — P P&E used in operations are assessed for impairment whenever changes in facts and circumstances indicate a possible significant deterioration in the future cash flows expected to be generated by an asset group and annually in the fourth quarter following updates to corporate planning assumptions. If there is an indication the carrying amount of an asset may not be recovered, the asset is monitored by management through an established process where changes to significant assumptions such as prices, volumes and futur e development plans are reviewed. If, upon review, the sum of the undiscounted before -tax cash flows is less than the carrying value of the asset group, the carrying value is written down to estimated fair value through additional amortization or deprecia tion provisions and reported as impairments in the periods in which the determination of the impairment is made. Individual assets are grouped for impairment purposes at the lowest level for which there are identifiable cash flows that are largely indepen dent of the cash flows of other groups of assets—generally on a field-by-field basis for exploration and production assets. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically deter mined based on the present values of expected future cash flows using discount rates believed to be consistent with those used by principal market participants or based on a multiple of operating cash flow validated with historical market transactions of s imilar assets where possible. Long-lived assets committed by management for disposal within one year are accounted for at the lower of amortized cost or fair value, less cost to sell, with fair value determined using a binding negotiated price, if availab le, or present value of expected future cash flows as previously described. The expected future cash flows used for impairment reviews and related fair value calculations are based on estimated future production volumes, prices and costs, considering all a vailable evidence at the date of review. The impairment review includes cash flows from proved developed and undeveloped reserves, including any development expenditures necessary to achieve that production. Additionally, when probable and possible reser ves exist, an appropriate risk-adjusted amount of these reserves may be included in the impairment calculation.
Impairment of Investments in Nonconsolidated Entities	Impairment of Investments in Nonconsolidated Entities — Investments in nonconsolidated entities are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred and annually following updates to corporate planning assumptions. When such a condition is judgmentally determined to be other than temporary, the carrying value of the investment is writte n down to fair value. The fair value of the impaired investment is based on quoted market prices, if available, or upon the present value of expected future cash flows using discount rates believed to be consistent with those used by principal market part icipants, plus market analysis of comparable assets owned by the investee, if appropriate.
Maintenance and Repairs	Maintenance and Repairs — C osts of ma intenance and repairs, which are not significant improvements, are expensed when incurred.
Property Dispositions	Property Dispositions — When complete units of depreciable property are sold, the asset cost and related accumulated depreciation are eliminated, with any gain or loss reflected in the “Gain on dispositions” line of our consolidated income statement. When less than complete units of depreciab le property are disposed of or retired, the difference between asset cost and salvage value is charged or credited to accumulated depreciation.
Asset Retirement Obligations and Environmental Costs	Asset Retirement Obligations and Environmental Costs — The fair value of legal obligations to retire and remove lo ng-lived assets are recorded in the period in which the obligation is incurred (typically when the asset is installed at the production location). When the liability is initially recorded, we capitalize this cost by increasing the carrying amount of the r elated PP&E. If, in subsequent periods, our estimate of this liability changes, we will record an adjustment to both the liability and PP&E. Over time the liability is increased for the change in its present value, and the capitalized cost in PP&E is dep reciated over the useful life of the related asset. For additional information, see Note 9 —Asset Retirement Obligations and Accrued Environmental C osts . Environmental expenditures are expensed or capitalized, depending upon their future economic be nefit. Expenditures relating to an existing condition caused by past operations, and those having no future economic benefit, are expensed. Liabilities for environmental expenditures are recorded on an undiscounted basis (unless acquired in a purchase bu siness combination , which we record on a discounted basis ) when environmental assessments or cleanups are probable and the costs can be reasonably estimated. Recoveries of environmental remediation costs from other parties are recorded as assets when thei r receipt is probable and estimable.
Guarantees	Guarantees — The f air value of a guarantee is determined and recorded as a liability at the time the guarantee is given. The initial liability is subsequently reduced as we are released from exposure under the guarantee. We amortize the guarantee liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of guarantee. In cases where the guarantee term is indefinite, we reverse the liability when we have information indicating the liability is essentially relieved or amortize it over an appropriate time period as the fair value of our guarantee exposure declines over time. We amortize the guarantee liability to the related income statement line item based on the nat ure of the guarantee. When it becomes probable that we will have to perform on a guarantee, we accrue a separate liability if it is reasonably estimable, based on the facts and circumstances at that time. We reverse the fair value liability only when the re is no further exposure under the guarantee.
Stock-Based Compensation	Share -Based Compensation — We recognize share -based compensation expense over the shorter of the service period (i.e., the stated period of time required to earn the award) or the period beginning at the start o f the service period and ending when an employee first becomes eligible for retirement. We have elected to recognize expense on a straight-line basis over the service period for the entire award, whether the award was granted with ratable or cliff vesting .
Income Taxes	Income Taxes — Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial reporting basis and the tax basis of our assets and liabilities, except for deferred taxes on income and tempor ary differences related to the cumulative translation adjustment considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures. Allowable tax credits are applied currently as reductions of the provision for i ncome taxes. Interest related to unrecognized tax benefits is reflected in interest and debt expense, and penalties related to unrecognized tax benefits are reflected in production and operating expenses.
Taxes Collected from Customers and Remitted to Governmental Authorities	Taxes Collected from Customers and Remitted to Gov ernmental Authorities — S ales and value-added taxes are recorded net.
Net Income (Loss) Per Share of Common Stock	Net Income (Loss) Per Share of Common Stock — Basic net income (loss) per share of common stock is calculated based upon the daily weighted-average number of common shares outstanding during the year. Also, this calculation includes fully vested stock and unit awards that have not yet been issued as common stock, along with an adjustment to net income (loss) for dividend equivalents paid on unvested unit awards that are considered participat ing securities. Diluted net income per share of common stock includes unvested stock, unit or option awards granted under our compensation plans and vested but unexercised stock options, but only to the extent these instruments dilute net income per share , primarily under the treasury-stock method. Diluted net loss per share, which is calculated the same as basic net loss per share, does not assume conversion or exercise of securities that would have an antidilutive effect. Treasury stock is excluded fro m the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the participating securities is immaterial.

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2017
Inventories [Abstract]
Inventories	Note 3 —Inventories Inventories at December 31 were: Millions of Dollars 2017 2016 Crude oil and natural gas $ 512 418 Materials and supplies 548 600 $ 1,060 1,018

Investments, Loans and Long-T36

Investments, Loans and Long-Term Receivables (Tables)	12 Months Ended
	Dec. 31, 2017
Investments, Loans and Long-Term Receivables and Joint Venture Acquisition Obligation [Abstract]
Components of investments, loans and long-term receivables	Note 5 —Investments, Loans and Long-Term Receivables Components of investments, loans and long-term receivables at December 31 were: Millions of Dollars 2017 2016 Equity investments $ 9,129 20,364 Loans and advances—related parties 461 581 Long-term receivables 375 631 Other investments 95 96 $ 10,060 21,672
Summarized financial information for equity method investments in affiliated companies	Summarized 100 percent earnings information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2017 2016 2015 Revenues $ 11,554 10,149 11,003 Income (loss) before income taxes (2,875) 660 1,866 Net income (loss) (1,431) 799 1,801 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2017 2016 Current assets $ 2,920 3,578 Noncurrent assets 42,693 60,243 Current liabilities 2,453 2,352 Noncurrent liabilities 25,522 23,764

Suspended Wells (Tables)

Suspended Wells (Tables)	12 Months Ended
	Dec. 31, 2017
Suspended Wells [Abstract]
Net changes in suspended exploratory well costs	Note 7 —Suspended Wells and Other Exploration Expenses The following table reflects the net changes in suspended exploratory well costs during 2017, 2016 and 2015: Millions of Dollars 2017 2016 2015 Beginning balance at January 1 $ 1,063 1,260 1,299 Additions pending the determination of proved reserves 118 225 331 Reclassifications to proved properties (66) (27) (28) Sales of suspended well investment - (247) - Charged to dry hole expense (262) (148) (342) Ending balance at December 31 $ 853 1,063 1,260
Aging of suspended well cost	The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2017 2016 2015 Exploratory well costs capitalized for a period of one year or less $ 67 132 235 Exploratory well costs capitalized for a period greater than one year 786 931 1,025 Ending balance $ 853 1,063 1,260 Number of projects with exploratory well costs capitalized for a period greater than one year 23 26 28
Aging of Exploratory Well Cost that have been capitalized for more than one year	The following table provides a further aging of those exploratory well costs that have been capitalized for more than one year since the completion of drilling as of December 31, 2017: Millions of Dollars Suspended Since Total 2014–2016 2011–2013 2004–2010 Greater Poseidon—Australia (2) 177 63 102 12 Greater Clair—UK (2) 144 99 45 - Surmont—Canada (1) 117 34 59 24 NPRA—Alaska (1) 114 66 42 6 Barossa/Caldita—Australia (2) 77 - - 77 Middle Magdalena Basin—Colombia (1) 48 48 - - Bohai—China (2) 19 19 - - Kamunsu East—Malaysia (2) 19 - 19 - NC 98—Libya (2) 15 11 - 4 Sunrise—Australia (2) 13 - - 13 Other of $10 million or less each (1)(2) 43 20 6 17 Total $ 786 360 273 153 (1)Additional appraisal wells planned. (2)Appraisal drilling complete; costs being incurred to assess development.

Impairments (Tables)

Impairments (Tables)	12 Months Ended
	Dec. 31, 2017
Impairment Of Long Lived Assets [Abstract]
Impairment Charges By Segment Before Tax	Note 8 —Impairments During 2017, 2016 and 2015, we recognized the following before-tax impairment charges: Millions of Dollars 2017 2016 2015 Alaska $ 180 1 10 Lower 48 3,969 149 (2) Canada 22 88 4 Europe and North Africa 46 (160) 724 Asia Pacific and Middle East 2,384 44 1,508 Corporate - 17 1 $ 6,601 139 2,245

Asset Retirement Obligations 39

Asset Retirement Obligations and Accrued Environmental Costs (Tables)	12 Months Ended
	Dec. 31, 2017
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations and accrued environmental costs	Note 9 —Asset Retirement Obligations and Accrued Environmental Costs Asset retirement obligations and accrued environmental costs at December 31 were: Millions of Dollars 2017 2016 Asset retirement obligations $ 7,798 8,405 Accrued environmental costs 180 247 Total asset retirement obligations and accrued environmental costs 7,978 8,652 Asset retirement obligations and accrued environmental costs due within one year* (347) (227) Long-term asset retirement obligations and accrued environmental costs $ 7,631 8,425 *Classified as a current liability on the balance sheet under "Other accruals."
Changes in overall asset retirement obligation changed	During 2017 and 2016, our overall ARO changed as follows: Millions of Dollars 2017 2016 Balance at January 1 $ 8,405 9,911 Accretion of discount 358 420 New obligations 113 180 Changes in estimates of existing obligations (150) (1,197) Spending on existing obligations (152) (314) Property dispositions (1,065) (150) Foreign currency translation 289 (445) Balance at December 31 $ 7,798 8,405

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2017
Debt [Abstract]
Long-term debt	Note 10 —Debt Long-term debt at December 31 was: Millions of Dollars 2017 2016 9.125% Debentures due 2021 $ 150 150 8.20% Debentures due 2025 150 150 8.125% Notes due 2030 600 600 7.9% Debentures due 2047 100 100 7.8% Debentures due 2027 300 300 7.65% Debentures due 2023 88 88 7.40% Notes due 2031 500 500 7.375% Debentures due 2029 92 92 7.25% Notes due 2031 500 500 7.20% Notes due 2031 575 575 7% Debentures due 2029 200 200 6.95% Notes due 2029 1,549 1,549 6.875% Debentures due 2026 67 67 6.65% Debentures due 2018 - 297 6.50% Notes due 2039 2,750 2,750 6.00% Notes due 2020 - 1,000 5.951% Notes due 2037 645 645 5.95% Notes due 2036 500 500 5.95% Notes due 2046 500 500 5.90% Notes due 2032 505 505 5.90% Notes due 2038 600 600 5.75% Notes due 2019 - 2,250 5.20% Notes due 2018 - 500 4.95% Notes due 2026 1,250 1,250 4.30% Notes due 2044 750 750 4.20% Notes due 2021 1,000 1,250 4.15% Notes due 2034 500 500 3.35% Notes due 2024 1,000 1,000 3.35% Notes due 2025 500 500 2.875% Notes due 2021 750 750 2.4% Notes due 2022 1,000 1,000 2.2% Notes due 2020 500 500 1.5% Notes due 2018 - 750 1.05% Notes due 2017 - 1,000 Floating rate term loan due 2019 at 2.31% – 2.75% during 2017 and 1.94% – 2.31% during 2016 - 1,450 Floating rate notes due 2018 at 1.24% – 1.75% during 2017 and 0.69% – 1.24% during 2016 250 250 Floating rate notes due 2022 at 1.81% – 2.32% during 2017 and 1.26% – 1.81% during 2016 500 500 Industrial Development Bonds due 2017 through 2038 at 0.64% – 1.74% during 2017 and 0.01% – 0.91% during 2016 18 18 Marine Terminal Revenue Refunding Bonds due 2031 at 0.64% – 1.74% during 2017 and 0.01% – 0.95% during 2016 265 265 Other 23 24 Debt at face value 18,677 26,175 Capitalized leases 774 852 Net unamortized premiums, discounts and debt issuance costs 252 248 Total debt 19,703 27,275 Short-term debt (2,575) (1,089) Long-term debt $ 17,128 26,186
Capital lease payment table	At December 31, 2017, future minimum payments due under capital leases were: Millions of Dollars 2018 $ 108 2019 106 2020 106 2021 88 2022 88 Remaining years 487 Total 983 Less: portion representing imputed interest (209) Capital lease obligations $ 774

Derivative and Financial Inst41

Derivative and Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2017
Derivative and Financial Instruments [Abstract]
Balance sheet location and fair value amounts of derivatives	The following table presents the gross fair values of our commodity derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet: Millions of Dollars 2017 2016 Assets Prepaid expenses and other current assets $ 275 268 Other assets 36 44 Liabilities Other accruals 282 300 Other liabilities and deferred credits 28 34 The following table presents the gross fair values of our foreign currency exchange derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet: Millions of Dollars 2017 2016 Assets Prepaid expenses and other current assets $ 1 1 Other assets 6 - Liabilities Other accruals - 168 Other liabilities and deferred credits 15 - In December 2017, we entered into foreign exchange zero cost collars buying the right to sell $1.25 billion CAD at $0.707 CAD and selling the right to buy $1.25 billion CAD at $0.842 CAD against the U.S. dollar.
Income statement location and gain/loss amounts of derivatives	The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars 2017 2016 2015 Sales and other operating revenues $ 77 (198) 231 Other income - (1) 2 Purchased commodities (61) 161 (201) The (gains) losses from foreign currency exchange derivatives incurred and the line item where they appear on our consolidated income statement were: Millions of Dollars 2017 2016 2015 Foreign currency transaction (gains) losses $ 13 247 (33)
Net exposures/net notional positions of derivative contracts	The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts: Open Position Long/(Short) 2017 2016 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (29) (31) Basis 12 2 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency 2017 2016 Foreign Currency Exchange Derivatives Sell U.S. dollar, buy other currencies (1) USD - 13 Buy U.S. dollar, sell other currencies (2) USD - 25 Buy British pound, sell other currencies (3) GBP - 1,069 Sell British pound, buy other currencies (4) GBP 1 51 Sell Canadian dollar, buy U.S. dollar CAD 1,225 - (1)Primarily Canadian dollar. (2)Primarily British pound. (3)Primarily Canadian dollar. (4)Primarily euro and Norwegian krone.
Net carrying amount of held to maturity investments	Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments 2017 2016 2017 2016 Cash $ 948 623 - - Time deposits Remaining maturities from 1 to 90 days 5,004 2,987 821 39 Remaining maturities from 91 to 180 days - - - 11 Commercial paper Remaining maturities from 1 to 90 days 373 - 978 - Remaining maturities from 91 to 180 days - - 74 - $ 6,325 3,610 1,873 50

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2017
Fair Value Measurement [Abstract]
Fair value hierarchy for gross financial assets and liabilities	Millions of Dollars December 31, 2017 December 31, 2016 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ 1,899 - - 1,899 - - - - Commodity derivatives 175 106 30 311 194 96 22 312 Total assets $ 2,074 106 30 2,210 194 96 22 312 Liabilities Commodity derivatives $ 158 111 41 310 207 105 22 334 Total liabilities $ 158 111 41 310 207 105 22 334
Commodity derivative balances subject to right of setoff	The following table summarizes those commodity derivative balances subject to the right of setoff as presented on our consolidated balance sheet. We have elected to offset the recognized fair value amounts for multiple derivative instruments executed with the same counterparty in our financial statements when a legal right of offset exists. Millions of Dollars Gross Gross Net Gross Amounts Amounts Amounts Amounts Cash without Net Recognized Offset Presented Collateral Right of Setoff Amounts December 31, 2017 Assets $ 311 186 125 - 4 121 Liabilities 310 186 124 7 5 112 December 31, 2016 Assets $ 312 221 91 - 5 86 Liabilities 334 221 113 12 12 89 At December 31, 2017, and December 31, 2016, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff.
Values of assets, by major category, measured at fair value on a nonrecurring basis	Non-Recurring Fair Value Measurement The following table summarizes the fair value hierarchy by major category and date of remeasurement for assets accounted for at fair value on a non-recurring basis: Millions of Dollars Fair Value Measurements Using Fair Value Level 1 Inputs Level 3 Inputs Before-Tax Loss Year ended December 31, 2017 Net PP&E (held for use) December 31, 2017 $ 75 - 75 154 Net PP&E (held for sale) June 30, 2017 2,830 2,830 - 3,882 December 31, 2017 113 113 - 78 Cost and equity method investments June 30, 2017 7,656 - 7,656 2,384 Year ended December 31, 2016 Net PP&E (held for use) March 31, 2016 $ 217 - 217 129 June 30, 2016 23 - 23 53 December 31, 2016 13 - 13 29 Net PP&E (held for sale) September 30, 2016 217 217 - 99 Cost and equity method investments December 31, 2016 90 4 86 40
Commodity derivative and financial instruments	The following table summarizes the net fair value of financial instruments (i.e., adjusted where the right of setoff exists for commodity derivatives): Millions of Dollars Carrying Amount Fair Value 2017 2016 2017 2016 Financial assets Investment in Cenovus Energy $ 1,899 - 1,899 - Commodity derivatives 125 91 125 91 Total loans and advances—related parties 586 701 586 701 Financial liabilities Total debt, excluding capital leases 18,929 26,423 22,435 29,307 Commodity derivatives 117 101 117 101

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Changes in shares of common stock	Note 15 —Equity Common Stock The changes in our shares of common stock, as categorized in the equity section of the balance sheet, were: Shares 2017 2016 2015 Issued Beginning of year 1,782,079,107 1,778,226,388 1,773,583,368 Distributed under benefit plans 3,340,068 3,852,719 4,643,020 End of year 1,785,419,175 1,782,079,107 1,778,226,388 Held in Treasury Beginning of year 544,809,771 542,230,673 542,230,673 Repurchase of common stock 63,502,263 2,579,098 - End of year 608,312,034 544,809,771 542,230,673

Non Mineral Leases (Tables)

Non Mineral Leases (Tables)	12 Months Ended
	Dec. 31, 2017
Leases [Abstract]
Future minimum rental payments due under noncancelable leases	At December 31, 2017, future minimum rental payments due under noncancelable leases were: Millions of Dollars 2018 $ 278 2019 214 2020 414 2021 126 2022 307 Remaining years 209 Total 1,548 Less: income from subleases (11) Net minimum operating lease payments $ 1,537
Operating leases rental expense	Operating lease rental expense for the years ended December 31 was: Millions of Dollars 2017 2016 2015 Total rentals $ 264 537 432 Less: sublease rentals (20) (10) * (9) $ 244 527 423 *Amount updated to reflect additional sublease income in 2016.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2017
Compensation And Retirement Disclosure [Abstract]
Pension and Postretirement Plans	An analysis of the projected benefit obligations for our pension plans and accumulated benefit obligations for our postretirement health and life insurance plans follows: Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 3,416 3,445 3,772 3,321 286 352 Service cost 89 77 108 76 2 2 Interest cost 118 103 133 120 9 13 Plan participant contributions - 2 - 3 23 24 Plan amendments - - - - - (27) Actuarial (gain) loss 244 52 247 466 12 (14) Benefits paid (631) (117) (872) (148) (68) (68) Curtailment - - 14 10 - 3 Settlement - - - (46) - - Recognition of termination benefits - - 14 1 - - Foreign currency exchange rate change - 283 - (358) 1 1 Benefit obligation at December 31* $ 3,236 3,845 3,416 3,445 265 286 *Accumulated benefit obligation portion of above at 3,076 3,404 3,246 3,067 December 31: $ Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 2,081 3,068 2,606 3,063 - - Actual return on plan assets 336 313 133 397 - - Company contributions 755 114 214 125 45 44 Plan participant contributions - 2 - 3 23 24 Benefits paid (631) (117) (872) (148) (68) (68) Foreign currency exchange rate change - 267 - (372) - - Fair value of plan assets at December 31 $ 2,541 3,647 2,081 3,068 - - Funded Status $ (695) (198) (1,335) (377) (265) (286)
Weighted-Average Assumptions Used to Determine Benefit Obligations and Net Periodic Benefit Cost	Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 205 - 164 - - Current liabilities (38) (4) (101) (7) (45) (44) Noncurrent liabilities (657) (399) (1,234) (534) (220) (242) Total recognized $ (695) (198) (1,335) (377) (265) (286) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 3.55 % 2.80 3.95 3.00 3.30 3.60 Rate of compensation increase 4.00 3.75 4.00 3.85 - - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.80 % 3.00 3.90 3.95 3.60 3.75 Expected return on plan assets 6.55 5.05 7.00 5.45 - - Rate of compensation increase 4.00 3.85 4.00 4.05 - -
Sources of change in other comprehensive income	Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ (40) 71 (263) (232) (12) 14 Amortization of (gain) loss included in income (loss)* 200 50 288 26 (3) (5) Net change during the period $ 160 121 25 (206) (15) 9 Prior service credit (cost) arising during the period $ - 2 - (4) - 27 Amortization of prior service cost (credit) included in income (loss) 4 (6) 5 (6) (36) (34) Net change during the period $ 4 (4) 5 (10) (36) (7) *Includes settlement losses recognized in 2017 and 2016.
Amounts included in accumulated other comprehensive income that are expected to be amortized into net periodic postretirement cost	Included in accumulated other comprehensive income (loss) at December 31 were the following before-tax amounts that had not been recognized in net periodic benefit cost: Millions of Dollars Pension Benefits Other Benefits 2017 2016 2017 2016 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial (gain) loss $ 588 358 748 479 (12) (27) Unrecognized prior service cost (credit) - (16) 4 (20) (249) (285) Included in accumulated other comprehensive loss at December 31, 2017, were the following before-tax amounts that are expected to be amortized into net periodic benefit cost during 2018: Millions of Dollars Pension Other Benefits Benefits U.S. Int’l. Unrecognized net actuarial (gain) loss $ 59 36 (1) Unrecognized prior service credit - (5) (34)
Net periodic benefit cost of all defined benefit plans	The components of net periodic benefit cost of all defined benefit plans are presented in the following table: Millions of Dollars Pension Benefits Other Benefits 2017 2016 2015 2017 2016 2015 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 89 77 108 76 138 124 2 2 4 Interest cost 118 103 133 120 161 135 9 13 22 Expected return on plan assets (132) (158) (149) (147) (201) (164) - - - Amortization of prior service cost (credit) 4 (6) 5 (6) 6 (7) (36) (34) (17) Recognized net actuarial loss (gain) 69 50 86 26 115 82 (3) (2) 2 Settlements 131 - 202 - 197 7 - - - Curtailment (gain) loss - - 14 - 35 (4) - 1 2 Net periodic benefit cost $ 279 66 399 69 451 173 (28) (20) 13
Fair values of our pension plan assets	The fair values of our pension plan assets at December 31, by asset class were as follows: Millions of Dollars U.S. International Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total 2017 Equity securities U.S. $ 161 - 14 175 440 - - 440 International 178 - - 178 315 - - 315 Common/collective trusts - - - - - 183 - 183 Mutual funds 146 - - 146 292 165 - 457 Debt securities Government - - - - 902 - - 902 Corporate - 2 - 2 - - - - Common/collective trusts - - - - - 648 - 648 Mutual funds - - - - 144 - - 144 Cash and cash equivalents - - - - 111 - - 111 Time deposits - - - - 3 - - 3 Derivatives - - - - 5 - - 5 Real estate - - - - - - 123 123 Total in fair value hierarchy $ 485 2 14 501 2,212 996 123 3,331 Investments measured at net asset value* Equity securities Common/collective trusts $ - - - 805 - - - - Debt securities Corporate - - - - - - - 172 Agency and mortgage-backed securities - - - - - - - 15 Common/collective trusts - - - 1,042 - - - - Cash and cash equivalents - - - 17 - - - 24 Real estate - - - 74 - - - 94 Total** $ 485 2 14 2,439 2,212 996 123 3,636 *In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets. **Excludes the participating interest in the insurance annuity contract with a net asset value of $99 million and net receivables related to security transactions of $14 million. The fair values of our pension plan assets at December 31, by asset class were as follows: Millions of Dollars U.S. International Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total 2016 Equity securities U.S. $ 632 - 14 646 628 - - 628 International 342 - - 342 428 - - 428 Common/collective trusts - - - - - 156 - 156 Mutual funds 62 - - 62 268 139 - 407 Debt securities Government - 38 - 38 470 - - 470 Corporate - 54 3 57 - - - - Common/collective trusts - - - - - 385 - 385 Mutual funds - - - - 137 - - 137 Cash and cash equivalents - - - - 48 - - 48 Derivatives - - - - 18 - - 18 Real estate - - - - - - 111 111 Total in fair value hierarchy $ 1,036 92 17 1,145 1,997 680 111 2,788 Investments measured at net asset value* Equity securities Common/collective trusts $ - - - 410 - - - - Debt securities Corporate - - - - - - - 155 Agency and mortgage-backed securities - - - - - - - 27 Common/collective trusts - - - 312 - - - - Cash and cash equivalents - - - 36 - - - 11 Real estate - - - 69 - - - 76 Total** $ 1,036 92 17 1,972 1,997 680 111 3,057 *In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets. **Excludes the participating interest in the insurance annuity contract with a net asset value of $121 million and net payables related to security transactions of $1 million.
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:	The following benefit payments, which are exclusive of amounts to be paid from the insurance annuity contract and which reflect expected future service, as appropriate, are expected to be paid: Millions of Dollars Pension Other Benefits Benefits U.S. Int’l. 2018 $ 383 122 40 2019 302 141 37 2020 290 135 34 2021 286 144 31 2022 291 144 28 2023–2027 1,247 780 91
Share-based compensation expense recognized in income and the associated tax benefit	Compensation Expense — Total share-based compensation expense recognized in loss and the associated tax benefit for the years ended December 31 were as follows: Millions of Dollars 2017 2016 2015 Compensation cost $ 227 272 362 Tax benefit 76 92 123
Significant assumptions used to calculate the fair market values	The fair market values of the options granted over the past three years were measured on the date of grant using the Black-Scholes-Merton option-pricing model. The weighted-average assumptions used were as follows: 2017 2016 2015 Assumptions used Risk-free interest rate 2.24 % 1.55 1.79 Dividend yield 4.00 % 4.00 4.00 Volatility factor 28.12 % 26.80 23.32 Expected life (years) 6.39 6.37 5.79
Summary of stock option activity	The following summarizes our stock option activity for the year ended December 31, 2017: Weighted- Weighted- Average Millions of Dollars Average Grant Date Aggregate Options Exercise Price Fair Value Intrinsic Value Outstanding at December 31, 2016 23,712,112 $ 52.14 $ 128 Granted 2,670,200 49.76 $ 9.18 Exercised (360,396) 37.24 4 Forfeited (50,696) 48.55 Expired or cancelled (1,248,417) 50.61 Outstanding at December 31, 2017 24,722,803 $ 52.18 $ 177 Vested at December 31, 2017 23,424,010 $ 52.52 $ 162 Exercisable at December 31, 2017 18,074,088 $ 54.34 $ 101 The following summarizes our stock unit activity for the year ended December 31, 2017: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2016 8,507,504 $ 48.65 Granted 3,011,903 48.77 Forfeited (372,871) 45.99 Issued (3,319,684) $ 159 Outstanding at December 31, 2017 7,826,852 $ 45.75 Not Vested at December 31, 2017 5,396,027 $ 45.58
Summary of Performance Share Program activity	The following summarizes our stock-settled Performance Share Program activity for the year ended December 31, 2017: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2016 3,889,524 $ 51.93 Granted 30,953 49.76 Issued (1,167,012) $ 57 Outstanding at December 31, 2017 2,753,465 $ 50.79 Not Vested at December 31, 2017 67,083 $ 48.17 The following summarizes our cash-settled Performance Share Program activity for the year ended December 31, 2017: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2016 1,274,762 $ 50.39 Granted 456,909 49.76 Settled (517,138) $ 24 Outstanding at December 31, 2017 1,214,533 $ 55.19 Not Vested at December 31, 2017 122,228 $ 55.19
Summary of aggregate activity of restricted shares and units	The following summarizes the aggregate activity of these restricted shares and units for the year ended December 31, 2017: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2016 1,317,964 $ 33.16 Granted 87,980 48.87 Cancelled (24,486) 21.37 Issued (80,418) $ 4 Outstanding at December 31, 2017 1,301,040 $ 32.66 Not Vested at December 31, 2017 -
Severance accrual	Millions of Dollars Balance at December 31, 2016 $ 80 Accruals 65 Benefit payments (93) Foreign currency translation adjustments 1 Balance at December 31, 2017 $ 53

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
Income Taxes [Abstract]
Income taxes charged to income (loss)	Note 18 —Income Taxes Income tax benefits included in net loss were: Millions of Dollars 2017 2016 2015 Income Taxes Federal Current $ 79 (9) (718) Deferred (3,046) (1,634) (1,443) Foreign Current 1,729 393 745 Deferred (510) (519) (1,315) State and local Current 51 (135) 8 Deferred (125) (67) (145) $ (1,822) (1,971) (2,868)
Components of deferred tax liabilities and assets	Deferred income taxes reflect the net tax effect of temporary differences between the carrying amounts of assets and liabilities for financial reporting purposes and the amounts used for tax purposes. Major components of deferred tax liabilities and assets at December 31 were: Millions of Dollars 2017 2016 Deferred Tax Liabilities PP&E and intangibles $ 9,692 15,099 Investments in joint ventures - 933 Inventory 61 36 Deferred state income tax 178 203 Other 464 486 Total deferred tax liabilities 10,395 16,757 Deferred Tax Assets Benefit plan accruals 786 1,280 Asset retirement obligations and accrued environmental costs 3,060 3,514 Investments in joint ventures 57 - Other financial accruals and deferrals 166 317 Loss and credit carryforwards 2,310 3,522 Other 152 250 Total deferred tax assets 6,531 8,883 Less: valuation allowance (1,254) (675) Net deferred tax assets 5,277 8,208 Net deferred tax liabilities $ 5,118 8,549
Components of loss and credit carryforwards and applicable valulation allowances	At December 31, 2017, the components of our loss and credit carryforwards before and after consideration of the applicable valuation allowances are: Millions of Dollars Net Deferred Expiration of Gross Deferred Tax Asset After Net Deferred Tax Asset Valuation Allowance Tax Asset U.S. foreign tax credits $ 856 567 2025-2027 U.S. general business credits 227 227 2036-2037 State net operating losses and tax credits 420 - Foreign net operating losses and tax credits 807 786 Post 2025 $ 2,310 1,580
Reconciliation of the beginning and ending unrecognized tax benefits	The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2017, 2016 and 2015: Millions of Dollars 2017 2016 2015 Balance at January 1 $ 381 459 442 Additions based on tax positions related to the current year 612 32 54 Additions for tax positions of prior years 109 19 4 Reductions for tax positions of prior years (129) (118) (37) Settlements (5) (9) (4) Lapse of statute (86) (2) - Balance at December 31 $ 882 381 459
Amounts of U.S. and foreign income (loss) before income taxes	The amounts of U.S. and foreign income (loss) before income taxes, with a reconciliation of tax at the federal statutory rate with the provision for income taxes, were: Millions of Dollars Percent of Pre-Tax Income (Loss) 2017 2016 2015 2017 2016 2015 Loss before income taxes United States $ (5,250) (4,410) (4,150) 200.8 % 79.7 57.3 Foreign 2,635 (1,120) (3,089) (100.8) 20.3 42.7 $ (2,615) (5,530) (7,239) 100.0 % 100.0 100.0 Federal statutory income tax $ (915) (1,936) (2,534) 35.0 % 35.0 35.0 Non-U.S. effective tax rates 625 361 301 (23.9) (6.5) (4.2) Impact of U.S. tax legislation (852) - - 32.6 - - Canada disposition (1,277) - - 48.8 - - Recovery of outside basis (962) (60) (491) 36.8 1.1 6.8 Adjustment to tax reserves 881 55 42 (33.7) (1.0) (0.6) APLNG impairment 834 - 525 (31.9) - (7.3) State income tax (84) (122) (85) 3.2 2.2 1.2 Enhanced oil recovery credit (68) (62) - 2.6 1.1 - U.K. rate change - (161) (555) - 2.9 7.7 Canada rate change - - 129 - - (1.8) U.S. fair value election - - (185) - - 2.6 Other (4) (46) (15) 0.2 0.8 0.2 $ (1,822) (1,971) (2,868) 69.7 % 35.6 39.6

Accumulated Other Comprehensi47

Accumulated Other Comprehensive Income (Tables)	12 Months Ended
	Dec. 31, 2017
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated other comprehensive income in the equity section of the balance sheet included	Note 19 —Accumulated Other Comprehensive Loss Accumulated other comprehensive loss in the equity section of the balance sheet included: Millions of Dollars Defined Benefit Plans Net Unrealized Loss on Securities Foreign Currency Translation Accumulated Other Comprehensive Loss December 31, 2014 $ (1,261) - (641) (1,902) Other comprehensive income (loss) 818 - (5,163) (4,345) December 31, 2015 (443) - (5,804) (6,247) Other comprehensive income (loss) (104) - 158 54 December 31, 2016 (547) - (5,646) (6,193) Other comprehensive income (loss) 147 (58) 586 675 December 31, 2017 $ (400) (58) (5,060) (5,518) There were no items within accumulated other comprehensive loss related to noncontrolling interests.
Items reclassified out of accumulated other comprehensive income (loss)	The following table summarizes reclassifications out of accumulated other comprehensive loss during the years ended December 31: Millions of Dollars 2017 2016 Defined Benefit Plans $ 135 179 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 74 95 See Note 17—Employee Benefit Plans, for additional information.

Cash Flow Information (Tables)

Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2017
Cash Flow Information [Abstract]
Cash Flow Information	Note 20 —Cash Flow Information Millions of Dollars 2017 2016 2015 Noncash Investing Activities Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations $ (37) (1,017) 402 Cash Payments (Receipts) Interest $ 1,163 1,151 920 Income taxes 1,168 (318) * 523 * Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ (6,617) (1,753) - Short-term investments sold 4,827 1,702 - $ (1,790) (51) - *Net of $585 million and $642 million in 2016 and 2015, respectively, related to refunds received from the Internal Revenue Service.

Other Financial Information (Ta

Other Financial Information (Tables)	12 Months Ended
	Dec. 31, 2017
Other Financial Information [Abstract]
Other Financial Information	Note 21 —Other Financial Information Millions of Dollars 2017 2016 2015 Interest and Debt Expense Incurred Debt $ 1,114 1,279 1,130 Other 103 123 84 1,217 1,402 1,214 Capitalized (119) (157) (294) Expensed $ 1,098 1,245 920 Other Income Interest income $ 112 57 45 Other, net 417 198 80 $ 529 255 125 Research and Development Expenditures —expensed $ 100 116 222 Shipping and Handling Costs* $ 1,058 1,139 1,181 *Amounts included in production and operating expenses. Foreign Currency Transaction (Gains) Losses —after-tax Alaska $ - - - Lower 48 - - - Canada 3 1 - Europe and North Africa 7 (7) (22) Asia Pacific and Middle East 23 (9) (78) Other International 1 7 (9) Corporate and Other (3) (18) 45 $ 31 (26) (64)
Property, Plant And Equipment [Table Text Block]	Millions of Dollars 2017 2016 Properties, Plants and Equipment Proved properties $ 102,044 119,970 Unproved properties 4,491 5,150 Other 3,896 6,286 Gross properties, plants and equipment 110,431 131,406 Less: Accumulated depreciation, depletion and amortization (64,748) (73,075) Net properties, plants and equipment $ 45,683 58,331

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2017
Related Party Transactions [Abstract]
Significant transactions with related parties	Note 22 —Related Party Transactions Our related parties primarily include equity method investments and certain trusts for the benefit of employees. Significant transactions with our equity affiliates were: Millions of Dollars 2017 2016 2015 Operating revenues and other income $ 107 133 118 Purchases 99 101 97 Operating expenses and selling, general and administrative expenses 59 63 62 Net interest (income) expense* (13) (12) (9) *We paid interest to, or received interest from, various affiliates. See Note 5 —Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Segment Disclosures and Relat51

Segment Disclosures and Related Information (Tables)	12 Months Ended
	Dec. 31, 2017
Segment Disclosures and Related Information [Abstract]
Sales and Other Operating Revenues	Analysis of Results by Operating Segment Millions of Dollars 2017 2016 2015 Sales and Other Operating Revenues Alaska $ 4,224 3,681 4,351 Lower 48 12,968 10,719 11,976 Intersegment eliminations (4) (17) (63) Lower 48 12,964 10,702 11,913 Canada 3,178 2,192 2,454 Intersegment eliminations (559) (218) (318) Canada 2,619 1,974 2,136 Europe and North Africa 5,181 3,462 6,110 Intersegment eliminations - - (4) Europe and North Africa 5,181 3,462 6,106 Asia Pacific and Middle East 4,014 3,705 4,746 Intersegment eliminations - - (1) Asia Pacific and Middle East 4,014 3,705 4,745 Other International - - 1 Corporate and Other 104 169 312 Consolidated sales and other operating revenues $ 29,106 23,693 29,564
Depreciation, Depletion, Amortization and Impairments	Depreciation, Depletion, Amortization and Impairments Alaska $ 1,026 868 690 Lower 48 6,693 4,358 4,227 Canada 461 975 788 Europe and North Africa 1,313 1,253 2,565 Asia Pacific and Middle East 3,819 1,606 2,981 Other International - 1 - Corporate and Other 134 140 107 Consolidated depreciation, depletion, amortization and impairments $ 13,446 9,201 11,358 In 2017, sales by our Lower 48, Alaska and Canada segments to a certain refining company accounted for approximately $3 billion or 11 percent of our total consolidated sales and other operating revenues.
Equity in Earnings of Affiliates	Millions of Dollars 2017 2016 2015 Equity in Earnings of Affiliates Alaska $ 7 9 4 Lower 48 5 (6) (5) Canada 197 89 78 Europe and North Africa 10 22 23 Asia Pacific and Middle East 553 (51) 550 Other International - - 8 Corporate and Other - (11) (3) Consolidated equity in earnings of affiliates $ 772 52 655
Income Taxes	Income Taxes Alaska $ (689) (59) (71) Lower 48 (2,453) (1,328) (1,119) Canada (616) (383) (223) Europe and North Africa 1,165 (46) (854) Asia Pacific and Middle East 351 306 467 Other International 21 (40) (456) Corporate and Other 399 (421) (612) Consolidated income taxes $ (1,822) (1,971) (2,868)
Net Income Attributable to ConocoPhillips	Net Income (Loss) Attributable to ConocoPhillips Alaska $ 1,466 319 4 Lower 48 (2,371) (2,257) (1,932) Canada 2,564 (935) (1,044) Europe and North Africa 553 394 409 Asia Pacific and Middle East (1,098) 209 (463) Other International 167 (16) (593) Corporate and Other (2,136) (1,329) (809) Consolidated net loss attributable to ConocoPhillips $ (855) (3,615) (4,428)
Investments In and Advances To Affiliates	Investments In and Advances To Affiliates Alaska $ 56 58 61 Lower 48 402 426 455 Canada - 8,784 8,165 Europe and North Africa 55 62 70 Asia Pacific and Middle East 9,077 11,611 11,780 Other International - - - Corporate and Other - 4 15 Consolidated investments in and advances to affiliates $ 9,590 20,945 20,546
Total Assets	Millions of Dollars 2017 2016 2015 Total Assets Alaska $ 12,108 12,314 12,555 Lower 48 14,632 22,673 26,932 Canada 6,214 17,548 17,221 Europe and North Africa 11,870 11,727 13,703 Asia Pacific and Middle East 16,985 20,451 22,318 Other International 97 97 282 Corporate and Other 11,456 4,962 4,473 Consolidated total assets $ 73,362 89,772 97,484
Capital Expenditures and Investments	Capital Expenditures and Investments Alaska $ 815 883 1,352 Lower 48 2,136 1,262 3,765 Canada 202 698 1,255 Europe and North Africa 872 1,020 1,573 Asia Pacific and Middle East 482 838 1,812 Other International 21 104 173 Corporate and Other 63 64 120 Consolidated capital expenditures and investments $ 4,591 4,869 10,050
Interest Income and Expense	Interest Income and Expense Interest income Corporate $ 101 47 36 Lower 48 - - - Europe and North Africa 2 2 2 Asia Pacific and Middle East 9 8 6 Other International - - 1 Interest and debt expense Corporate $ 1,098 1,245 920
Geographic Information	Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2017 2016 2015 2017 2016 2015 United States $ 17,204 14,400 16,284 23,623 32,949 37,445 Australia (3) 1,448 1,353 2,127 9,657 12,259 12,788 Canada 2,619 1,974 2,136 5,613 16,846 16,766 China 712 551 782 1,275 1,372 1,647 Indonesia 757 938 1,165 758 856 1,191 Malaysia 1,103 735 598 2,736 3,323 3,599 Norway 2,348 1,645 2,107 6,154 6,228 6,933 United Kingdom 2,248 1,816 4,005 3,335 3,209 4,154 Other foreign countries 667 281 360 2,122 2,234 2,469 Worldwide consolidated $ 29,106 23,693 29,564 55,273 79,276 86,992 (1)Sales and other operating revenues are attributable to countries based on the location of the selling operation. (2)Defined as net PP&E plus investments in and advances to affiliated companies. (3)Includes amounts related to the joint petroleum development area with shared ownership held by Australia and Timor-Leste.
Sales and Other Operating Revenues by Product	Sales and Other Operating Revenues by Product Crude oil $ 13,260 10,801 12,830 Natural gas 10,773 9,401 11,888 Natural gas liquids 1,102 837 952 Other* 3,971 2,654 3,894 Consolidated sales and other operating revenues by product $ 29,106 23,693 29,564 *Includes LNG and bitumen.

Supplementary Information - C52

Supplementary Information - Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2017
Supplementary Information - Condensed Consolidating Financial Information [Abstract]
Condensed Consolidated Income Statement	Millions of Dollars Year Ended December 31, 2017 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 12,433 - 16,673 - 29,106 Equity in earnings (losses) of affiliates (454) 2,047 - 630 (1,451) 772 Gain on dispositions - 916 - 1,261 - 2,177 Other income 2 35 - 492 - 529 Intercompany revenues 48 291 170 3,405 (3,914) - Total Revenues and Other Income (404) 15,722 170 22,461 (5,365) 32,584 Costs and Expenses Purchased commodities - 11,145 - 4,580 (3,250) 12,475 Production and operating expenses - 832 - 4,358 (17) 5,173 Selling, general and administrative expenses 9 476 - 82 (6) 561 Exploration expenses - 544 - 394 - 938 Depreciation, depletion and amortization - 855 - 5,990 - 6,845 Impairments - 1,159 - 5,442 - 6,601 Taxes other than income taxes - 140 - 669 - 809 Accretion on discounted liabilities - 32 - 330 - 362 Interest and debt expense 420 664 147 508 (641) 1,098 Foreign currency transaction (gains) losses (43) 11 156 (89) - 35 Other expense 267 35 - - - 302 Total Costs and Expenses 653 15,893 303 22,264 (3,914) 35,199 Income (Loss) before income taxes (1,057) (171) (133) 197 (1,451) (2,615) Income tax provision (benefit) (202) 283 7 (1,910) - (1,822) Net income (loss) (855) (454) (140) 2,107 (1,451) (793) Less: net income attributable to noncontrolling interests - - - (62) - (62) Net Income (Loss) Attributable to ConocoPhillips $ (855) (454) (140) 2,045 (1,451) (855) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (180) 221 23 2,703 (2,947) (180) Income Statement Year Ended December 31, 2016 Revenues and Other Income Sales and other operating revenues $ - 10,352 - 13,341 - 23,693 Equity in earnings (losses) of affiliates (3,351) (1,051) - (91) 4,545 52 Gain on dispositions - 120 - 240 - 360 Other income 1 (11) - 265 - 255 Intercompany revenues 88 277 220 3,036 (3,621) - Total Revenues and Other Income (3,262) 9,687 220 16,791 924 24,360 Costs and Expenses Purchased commodities - 9,144 - 3,562 (2,712) 9,994 Production and operating expenses - 779 - 5,131 (243) 5,667 Selling, general and administrative expenses 8 581 - 140 (6) 723 Exploration expenses - 1,231 - 684 - 1,915 Depreciation, depletion and amortization - 1,178 - 7,884 - 9,062 Impairments - 67 - 72 - 139 Taxes other than income taxes - 162 - 577 - 739 Accretion on discounted liabilities - 46 - 379 - 425 Interest and debt expense 506 622 207 570 (660) 1,245 Foreign currency transaction (gains) losses (19) 2 174 (176) - (19) Total Costs and Expenses 495 13,812 381 18,823 (3,621) 29,890 Loss before income taxes (3,757) (4,125) (161) (2,032) 4,545 (5,530) Income tax benefit (142) (774) (9) (1,046) - (1,971) Net loss (3,615) (3,351) (152) (986) 4,545 (3,559) Less: net income attributable to noncontrolling interests - - - (56) - (56) Net Loss Attributable to ConocoPhillips $ (3,615) (3,351) (152) (1,042) 4,545 (3,615) Comprehensive Loss Attributable to ConocoPhillips $ (3,561) (3,297) (27) (952) 4,276 (3,561) Millions of Dollars Year Ended December 31, 2015 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 11,473 - 18,091 - 29,564 Equity in earnings (losses) of affiliates (4,081) (1,950) - 1,364 5,322 655 Gain on dispositions - 332 - 259 - 591 Other income - 12 - 113 - 125 Intercompany revenues 74 341 246 3,365 (4,026) - Total Revenues and Other Income (4,007) 10,208 246 23,192 1,296 30,935 Costs and Expenses Purchased commodities - 9,905 - 5,838 (3,317) 12,426 Production and operating expenses - 1,469 - 5,585 (38) 7,016 Selling, general and administrative expenses 9 744 1 209 (10) 953 Exploration expenses - 2,093 - 2,099 - 4,192 Depreciation, depletion and amortization - 1,201 - 7,912 - 9,113 Impairments - 15 - 2,230 - 2,245 Taxes other than income taxes - 173 - 728 - 901 Accretion on discounted liabilities - 58 - 425 - 483 Interest and debt expense 485 423 226 447 (661) 920 Foreign currency transaction (gains) losses 114 1 (708) 518 - (75) Total Costs and Expenses 608 16,082 (481) 25,991 (4,026) 38,174 Income (loss) before income taxes (4,615) (5,874) 727 (2,799) 5,322 (7,239) Income tax provision (benefit) (187) (1,793) 21 (909) - (2,868) Net income (loss) (4,428) (4,081) 706 (1,890) 5,322 (4,371) Less: net income attributable to noncontrolling interests - - - (57) - (57) Net Income (Loss) Attributable to ConocoPhillips $ (4,428) (4,081) 706 (1,947) 5,322 (4,428) Comprehensive Income (Loss) Attributable to ConocoPhillips $ (8,773) (8,426) 71 (6,705) 15,060 (8,773)
Schedule of Condensed Balance Sheet	Millions of Dollars At December 31, 2017 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Assets Cash and cash equivalents $ - 234 4 6,087 - 6,325 Short-term investments - - - 1,873 - 1,873 Accounts and notes receivable 24 2,255 35 4,870 (2,864) 4,320 Investment in Cenovus Energy - 1,899 - - - 1,899 Inventories - 163 - 897 - 1,060 Prepaid expenses and other current assets 1 278 6 779 (29) 1,035 Total Current Assets 25 4,829 45 14,506 (2,893) 16,512 Investments, loans and long-term receivables* 29,400 47,974 2,533 15,050 (84,897) 10,060 Net properties, plants and equipment - 4,230 - 41,930 (477) 45,683 Other assets 15 1,146 186 1,302 (1,542) 1,107 Total Assets $ 29,440 58,179 2,764 72,788 (89,809) 73,362 Liabilities and Stockholders’ Equity Accounts payable $ - 3,094 1 3,799 (2,864) 4,030 Short-term debt (5) 2,505 7 77 (9) 2,575 Accrued income and other taxes - 107 - 931 - 1,038 Employee benefit obligations - 554 - 171 - 725 Other accruals 85 314 48 612 (30) 1,029 Total Current Liabilities 80 6,574 56 5,590 (2,903) 9,397 Long-term debt 3,787 9,321 1,703 2,794 (477) 17,128 Asset retirement obligations and accrued environmental costs - 432 - 7,199 - 7,631 Deferred income taxes - - - 6,263 (981) 5,282 Employee benefit obligations - 1,335 - 519 - 1,854 Other liabilities and deferred credits* 1,528 5,229 926 9,215 (15,629) 1,269 Total Liabilities 5,395 22,891 2,685 31,580 (19,990) 42,561 Retained earnings 22,867 13,317 (681) 11,958 (18,070) 29,391 Other common stockholders’ equity 1,178 21,971 760 29,056 (51,749) 1,216 Noncontrolling interests - - - 194 - 194 Total Liabilities and Stockholders’ Equity $ 29,440 58,179 2,764 72,788 (89,809) 73,362 Balance Sheet At December 31, 2016 Assets Cash and cash equivalents $ - 358 13 3,239 - 3,610 Short-term investments - - - 50 - 50 Accounts and notes receivable 22 1,968 23 6,103 (4,702) 3,414 Inventories - 84 - 934 - 1,018 Prepaid expenses and other current assets 2 116 8 415 (24) 517 Total Current Assets 24 2,526 44 10,741 (4,726) 8,609 Investments, loans and long-term receivables* 37,901 64,434 2,296 31,643 (114,602) 21,672 Net properties, plants and equipment - 6,301 - 52,030 - 58,331 Other assets 40 2,194 220 1,240 (2,534) 1,160 Total Assets $ 37,965 75,455 2,560 95,654 (121,862) 89,772 Liabilities and Stockholders’ Equity Accounts payable $ - 4,683 1 3,671 (4,702) 3,653 Short-term debt (10) 999 6 94 - 1,089 Accrued income and other taxes - 85 - 399 - 484 Employee benefit obligations - 489 - 200 - 689 Other accruals 171 271 40 536 (24) 994 Total Current Liabilities 161 6,527 47 4,900 (4,726) 6,909 Long-term debt 8,975 12,635 1,710 2,866 - 26,186 Asset retirement obligations and accrued environmental costs - 925 - 7,500 - 8,425 Deferred income taxes - - - 10,972 (2,023) 8,949 Employee benefit obligations - 1,901 - 651 - 2,552 Other liabilities and deferred credits* 417 10,391 748 17,832 (27,863) 1,525 Total Liabilities 9,553 32,379 2,505 44,721 (34,612) 54,546 Retained earnings 25,025 14,015 (541) 12,883 (19,834) 31,548 Other common stockholders’ equity 3,387 29,061 596 37,798 (67,416) 3,426 Noncontrolling interests - - - 252 - 252 Total Liabilities and Stockholders’ Equity $ 37,965 75,455 2,560 95,654 (121,862) 89,772 *Includes intercompany loans.
Condensed Consolidated Statement of Cash Flows	Millions of Dollars Year Ended December 31, 2017 Statement of Cash Flows ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ 71 1,183 (74) 8,931 (3,034) 7,077 Cash Flows From Investing Activities Capital expenditures and investments - (1,663) - (3,795) 867 (4,591) Working capital changes associated with investing activities - 194 - (62) - 132 Proceeds from asset dispositions 7,765 11,146 - 12,796 (17,847) 13,860 Net purchases of short-term investments - - - (1,790) - (1,790) Long-term advances/loans—related parties - (214) - (85) 299 - Collection of advances/loans—related parties 658 1,527 - 2,196 (4,266) 115 Intercompany cash management 1,151 101 - (1,252) - - Other - (8) - 44 - 36 Net Cash Provided by Investing Activities 9,574 11,083 - 8,052 (20,947) 7,762 Cash Flows From Financing Activities Issuance of debt - 20 65 214 (299) - Repayment of debt (5,459) (4,411) - (2,272) 4,266 (7,876) Issuance of company common stock 115 - - - (178) (63) Repurchase of company common stock (3,000) - - - - (3,000) Dividends paid (1,305) (235) - (2,977) 3,212 (1,305) Other 4 (7,765) - (9,331) 16,980 (112) Net Cash Provided by (Used in) Financing Activities (9,645) (12,391) 65 (14,366) 23,981 (12,356) Effect of Exchange Rate Changes on Cash and Cash Equivalents - 1 - 231 - 232 Net Change in Cash and Cash Equivalents - (124) (9) 2,848 - 2,715 Cash and cash equivalents at beginning of period - 358 13 3,239 - 3,610 Cash and Cash Equivalents at End of Period $ - 234 4 6,087 - 6,325 Statement of Cash Flows Year Ended December 31, 2016 Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (306) (322) (2) 5,903 (870) 4,403 Cash Flows From Investing Activities Capital expenditures and investments - (989) - (4,281) 401 (4,869) Working capital changes associated with investing activities - (126) - (205) - (331) Proceeds from asset dispositions 2,300 266 - 1,114 (2,394) 1,286 Net purchases of short-term investments - - - (51) - (51) Long-term advances/loans—related parties - (812) - - 812 - Collection of advances/loans—related parties - 391 1,250 272 (1,805) 108 Intercompany cash management (2,214) 1,433 - 781 - - Other - 1 - (3) - (2) Net Cash Provided by (Used in) Investing Activities 86 164 1,250 (2,373) (2,986) (3,859) Cash Flows From Financing Activities Issuance of debt 1,600 2,994 - 812 (812) 4,594 Repayment of debt (150) (164) (1,250) (2,492) 1,805 (2,251) Issuance of company common stock 148 - - - (211) (63) Repurchase of company common stock (126) - - - - (126) Dividends paid (1,253) - - (1,081) 1,081 (1,253) Other 1 (2,315) - 184 1,993 (137) Net Cash Provided by (Used in) Financing Activities 220 515 (1,250) (2,577) 3,856 764 Effect of Exchange Rate Changes on Cash and Cash Equivalents - (3) - (63) - (66) Net Change in Cash and Cash Equivalents - 354 (2) 890 - 1,242 Cash and cash equivalents at beginning of period - 4 15 2,349 - 2,368 Cash and Cash Equivalents at End of Period $ - 358 13 3,239 - 3,610 Millions of Dollars Year Ended December 31, 2015 Statement of Cash Flows ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities $ (225) 245 9 7,519 24 7,572 Cash Flows From Investing Activities Capital expenditures and investments - (3,064) - (8,386) 1,400 (10,050) Working capital changes associated with investing activities - (4) - (964) - (968) Proceeds from asset dispositions 3,500 826 - 1,225 (3,599) 1,952 Long-term advances/loans—related parties - (278) - (2,245) 2,523 - Collection of advances/loans—related parties - - - 205 (100) 105 Intercompany cash management 102 46 - (148) - - Other - 304 - 1 1 306 Net Cash Provided by (Used in) Investing Activities 3,602 (2,170) - (10,312) 225 (8,655) Cash Flows From Financing Activities Issuance of debt - 4,743 - 278 (2,523) 2,498 Repayment of debt - (100) - (103) 100 (103) Issuance of company common stock 283 - - (2) (363) (82) Dividends paid (3,664) - - (339) 339 (3,664) Other 4 (3,484) - 1,204 2,198 (78) Net Cash Provided by (Used in) Financing Activities (3,377) 1,159 - 1,038 (249) (1,429) Effect of Exchange Rate Changes on Cash and Cash Equivalents - - (1) (181) - (182) Net Change in Cash and Cash Equivalents - (766) 8 (1,936) - (2,694) Cash and cash equivalents at beginning of period - 770 7 4,285 - 5,062 Cash and Cash Equivalents at End of Period $ - 4 15 2,349 - 2,368

Schedule II (Tables)

Schedule II (Tables)	12 Months Ended
	Dec. 31, 2017
Valuation and Qualifying Accounts [Abstract]
Schedule Of Valuation And Qualifying Accounts Disclosure Table TextBlock	SCHEDULE II—VALUATION AND QUALIFYING ACCOUNTS (Consolidated) ConocoPhillips Millions of Dollars Balance at Charged to Balance at Description January 1 Expense Other (a) Deductions December 31 2017 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 5 2 - (3) (b) 4 Deferred tax asset valuation allowance 675 560 (c) 19 - 1,254 Included in other liabilities: Restructuring accruals 80 65 1 (93) (d) 53 2016 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 7 3 (1) (4) (b) 5 Deferred tax asset valuation allowance 734 (31) (12) (16) 675 Included in other liabilities: Restructuring accruals 156 129 1 (206) (d) 80 2015 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 5 4 (2) - (b) 7 Deferred tax asset valuation allowance 970 6 (21) (221) 734 Included in other liabilities: Restructuring accruals 61 303 (8) (200) (d) 156 (a)Represents acquisitions/dispositions/revisions and the effect of translating foreign financial statements. (b)Amounts charged off less recoveries of amounts previously charged off. (c)Includes an adjustment to the U.S. tax basis due to U.S. Tax Legislation. (d)Benefit payments.

Accounting Policies - Textuals

Accounting Policies - Textuals (Details)	12 Months Ended
	Dec. 31, 2017
Accounting Policies [Abstract]
Number of operating segments	6

Variable Interest Entities (V55

Variable Interest Entities (VIEs) (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Schedule Of Equity Method Investments [Line Items]
Equity investments	$ 9,129	$ 20,364
Debt at face value - letter of credit	$ 18,677	$ 26,175
MWCC Llc [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment	10.00%
MWCC Llc [Member] | MWCC Llc [Member]
Schedule Of Equity Method Investments [Line Items]
Term Loan Financing	$ 154
Equity investments	139
MWCC Llc [Member] | MWCC Llc [Member] | Line Of Credit [Member]
Schedule Of Equity Method Investments [Line Items]
Debt at face value - letter of credit	$ 22

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Inventory, Net [Abstract]
Crude oil and natural gas	$ 512	$ 418
Materials and supplies	548	600
Inventory Net	$ 1,060	$ 1,018

Inventory Disclosure - Narrativ

Inventory Disclosure - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Inventory, Net [Abstract]
Inventories valued on the LIFO basis	$ 341	$ 269
Excess of current replacement cost over LIFO cost of inventories	124	$ 104
Effect of LIFO Inventory Liquidation on Income	$ 1

Assets Held for Sale, Sold or58

Assets Held for Sale, Sold or Acquired Textuals (Details) $ / shares in Units, shares in Millions, CAD in Millions, $ in Millions	1 Months Ended							3 Months Ended		5 Months Ended	7 Months Ended	9 Months Ended	12 Months Ended
	Jan. 31, 2018USD ($)	Dec. 31, 2016USD ($)	Nov. 30, 2016USD ($)	Oct. 31, 2016USD ($)	Apr. 30, 2016USD ($)	Dec. 31, 2015USD ($)	Nov. 30, 2015USD ($)	Jun. 30, 2017USD ($)	Sep. 30, 2016USD ($)	May 17, 2017USD ($)shares	Jul. 31, 2017USD ($)	Sep. 29, 2017USD ($)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	May 17, 2017CAD	May 17, 2017USD ($)$ / shares
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Other income													$ 529	$ 255	$ 125
Equity Method Investments		$ 20,364											9,129	20,364
Income (Loss) From Equity Method Investments													772	52	655
Investment in Cenovus Energy		0												0
Alaska Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (Loss) From Equity Method Investments													7	9	4
Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (Loss) From Equity Method Investments													5	(6)	(5)
Canada Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (Loss) From Equity Method Investments													197	89	78
Other International Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (Loss) From Equity Method Investments													0	0	8
Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Income (Loss) From Equity Method Investments													553	(51)	550
Western Canadian Properties [Member] | Canada Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions						$ 130
Gain (Loss) on Sale of Oil and Gas Property						(235)
Net carrying value						365									365
Amount of PP&E in carrying value of asset						488									488
Western Canadian Properties [Member] | Canada Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold						126									126
Western Canadian Properties Alberta [Member] | Canada Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions							$ 198
Gain (Loss) on Sale of Oil and Gas Property							66
Net carrying value							132
Amount of PP&E in carrying value of asset							379
Western Canadian Properties Alberta [Member] | Canada Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold							$ 248
Western Canadian Properties Alberta [Member] | Canada Segment [Member] | Operating Segments [Member] | Canada Asset Exchange [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Gain (Loss) on Sale of Oil and Gas Property				$ (1)
Impairment of assets in exchange									$ 57
Fair value of assets exchanged				69
East Texas North Louisiana [Member] | Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions						412
Gain (Loss) on Sale of Oil and Gas Property						189
Net carrying value						223									223
Amount of PP&E in carrying value of asset						351									351
East Texas North Louisiana [Member] | Lower 48 Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold						128									128
South Texas Properties [Member] | Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions						358
Gain (Loss) on Sale of Oil and Gas Property						201
Net carrying value						157									157
Amount of PP&E in carrying value of asset						369									369
South Texas Properties [Member] | Lower 48 Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold						212									212
Texas Pipeline Gathering Assets [Member] | Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions						201
Gain (Loss) on Sale of Oil and Gas Property						193
Net carrying value						8									8
Amount of PP&E in carrying value of asset						24									24
Texas Pipeline Gathering Assets [Member] | Lower 48 Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold						18									18
Polar Lights Company [Member] | Other International Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions						98
Gain (Loss) on Sale of Oil and Gas Property						58
Net carrying value						$ 40									40
Beluga River Unit [Member] | Alaska Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions					$ 134
Gain (Loss) on Sale of Oil and Gas Property					56
Net carrying value					78
Amount of PP&E in carrying value of asset					100
Beluga River Unit [Member] | Alaska Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold					$ 19
Senegal [Member] | Other International Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions				442
Gain (Loss) on Sale of Oil and Gas Property				146
Net carrying value				$ 286
Block B [Member] | Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions			$ 225
Gain (Loss) on Sale of Oil and Gas Property			(26)
Net carrying value			251
Amount of PP&E in carrying value of asset			154
Amount of deferred taxes in carrying value of asset			54
Amount of Inventory in carrying value of asset			25
Amount of Accounts Receivable in carrying value			178
Total current liabilities of discontinued operations			130
Impairment of asset held for sale														42
Amount of Employee Benefit Obligations in carrying value			$ 38
Greater Northern Iron Ore Properties Trust [Member] | Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions		148
Gain (Loss) on Sale of Oil and Gas Property		4
Amount of PP&E in carrying value of asset		144												144
Other income		$ 88
Barnett [Member] | Lower 48 Segment [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Results Of Operations Income Before Income Taxes													(58)	(66)	(566)
Barnett [Member] | Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Net carrying value													291
Amount of PP&E in carrying value of asset													339
Impairment of asset held for sale													572
Barnett [Member] | Lower 48 Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold													48
Certain other properties [Member] | Lower 48 Segment [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Net carrying value													212
Impairment of asset held for sale													78
Certain other properties [Member] | Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions	$ 112
Amount of PP&E in carrying value of asset													238
Certain other properties [Member] | Lower 48 Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold													26
Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Canada Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions										$ 11,000
Shares Exchanged for Assets Held for Sale | shares										208
Assets Held for Sale, Contigent Consideration, Contingent Payment Based on Crude Oil Price per Barrel Trigger | CAD																CAD 6
Cenovus Energy common share price | $ / shares																	$ 9.41
Cenovus Energy Investment at Cost																	$ 1,960
Foster Creek Christina Lake (FCCL) [Member] | Canada Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Carrying Value of Equity Investment Sold										$ 8,900
Income (Loss) From Equity Method Investments													197	89	78
Western Canada Gas Properties [Member] | Canada Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Net carrying value																	1,900
Amount of PP&E in carrying value of asset																	2,600
Results Of Operations Income Before Income Taxes													(26)	(572)	(582)
AccrualForEnvironmentalLossContingencies																	100
Western Canada Gas Properties [Member] | Canada Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold																	$ 585
San Juan Basin [Member] | Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions											$ 2,500
Gain (Loss) on Sale of Oil and Gas Property											(22)
Net carrying value											2,500
Amount of PP&E in carrying value of asset											$ 2,900
Impairment of asset held for sale								$ 3,300
Assets Held for Sale, Contingent Consideration Term											due annually for the periods in which the monthly U.S. Henry Hub price is at or above $3.20 per million British thermal units.
Results Of Operations Income Before Income Taxes													(3,200)	(239)	(99)
Assets Held for Sale, Contingent Consideration, Henry Hub Price per Unit											$ 300
San Juan Basin [Member] | Lower 48 Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold											$ 406
Panhandle [Member] | Lower 48 Segment [Member] | Operating Segments [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Proceeds from asset dispositions												$ 178
Gain (Loss) on Sale of Oil and Gas Property												(28)
Net carrying value												206
Amount of PP&E in carrying value of asset												279
Results Of Operations Income Before Income Taxes													$ (14)	$ (21)	$ (41)
Panhandle [Member] | Lower 48 Segment [Member] | Operating Segments [Member] | Asset Retirement Obligation Costs [Member]
Income Statement Balance Sheet And Additional Disclosures By Disposal Groups Including Discontinued Operations [Line Items]
Asset Retirement Obligation of held for sale or sold												$ 72

Aquisitons (Details)

Aquisitons (Details) $ in Millions	1 Months Ended
	Jan. 28, 2018USD ($)
Certain Oil & Gas Assets [Member] | Alaska Segment [Member] | Operating Segments [Member] | Scenario Plan [Member]
Business Acquisition [Line Items]
Costs Incurred, Acquisition of Oil and Gas Properties, Total	$ 400

Investments, Loans and LT Recei

Investments, Loans and LT Receivables Components (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Components of investments, loans and long-term receivables
Equity investments	$ 9,129	$ 20,364
Loans and advances-related parties	461	581
Long-term receivables	375	631
Other investments	95	96
Total	$ 10,060	$ 21,672

Investments, Loans and LT Rec61

Investments, Loans and LT Receivables - Financial Info (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Equity Method Investment, Summarized Financial Information [Abstract]
Revenues	$ 11,554	$ 10,149	$ 11,003
Income before income taxes	(2,875)	660	1,866
Net income (loss)	(1,431)	799	$ 1,801
Current assets	2,920	3,578
Noncurrent assets	42,693	60,243
Current liabilities	2,453	2,352
Noncurrent liabilities	$ 25,522	$ 23,764

Investments, Loans and LT Rec62

Investments, Loans and LT Receivables Textuals (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Jun. 30, 2017	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	May 17, 2017	Oct. 31, 2016	Dec. 31, 2014	Dec. 31, 2012
Schedule Of Equity Method Investments [Line Items]
Retained Earning Equity Method			$ 20
Inercompany Distribution of Earnings			605	$ 398	$ 876
Equity investments			9,129	20,364
Foreign currency translation adjustments			(5,060)	(5,646)	(5,804)			$ (641)
Income (Loss) From Equity Method Investments			$ 772	52	655
Australia Pacific LNG [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment			37.50%
Total amount under revolving credit facilities									$ 8,500
Equity investments			$ 7,669
Historical cost basis			7,213
Difference between estimated value and book value of equity method investment			456
Amortizable portion of the basis difference in PPE			100	$ 92	21
Percent Decrease In Guarantee							60.00%
Line of Credit Facility, Remaining Borrowing Capacity			0
Before-Tax Loss - Equity method investments	$ 2,384				$ 1,502
Income (Loss) From Equity Method Investments			$ (2,384)
Australia Pacific LNG [Member] | Export-Import Bank of US [Member]
Schedule Of Equity Method Investments [Line Items]
Total amount under revolving credit facilities									2,900
Australia Pacific LNG [Member] | Export-Import Bank of China [Member]
Schedule Of Equity Method Investments [Line Items]
Total amount under revolving credit facilities									2,700
Australia Pacific LNG [Member] | Australian and International Commercial Bank Syndicate [Member]
Schedule Of Equity Method Investments [Line Items]
Total amount under revolving credit facilities									$ 2,900
Australia Pacific LNG [Member] | Origin Energy [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment			37.50%
Australia Pacific LNG [Member] | Sinopec [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment			25.00%
Deferred Tax Effect [Member]
Schedule Of Equity Method Investments [Line Items]
Income (Loss) From Equity Method Investments		$ 174
Foster Creek Christina Lake (FCCL) [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment				50.00%		0.00%
Foster Creek Christina Lake (FCCL) [Member] | Cenovus Energy Inc. [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment				50.00%		100.00%
QGC
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment			30.00%
Total amount under revolving credit facilities			$ 4,000
Equity investments			886
Loans to related parties			$ 581
Percentage Of Interest In Terminal And Pipeline Use Agreements			12.40%
QGC | Credit Agencies [Member]
Schedule Of Equity Method Investments [Line Items]
Total amount under revolving credit facilities			$ 1,300
QGC | Commerical Banks [Member]
Schedule Of Equity Method Investments [Line Items]
Total amount under revolving credit facilities			1,500
QGC | ConocoPhillips [Member]
Schedule Of Equity Method Investments [Line Items]
Total amount under revolving credit facilities			$ 1,200
QGC | Mitsui & Co, Ltd. [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment			1.50%
QGC | Qatar Petroleum [Member]
Schedule Of Equity Method Investments [Line Items]
Ownership percentage in equity investment			68.50%

Investment in Cenovus Energy (D

Investment in Cenovus Energy (Details) - USD ($) $ / shares in Units, $ in Thousands, shares in Millions	5 Months Ended	12 Months Ended
	May 17, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Available-for-sale Securities [Line Items]
Percent of Issued and common shares	16.90%
Cenovus Energy Investment at Fair Value			$ 0
Unrealized holding gain on securities, before and after tax		$ (58,000)	$ 0	$ 0
Common Stock [Member] | Cenovus Energy [Member]
Schedule of Available-for-sale Securities [Line Items]
Shares Exchanged for Assets Held for Sale	208
Cenovus Energy common share price	$ 9.41	$ 9.13
Cenovus Energy Investment at Fair Value		$ 1,900,000
Cenovus Energy Investment at Cost	$ 1,960,000
Unrealized holding gain on securities, before and after tax		$ (58,000)

Suspended Wells Net Changes in

Suspended Wells Net Changes in Well Costs (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Net changes in suspended Exploratory well costs
Beginning balance	$ 1,063,000,000	$ 1,260,000,000	$ 1,299,000,000
Additions pending the determination of proved reserves	118,000,000	225,000,000	331,000,000
Reclassifications to proved properties	(66,000,000)	(27,000,000)	(28,000,000)
Sales of suspended well investment	0	(247,000,000)	0
Charged to dry hole expense	(262,000,000)	(148,000,000)	(342,000,000)
Ending balance	$ 853,000,000	$ 1,063,000,000	$ 1,260,000,000

Suspended Wells - Aging of susp

Suspended Wells - Aging of suspended well balances (Details)	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Aging of suspended well cost
Exploratory well costs capitalized for a period of one year or less	$ 67,000,000	$ 132,000,000	$ 235,000,000
Exploratory well costs capitalized for a period greater than one year	786,000,000	931,000,000	1,025,000,000
Ending balance	$ 853,000,000	$ 1,063,000,000	$ 1,260,000,000	$ 1,299,000,000
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year	23	26	28

Suspended Wells-Exploratory Cap

Suspended Wells-Exploratory Capitalized Well Costs (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	$ 786	$ 931	$ 1,025
2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	360
2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	273
2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	153
Greater Poseidon-Australia [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	177
Greater Poseidon-Australia [Member] | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	63
Greater Poseidon-Australia [Member] | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	102
Greater Poseidon-Australia [Member] | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	12
Greater Clair-UK [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	144
Greater Clair-UK [Member] | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	99
Greater Clair-UK [Member] | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	45
Greater Clair-UK [Member] | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Surmont - Canada
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	117
Surmont - Canada | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	34
Surmont - Canada | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	59
Surmont - Canada | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	24
NPR-A-Alaska [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	114
NPR-A-Alaska [Member] | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	66
NPR-A-Alaska [Member] | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	42
NPR-A-Alaska [Member] | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	6
Caldita/Barossa-Australia [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	77
Caldita/Barossa-Australia [Member] | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Caldita/Barossa-Australia [Member] | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Caldita/Barossa-Australia [Member] | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	77
Middle Magdalena Basin-Columbia
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	48
Middle Magdalena Basin-Columbia | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	48
Middle Magdalena Basin-Columbia | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Middle Magdalena Basin-Columbia | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Bohai-China
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	19
Bohai-China | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	19
Bohai-China | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Bohai-China | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Kamunsu East-Malaysia
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	19
Kamunsu East-Malaysia | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Kamunsu East-Malaysia | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	19
Kamunsu East-Malaysia | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
NC 98-Libya
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	15
NC 98-Libya | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	11
NC 98-Libya | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
NC 98-Libya | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	4
Sunrise-Australia[Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	13
Sunrise-Australia[Member] | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Sunrise-Australia[Member] | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	0
Sunrise-Australia[Member] | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	13
Other of $10 million or less each [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	43
Other of $10 million or less each [Member] | 2013 -2015 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	20
Other of $10 million or less each [Member] | 2010-2012 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	6
Other of $10 million or less each [Member] | 2002-2009 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	$ 17

Suspended Wells-Exploration Exp

Suspended Wells-Exploration Expense (Details) - USD ($)	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		$ 938,000,000	$ 1,915,000,000	$ 4,192,000,000
Lower 48 Segment [Member] | Operating Segments [Member] | Gulf of Mexico Ensco drillship
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense				335,000,000
Lower 48 Segment [Member] | Operating Segments [Member] | Gulf of Mexico deepwater drillship
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			$ 146,000,000
Lower 48 Segment [Member] | Operating Segments [Member] | Gulf of Mexico Ensco drillship capitalized costs [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense				$ 48,000,000
Angola | Other International Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	$ 43,000,000

Impairments (Details)

Impairments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 6,601	$ 139	$ 2,245
Alaska Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	180	1	10
Lower 48 Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	3,969	149	(2)
Canada Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	22	88	4
Europe and North Africa Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	46	(160)	724
Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	2,384	44	1,508
Corporate Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 0	$ 17	$ 1

Impairments Narratives (Details

Impairments Narratives (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 6,601	$ 139	$ 2,245
Exploration Expense	938	1,915	4,192
Alaska Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	180	1	10
Alaska Segment [Member] | Non Operated Producing Property [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	180
Alaska Segment [Member] | Chukchi Member [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			575
Lower 48 Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	3,969	149	(2)
Lower 48 Segment [Member] | Certain Developed Properties [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	3,969
Lower 48 Segment [Member] | Shenandoah Leasehold [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	51
Lower 48 Segment [Member] | Mineral Assets [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	38
Lower 48 Segment [Member] | Eagleford And Other Changes [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges		149
Lower 48 Segment [Member] | Gibson Tiber [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		203
Lower 48 Segment [Member] | Melmar [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		95
Lower 48 Segment [Member] | Gulf of Mexico [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		79	399
Canada Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	22	88	4
Exploration Expense		31
Canada Segment [Member] | Certain Developed Properties [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges		88
Canada Segment [Member] | Cancelled Project [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	22
Exploration Expense		31
Canada Segment [Member] | Duvernay Thornbury Saleski Crow Lake [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			102
Europe and North Africa Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	46	(160)	724
Europe and North Africa Segment [Member] | Certain Projects In Europe And NorthAfrica [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	46
Europe and North Africa Segment [Member] | United Kingdom Activity [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges		(160)	724
Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	2,384	44	1,508
Asia Pacific and Middle East Segment [Member] | Australia Pacific LNG [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	2,384
Asia Pacific and Middle East Segment [Member] | Block B [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges		44
Asia Pacific and Middle East Segment [Member] | Palangkaraya [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			105
Other International Segment [Member] | Block 36 [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			377
Other International Segment [Member] | Block 37 [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			116
CorporateMember | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 0	17	$ 1
CorporateMember | Office Buildings [Member] | Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges		$ 17

Asset Retirement Obligations 70

Asset Retirement Obligations and Accrued Environmental Costs (Details) - USD ($) $ in Millions		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Asset retirement obligations and accrued environmental costs
Asset retirement obligations		$ 7,798	$ 8,405	$ 9,911
Accrued environmental costs		180	247
Total asset retirement obligations and accrued environmental costs		7,978	8,652
Asset retirement obligations and accrued environmental costs due within one year	[1]	347	227
Total asset retirement obligations and accrued environmental costs		$ 7,631	$ 8,425
[1]	*Classified as a current liability on the balance sheet under "Other accruals."

Asset Retirement Obligations 71

Asset Retirement Obligations and Accrued Environmental Costs - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Changes in overall asset retirement obligation changed
Balance at January 1	$ 8,405	$ 9,911
Accretion of discount	358	420
New obligations	113	180
Changes in estimates of existing obligations	(150)	(1,197)
Spending on existing obligations	(152)	(314)
Property dispositions	(1,065)	(150)
Foreign currency translation	289	(445)
Balance at December 31	$ 7,798	$ 8,405

Asset Retirement Obligations 72

Asset Retirement Obligations and Accrued Environmental Costs - Textuals (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Environmental Liabilities [Line Items]
Accrued environmental costs	$ 180	$ 247
Additional Asset Retirement Obligations and Accrued Environmental Costs (Textual) [Abstract]
Expected expenditures for acquired environmental obligations, weighted-average discount factor rate	5.00%
Accrued environmental costs, undiscounted due within one year	$ 12
Accrued environmental costs, undiscounted due within second year	10
Accrued environmental costs, undiscounted due within three year	5
Accrued environmental costs, undiscounted due within fourth year	10
Accrued environmental costs, undiscounted due within fifth year	3
Accrued environmental costs, undiscounted due after fifth year	106
Cleanup Remediation Activities [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	105	183
Corporate and Other Environmental Liabilities [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	60	51
Federal Comprehensive Environmental Response Compensation and Liability Act or Similar State Laws [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	$ 15	$ 13

Debt (Details)

Debt (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Long-term debt
Debt Instrument, Face Amount	$ 18,677	$ 26,175
Capitalized leases	774	852
Net unamortized premiums and discounts	252	248
Total debt	19,703	27,275
Short-term debt	(2,575)	(1,089)
Long-term debt	17,128	26,186
Variable rate debt bonds [Member]
Long-term debt
Debt Instrument, Face Amount	283
Long-term debt	283	283
9.125% Debentures [Member] | Due 2021 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	150	150
8.20% Debentures [Member] | Due 2025 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	150	150
8.125% Notes [Member] | Due 2030 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	600	600
7.9% Debentures [Member] | Due 2047 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	100	100
7.8% Debentures [Member] | Due 2027 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	300	300
7.65% Debentures [Member] | Due 2023 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	88	88
7.40% Notes [Member] | Due 2031 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	500	500
7.375% Debentures [Member] | Due 2029 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	92	92
7.25% Notes [Member] | Due 2031 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	500	500
7.20% Notes [Member] | Due 2031 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	575	575
7% Debentures [Member] | Due 2029 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	200	200
6.95% Notes [Member] | Due 2029 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	1,549	1,549
6.875% Debentures [Member] | Due 2026 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	67	67
6.65% Debentures [Member] | Due 2018 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	0	297
6.50% Notes [Member] | Due 2039 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	2,750	2,750
6.00% Notes [Member] | Due 2020 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	0	1,000
5.951% Notes [Member] | Due 2037 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	645	645
5.95% Notes [Member] | Due 2036 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	500	500
5.95% Notes [Member] | Due 2046 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	500	500
5.90% Notes [Member] | Due 2032 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	505	505
5.90% Notes [Member] | Due 2038 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	600	600
5.75% Notes [Member] | Due 2019 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	0	2,250
5.20% Notes [Member] | Due 2018 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	0	500
4.95% Notes [Member] | Due 2026 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	1,250	1,250
4.3% Notes [Member] | Due 2044 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	750	750
4.2% Notes [Member] | Due 2018 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	1,000	1,250
4.2% Notes [Member] | Due 2021 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Debt Instrument, Face Amount	1,000	1,250
4.15% Notes [Member] | Due 2034 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	500	500
3.35% Notes [Member] | Due 2024 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	1,000	1,000
3.35% Notes [Member] | Due 2025 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	500	500
2.875% Notes [Member] | Due 2018 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	750	750
2.4% Notes [Member] | Due 2022 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	1,000	1,000
2.2% Notes [Member] | Due 2018 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	500	500
1.5% Notes [Member] | Due 2018 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	0	750
1.05% Notes [Member] | Due 2017 [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	0	1,000
Floating rate term loan due 2019 [Member} | Due 2019 [Member] | Floating Rate Term Loan [Member]
Long-term debt
Long-term debt	$ 0	$ 1,450
Floating rate term loan due 2019 [Member} | Due 2019 [Member] | Floating Rate Term Loan [Member] | Minimum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	2.31%	1.94%
Floating rate term loan due 2019 [Member} | Due 2019 [Member] | Floating Rate Term Loan [Member] | Maximum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	2.75%	2.31%
Floating rate note due 2018 [Member] | Due 2018 [Member] | Floating Rate Notes [Member]
Long-term debt
Long-term debt	$ 250	$ 250
Floating rate note due 2018 [Member] | Due 2018 [Member] | Floating Rate Notes [Member] | Minimum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	1.24%	0.69%
Floating rate note due 2018 [Member] | Due 2018 [Member] | Floating Rate Notes [Member] | Maximum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	1.75%	1.24%
Floating Rate Notes Due 2022 [Member] | Due 2020 [Member] | Floating Rate Notes [Member] | Minimum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	1.81%	1.26%
Floating Rate Notes Due 2022 [Member] | Due 2020 [Member] | Floating Rate Notes [Member] | Maximum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	2.32%	1.81%
Floating Rate Notes Due 2022 [Member] | Due 2022 [Member] | Floating Rate Notes [Member]
Long-term debt
Long-term debt	$ 500	$ 500
Industrial Development Bonds Due One [Member] | Variable rate debt bonds [Member]
Long-term debt
Long-term debt	$ 18	$ 18
Industrial Development Bonds Due One [Member] | Variable rate debt bonds [Member] | Minimum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	0.64%	0.01%
Industrial Development Bonds Due One [Member] | Variable rate debt bonds [Member] | Maximum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	1.74%	0.91%
Marine Terminal Revenue Refunding Bonds [Member] | Variable rate debt bonds [Member] | Minimum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	0.64%	0.01%
Marine Terminal Revenue Refunding Bonds [Member] | Variable rate debt bonds [Member] | Maximum [Member]
Long-term debt
Debt Instrument, Interest Rate, Stated Percentage	1.74%	0.95%
Marine Terminal Revenue Refunding Bonds [Member] | Due 2031 [Member] | Variable rate debt bonds [Member]
Long-term debt
Long-term debt	$ 265	$ 265
Other Debt [Member] | Unsecured Debt (Debentures) [Member]
Long-term debt
Long-term debt	$ 23	$ 24

Debt Capital Lease (Details)

Debt Capital Lease (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Capital lease obligations
2,017	$ 108
2,018	106
2,019	106
2,020	88
2,021	88
Remaining years	487
Capital lease payments	983
Less portion representing imputed interest	(209)
Capital Lease Obligations, Total	$ 774	$ 852

Debt Narratives (Details)

Debt Narratives (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Debt (Textual) [Abstract]
Maturities of long-term borrowings in 2018	$ 2,575
Maturities of long-term borrowings in 2019	113
Maturities of long-term borrowings in 2020	97
Maturities of long-term borrowings in 2021	236
Maturities of long-term borrowings in 2022	1,602
Classification of short-term debt as long-term debt	0
Capital Leased Assets [Line Items]
Capital lease obligations	774	$ 852
Debt Instrument [Line Items]
Debt Instrument, Face Amount	18,677	26,175
Repayment of Debt	7,876	2,251	$ 103
Repayments Of Debt At Maturity	1,001
Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Total amount under revolving credit facilities	6,750
Line of Credit Facility, Remaining Borrowing Capacity	$ 6,750
Letter Of Credit [Member]
Short-term Debt [Line Items]
Maturity period of commercial paper (in days)	90
Letters of credit capacity	$ 500
Minimum limit of debt for cross default provision	200
Letters of credit issued	$ 0
Gumusut Lease [Member]
Capital Leased Assets [Line Items]
Capital lease, initial non-cancelable term	15 years
Capital lease, cancelable term	5 years
Capital lease, additional term	5 years
Capital lease obligations	$ 906
Incremental Borrowing Rate	3.58%
Capital Leased Assets Net	$ 434	540
Capital Leases Other Accumulated Depreciation	$ 381	268
Ownership percentage in equity investment	29.00%
Floating Rate Term Loan [Member] | Due 2019 [Member] | Floating rate term loan due 2019 [Member}
Debt Instrument [Line Items]
Repayment of Debt	$ 1,450
Unsecured Debt (Debentures) [Member]
Debt Instrument [Line Items]
Total Prepayments Of Debt	5,000
Premiums above book value	301
Unsecured Debt (Debentures) [Member] | Due 2017 [Member] | 1.05% Notes [Member]
Debt Instrument [Line Items]
Repayments Of Debt At Maturity	1,000
Unsecured Debt (Debentures) [Member] | Due 2018 [Member] | 6.65% Debentures [Member]
Debt Instrument [Line Items]
Repayment of Debt	297
Unsecured Debt (Debentures) [Member] | Due 2018 [Member] | 5.20% Notes [Member]
Debt Instrument [Line Items]
Repayment of Debt	500
Unsecured Debt (Debentures) [Member] | Due 2018 [Member] | 1.5% Notes [Member]
Debt Instrument [Line Items]
Repayment of Debt	750
Unsecured Debt (Debentures) [Member] | Due 2019 [Member] | 5.75% Notes [Member]
Debt Instrument [Line Items]
Repayment of Debt	2,250
Unsecured Debt (Debentures) [Member] | Due 2020 [Member] | 6.00% Notes [Member]
Debt Instrument [Line Items]
Repayment of Debt	1,000
Unsecured Debt (Debentures) [Member] | Due 2021 [Member] | 4.2% Notes [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	1,000	$ 1,250
Repayment of Debt	250
Unsecured Debt (Debentures) [Member] | Scenario Plan [Member]
Debt Instrument [Line Items]
Total Prepayments Of Debt	2,250
Premiums above book value	75
Unsecured Debt (Debentures) [Member] | Scenario Plan [Member] | Due 2020 [Member] | 2.2% Notes [Member]
Debt Instrument [Line Items]
Repayment of Debt	500
Unsecured Debt (Debentures) [Member] | Scenario Plan [Member] | Due 2021 [Member] | 4.2% Notes [Member]
Debt Instrument [Line Items]
Repayment of Debt	1,000
Unsecured Debt (Debentures) [Member] | Scenario Plan [Member] | Due 2021 [Member] | 2.875% Notes [Member]
Debt Instrument [Line Items]
Repayment of Debt	750
ConocoPhilips Commerical Paper Program [Member] | Letter Of Credit [Member]
Short-term Debt [Line Items]
Commercial paper program	6,250
Commercial paper outstanding	0
ConocoPhillips Qatar Funding Ltd [Member] | Letter Of Credit [Member]
Short-term Debt [Line Items]
Commercial paper program	500
Commercial paper outstanding	$ 0

Guarantees Textual (Details)

Guarantees Textual (Details)	12 Months Ended
	Dec. 31, 2017USD ($)
Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Equity Interest Of Others	37.50%
Australia Pacific LNG [Member] | Construction Contracts [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Current Carrying Value	$ 0
Continued development [Member] | Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 150,000,000
Terms of Guarantees Outstanding	up to 28 years
Other Guarantees [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 780,000,000
Terms of Guarantees Outstanding	up to 5 years
Indemnification [Member]
Guarantor Obligations [Line Items]
Accrual for Environmental Loss Contingencies	$ 40,000,000
Carrying value of indemnification asset	$ 100,000,000
Guarantee existing sales agreement of natural gas delivery | Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Terms of Guarantees Outstanding	up to 24 years
Guarantee existing sales agreement of natural gas delivery | Refinery Supplier [Member]
Guarantor Obligations [Line Items]
Terms of Guarantees Outstanding	seven years
Guarantor Obligations, Current Carrying Value	$ 98,000,000
Carrying value of indemnification asset	98,000,000
Max potential future payments-reckless breach [Member] | Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	1,710,000,000
Max potential future payments-prorata share [Member] | Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 960,000,000
Max potential future payments-prorata share [Member] | Refinery Supplier [Member]
Guarantor Obligations [Line Items]
Terms of Guarantees Outstanding	1,310,000,000
Finance Reserve Guarantee [Member] | Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 200,000,000
Terms of Guarantees Outstanding	12 years
Carrying value of indemnification asset	$ 14,000,000

Contingencies and Commitments (

Contingencies and Commitments (Details) - USD ($) $ in Millions	1 Months Ended			12 Months Ended
	Apr. 30, 2018	Dec. 31, 2017	Feb. 28, 2017	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Long-Term Throughput Agreements and Take-or-Pay Agreements [Abstract]
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due Within One Year		$ 21		$ 21
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Second Year		7		7
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Third Year		7		7
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Fourth Year		7		7
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Fifth Year		7		7
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due after Fifth Year		74		74
Total payments under Long-Term Throughput Agreements and Take-or-Pay Agreements		43		43	$ 42	$ 27
Burlington Resources Inc Vs The Republic Of Ecuador [Member] | Burlington Resources Inc [Member] | Ecuador
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party			$ 380	$ 337
Litigation Settlement, Amount Awarded to Other Party			$ 42
Loss Contingency Settlement Agreement Terms				two installments
Settlement Amount Received From Other Party		75
Burlington Resources Inc Vs The Republic Of Ecuador [Member] | Burlington Resources Inc [Member] | Ecuador | Scenario Plan [Member]
Loss Contingencies [Line Items]
Settlement Amount Received From Other Party	$ 262
Settlement Amount Awarded To Other Party Through Third Party				$ 24
Performance Guarantee [Member]
Loss Contingencies [Line Items]
Letters of Credit Outstanding, Amount		$ 338		$ 338

Derivative and Financial Inst78

Derivative and Financial Instruments - Commodity Balance Sheet (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	$ 275	$ 268
Other assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	36	44
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	282	300
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	$ 28	$ 34

Derivative and Financial Inst79

Derivative and Financial Instruments - Commodity GainLoss (Details) - Commodity Contract [Member] - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Sales and other operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ 77,000,000	$ (198,000,000)	$ 231,000,000
Other Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	0	(1,000,000)	2,000,000
Purchased commodities [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (61,000,000)	$ 161,000,000	$ (201,000,000)

Derivative and Financial Inst80

Derivative and Financial Instruments - Commodity Notional (Details) - Commodity Contract [Member] - ft3 ft3 in Billions	Dec. 31, 2017	Dec. 31, 2016
Natural gas and power, Fixed price [Member] | Short [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	(29)	(31)
Natural gas and power, Basis [Member] | Long [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	(12)	(2)

Derivative and Financial Inst81

Derivative and Financial Instruments - FX Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	$ 1	$ 1
Other assets [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	6	0
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	0	168
Foreign currency exchange derivative liabilities	15	0
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	$ 15	$ 0

Derivative and Financial Inst82

Derivative and Financial Instruments - FX Derivative (Details)	12 Months Ended
	Dec. 31, 2017
Derivative and Financial Instruments [Abstract]
Description of Foreign Currency Derivative Instruments Not Designated as Hedging Instruments Activities	In December 2017, we entered into foreign exchange zero cost collars buying the right to sell $1.25 billion CAD at $0.707 CAD and selling the right to buy $1.25 billion CAD at $0.842 CAD against the U.S. dollar.

Derivative and Financial Inst83

Derivative and Financial Instruments - FX GainLoss (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Foreign currency transaction (gains) losses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Foreign currency transaction (gains) losses	$ 13	$ 247	$ (33)

Derivative and Financial Inst84

Derivative and Financial Instruments - FX Notional (Details) - Not Designated as Hedging Instrument [Member] - USD ($)	Dec. 31, 2017	Dec. 31, 2016
Sell U.S. dollar, buy other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	$ 0	$ 13,000,000
Buy U.S. dollar, sell other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	0	25,000,000
Buy British pound, sell other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	0	1,069,000,000
Sell British pound, buy other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	1,000,000	51,000,000
Sell Canadian dollar, buy U.S. dollar [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	$ 1,225,000,000	$ 0

Derivative and Financial Inst85

Derivative and Financial Instruments - Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	$ 6,325	$ 3,610	$ 2,368	$ 5,062
Short-term Investments	1,873	50
Cash [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	948	623
Short-term Investments	0	0
Bank Time Deposits [Member] | RemainingMaturities1To90Days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	5,004	2,987
Short-term Investments	821	39
Bank Time Deposits [Member] | RemainingMaturities91To180Days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	0	0
Short-term Investments	0	11
Commercial Paper [Member] | RemainingMaturities1To90Days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	373	0
Short-term Investments	978	0
Commercial Paper [Member] | RemainingMaturities91To180Days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents	0	0
Short-term Investments	$ 74	$ 0

Derivative and Financial Inst86

Derivative and Financial Instruments - Textuals (Details)	12 Months Ended
	Dec. 31, 2017
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Credit Derivative, Recourse Provisions	Certain of our derivative instruments contain provisions that require us to post collateral if the derivative exposure exceeds a threshold amount. We have contracts with fixed threshold amounts and other contracts with variable threshold amounts that are contingent on our credit rating. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically revert to zero if we fall below investment grade. Cash is the primary collateral in all contracts; however, many also permit us to post letters of credit as collateral, such as transactions administered through the New York Mercantile Exchange.
Trade receivables [Member] | Maximum [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Terms of financial instruments and trade receivables	30 days

Fair Value Measurement - FV Hie

Fair Value Measurement - FV Hierarchy (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy		$ 0
Commodity derivative asset, gross	$ 311	312
Commodity derivative liability, gross	310	334
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy		0
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	0
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	0
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	1,899
Commodity derivative asset, gross	311	312
Total assets	2,210	312
Commodity derivative liability, gross	310	334
Total liabilities	$ 310	334
Level 1 To Level 2 Transfers Description	investment in Cenovus Energy
Level 1 To Level 2 Transfers Amount	$ 1,899
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	1,899
Commodity derivative asset, gross	175	194
Total assets	2,074	194
Commodity derivative liability, gross	158	207
Total liabilities	158	207
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative asset, gross	106	96
Total assets	106	96
Commodity derivative liability, gross	111	105
Total liabilities	111	105
Fair Value, Measurements, Recurring [Member] | Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative asset, gross	30	22
Total assets	30	22
Commodity derivative liability, gross	41	22
Total liabilities	$ 41	$ 22

Fair Value Measurement - FV of

Fair Value Measurement - FV of Commodity Derivatives (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Offsetting Derivative Assets [Abstract]
Assets - gross amounts recognized	$ 311	$ 312
Assets - gross amounts offset	186	221
Assets - net amounts presented	125	91
Assets - cash collateral	0	0
Assets - amounts without right of setoff	4	5
Commodity derivatives, assets	121	86
Offsetting Derivative Liabilities [Abstract]
Liabilities - gross amounts recognized	310	334
Liabilities - gross amounts offset	186	221
Liabilities - net amounts presented	124	113
Liabilities - cash collateral	7	12
Liabilities - amounts without right of setoff	5	12
Commodity derivatives	$ 112	$ 89

Fair Value Measurement - Nonrec

Fair Value Measurement - Nonrecurring (Details) - Fair Value, Measurements, Nonrecurring [Member] - USD ($) $ in Millions	3 Months Ended	6 Months Ended		9 Months Ended	12 Months Ended
	Mar. 31, 2016	Jun. 30, 2017	Jun. 30, 2016	Sep. 30, 2016	Dec. 31, 2017	Dec. 31, 2016
Fair Value, Disclosure Item Amounts [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Before-Tax Loss - Net PP&E (held for use)	$ 129		$ 53		$ 154	$ 29
Before-Tax Loss - Net PP&E (held for sale)		$ 3,882		$ 99	78
Before-Tax Loss - Cost and Equity method investments		2,384				40
Fair Value - Net PP&E (held for use)	217		23		75	13
Fair Value- Net PP&E (held for sale)		2,830		217	113
Fair Value - Cost and Equity Method Investments		7,656				90
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for use)	0		0		0	0
Fair Value- Net PP&E (held for sale)		2,830		217	113
Fair Value - Cost and Equity Method Investments						4
Fair Value, Inputs, Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for use)	$ 217		$ 23		75	13
Fair Value- Net PP&E (held for sale)		0		$ 0	$ 0
Fair Value - Cost and Equity Method Investments		$ 7,656				$ 86

Fair Value Measurement - Fair V

Fair Value Measurement - Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Financial Assets
Investment in Cenovus Energy	$ 1,899
Commodity derivatives, assets	121	$ 86
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Commodity derivatives	112	89
Carrying Amount [Member]
Financial Assets
Investment in Cenovus Energy	1,899
Total loans and advances - related parties	586	701
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Total debt, excluding capital leases	18,929	26,423
Carrying Amount [Member] | Commodity Contract [Member]
Financial Assets
Commodity derivatives, assets	125	91
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Commodity derivatives	117	101
Fair Value [Member]
Financial Assets
Investment in Cenovus Energy	1,899
Total loans and advances - related parties	586	701
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Total debt, excluding capital leases	22,435	29,307
Fair Value [Member] | Commodity Contract [Member]
Financial Assets
Commodity derivatives, assets	125	91
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Commodity derivatives	$ 117	$ 101

Fair Value Measurement - Textua

Fair Value Measurement - Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule Of Equity Method Investments [Line Items]
Income (Loss) From Equity Method Investments	$ 772	$ 52	$ 655
Australia Pacific LNG [Member]
Schedule Of Equity Method Investments [Line Items]
Equity method investments, fair value	7,656
Income (Loss) From Equity Method Investments	(2,384)
Australia Pacific LNG [Member] | Fair Value, Inputs, Level 3 [Member]
Schedule Of Equity Method Investments [Line Items]
Equity method investments, fair value	7,656
Income (Loss) From Equity Method Investments	$ (2,384)

Equity - changes in shares of c

Equity - changes in shares of common stock (Details) - shares	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Common Stock [Member]
Changes in shares of common stock
Beginning Balance, Common Stock	1,782,079,107	1,778,226,388	1,773,583,368
Distributed under benefit plans	3,340,068	3,852,719	4,643,020
Ending Balance, Common Stock	1,785,419,175	1,782,079,107	1,778,226,388
Treasury Stock [Member]
Changes in shares of common stock
Beginning Balance, Common Stock	544,809,771	542,230,673	542,230,673
Repurchase of common stock	63,502,263	2,579,098	0
Ending Balance, Common Stock	608,312,034	544,809,771	542,230,673

Equity - Textuals (Details)

Equity - Textuals (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Mar. 29, 2017	Nov. 10, 2016
Equity [Abstract]
Preferred Stock, Authorized	500,000,000	500,000,000
Preferred Stock, Par or Stated Value Per Share	$ 0.01	$ 0.01
Preferred Stock, Shares Issued	0	0
Preferred Stock, Shares Outstanding	0	0
Stockholders' Equity Attributable to Noncontrolling Interest	$ 194	$ 252
Treasury Stock, Shares, Acquired	66,081,361
Payments for Repurchase of Common Stock	$ 3,000	$ 126	$ 0
Stock Repurchase Program Authorized				$ 3,000	$ 3,000

Non Mineral Leases (Details)

Non Mineral Leases (Details) $ in Millions	Dec. 31, 2017USD ($)
Future minimum rental payments due under noncancelable leases
2,018	$ 278
2,019	214
2,020	414
2,021	126
2,022	307
Remaining Years	209
Total	1,548
Less income from subleases	(11)
Net Minimum Operating Lease Payments	$ 1,537

Non-Mineral Leases - Operating

Non-Mineral Leases - Operating lease rental (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating lease rental expense
Total rentals	$ 264	$ 537	$ 432
Less sublease rentals	(20)	(10)	(9)
Operating Leases, Rent Expense, Total	$ 244	$ 527	$ 423

Employee Benefit Plans - Change

Employee Benefit Plans - Change in Benefit Obligations and Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Change in Benefit Obligation
Benefit obligation at January 1	$ 286
Benefit obligation at December 31	265	$ 286
U.S.
Change in Benefit Obligation
Recognition of termination benefits		14	$ 46
Pension Plans Defined Benefit [Member] | U.S.
Change in Benefit Obligation
Benefit obligation at January 1	3,416	3,772
Service cost	89	108	138
Interest cost	118	133	161
Plan participant contributions	0	0
Plan amendments	0	0
Actuarial (gain) loss	244	247
Benefits paid	(631)	(872)
Curtailment	0	14
Settlement	0	0
Recognition of termination benefits	0	14
Foreign currency exchange rate change	0	0
Benefit obligation at December 31	3,236	3,416	3,772
Change in Fair Value of Plan Assets
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	2,081	2,606
Actual return on plan assets	336	133
Company contributions	755	214
Plan participant contributions	0	0
Defined Benefit Plan Plan Assets Benefits Paid	(631)	(872)
Foreign currency exchange rate change	0	0
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	2,541	2,081	2,606
Funded Status	695	1,335
Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	3,445	3,321
Service cost	77	76	124
Interest cost	103	120	135
Plan participant contributions	2	3
Plan amendments	0	0
Actuarial (gain) loss	52	466
Benefits paid	(117)	(148)
Curtailment	0	10
Settlement	0	(46)
Recognition of termination benefits	0	1
Foreign currency exchange rate change	283	(358)
Benefit obligation at December 31	3,845	3,445	3,321
Change in Fair Value of Plan Assets
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	3,068	3,063
Actual return on plan assets	313	397
Company contributions	114	125
Plan participant contributions	2	3
Defined Benefit Plan Plan Assets Benefits Paid	(117)	(148)
Foreign currency exchange rate change	267	(372)
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	3,647	3,068	3,063
Funded Status	198	377
Other Postretirement Benefit Plans, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	286	352
Service cost	2	2	4
Interest cost	9	13	22
Plan participant contributions	23	24
Plan amendments	0	(27)
Actuarial (gain) loss	12	(14)
Benefits paid	(68)	(68)
Curtailment	0	3
Settlement	0	0
Recognition of termination benefits	0	0
Foreign currency exchange rate change	1	1
Benefit obligation at December 31	265	286	352
Change in Fair Value of Plan Assets
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	0	0
Actual return on plan assets	0	0
Company contributions	45	44
Plan participant contributions	23	24
Defined Benefit Plan Plan Assets Benefits Paid	(68)	(68)
Foreign currency exchange rate change	0	0
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	0	0	$ 0
Funded Status	$ 265	$ 286

Employee Benefit Plans - Chan97

Employee Benefit Plans - Change in Benefit Obligations (Details) (Parenthetical) - Pension Plans Defined Benefit [Member] - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
U.S.
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Accumulated Benefit Obligation	$ 3,076	$ 3,246
Foreign Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Accumulated Benefit Obligation	$ 3,404	$ 3,067

Employee Benefit Plans - Amount

Employee Benefit Plans - Amounts recognized in Balance Sheet And Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent liabilities	$ (1,854)	$ (2,552)
Pension Plans Defined Benefit [Member] | U.S.
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent assets	0	0
Current liabilities	(38)	(101)
Noncurrent liabilities	(657)	(1,234)
Total recognized	$ (695)	$ (1,335)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.55%	3.95%
Rate of compensation increase	4.00%	4.00%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	3.80%	3.90%
Expected return on plan assets	6.55%	7.00%
Rate of compensation increase	4.00%	4.00%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 588	$ 748
Unrecognized prior service cost (credit)	0	4
Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent assets	205	164
Current liabilities	(4)	(7)
Noncurrent liabilities	(399)	(534)
Total recognized	$ (198)	$ (377)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	2.80%	3.00%
Rate of compensation increase	3.75%	3.85%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	3.00%	3.95%
Expected return on plan assets	5.05%	5.45%
Rate of compensation increase	3.85%	4.05%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 358	$ 479
Unrecognized prior service cost (credit)	(16)	(20)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent assets	0	0
Current liabilities	(45)	(44)
Noncurrent liabilities	(220)	(242)
Total recognized	$ (265)	$ (286)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.30%	3.60%
Rate of compensation increase	0.00%	0.00%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	3.60%	3.75%
Expected return on plan assets	0.00%	0.00%
Rate of compensation increase	0.00%	0.00%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ (12)	$ (27)
Unrecognized prior service cost (credit)	$ (249)	$ (285)

Employee Benefit Plans - Source

Employee Benefit Plans - Sources of Change in Other Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Sources of change in other comprehensive income (loss)
Net actuarial gain (loss) arising during the period	$ 19	$ (481)	$ 592
Amortization of (gain) loss included in income	247	309	403
Net actuarial gain, Before-tax	266	(172)	995
Prior service (cost) credit arising during the period	2	23	301
Amortization of prior service cost (credit) included in net loss	(38)	(35)	(19)
Net prior service cost during the period	36	12	$ (282)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Sources of change in other comprehensive income (loss)
Net actuarial gain (loss) arising during the period	(12)	14
Amortization of (gain) loss included in income	(3)	(5)
Net actuarial gain, Before-tax	(15)	9
Prior service (cost) credit arising during the period	0	(27)
Amortization of prior service cost (credit) included in net loss	36	34
Net prior service cost during the period	(36)	(7)
Defined Benefit Plan Amounts That Will Be Amortized From Accumulated Other Comprehensive Income Loss In Next Fiscal Year [Abstract]
Unrecognized net actuarial loss (gain)	(1)
Unrecognized prior service cost (credit)	(34)
Pension Plans Defined Benefit [Member] | U.S.
Sources of change in other comprehensive income (loss)
Net actuarial gain (loss) arising during the period	(40)	(263)
Amortization of (gain) loss included in income	200	288
Net actuarial gain, Before-tax	160	25
Prior service (cost) credit arising during the period	0	0
Amortization of prior service cost (credit) included in net loss	(4)	(5)
Net prior service cost during the period	4	5
Defined Benefit Plan Amounts That Will Be Amortized From Accumulated Other Comprehensive Income Loss In Next Fiscal Year [Abstract]
Unrecognized net actuarial loss (gain)	59
Unrecognized prior service cost (credit)	0
Pension Plans Defined Benefit [Member] | Foreign Plan [Member]
Sources of change in other comprehensive income (loss)
Net actuarial gain (loss) arising during the period	71	(232)
Amortization of (gain) loss included in income	50	26
Net actuarial gain, Before-tax	121	(206)
Prior service (cost) credit arising during the period	(2)	4
Amortization of prior service cost (credit) included in net loss	6	6
Net prior service cost during the period	(4)	$ (10)
Defined Benefit Plan Amounts That Will Be Amortized From Accumulated Other Comprehensive Income Loss In Next Fiscal Year [Abstract]
Unrecognized net actuarial loss (gain)	36
Unrecognized prior service cost (credit)	$ (5)

Employee Benefit Plans - Compon

Employee Benefit Plans - Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Net periodic benefit cost of all defined benefit plans
Curtailments (gain) loss	$ 0
U.S.
Net periodic benefit cost of all defined benefit plans
Curtailments (gain) loss		$ (15)	$ (33)
Pension Plans Defined Benefit [Member]
Net periodic benefit cost of all defined benefit plans
Pension settlement losses	131	202	204
Pension Plans Defined Benefit [Member] | U.S.
Net periodic benefit cost of all defined benefit plans
Service cost	89	108	138
Interest cost	118	133	161
Expected return on plan assets	(132)	(149)	(201)
Amortization of prior service cost (credit)	4	5	6
Recognized net actuarial loss (gain)	69	86	115
Pension settlement losses	131	202	197
Curtailments (gain) loss	0	14	35
Net periodic benefit cost	279	399	451
Pension Plans Defined Benefit [Member] | Foreign Plan [Member]
Net periodic benefit cost of all defined benefit plans
Service cost	77	76	124
Interest cost	103	120	135
Expected return on plan assets	(158)	(147)	(164)
Amortization of prior service cost (credit)	(6)	(6)	(7)
Recognized net actuarial loss (gain)	50	26	82
Pension settlement losses	0	0	7
Curtailments (gain) loss	0	0	(4)
Net periodic benefit cost	66	69	173
Other Postretirement Benefit Plans, Defined Benefit [Member]
Net periodic benefit cost of all defined benefit plans
Service cost	2	2	4
Interest cost	9	13	22
Expected return on plan assets	0	0	0
Amortization of prior service cost (credit)	(36)	(34)	(17)
Recognized net actuarial loss (gain)	(3)	(2)	2
Pension settlement losses	0	0	0
Curtailments (gain) loss	0	1	2
Net periodic benefit cost	$ (28)	$ (20)	$ 13

Employee Benefit Plans - Fair v

Employee Benefit Plans - Fair values of pension plan assets (Details) - USD ($) $ in Millions	Dec. 31, 2017		Dec. 31, 2016	Dec. 31, 2015
Fair Value, Disclosure Item Amounts [Domain] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	$ 2,439		$ 1,972
Fair Value, Disclosure Item Amounts [Domain] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	3,636		3,057
Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	501		1,145
Pension Plans Defined Benefit [Member] | U.S.
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	2,541		2,081	$ 2,606
Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	3,331		2,788
Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	3,647		3,068	3,063
Other Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0	$ 0
Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	146		62
Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	175		646
Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | Non-US [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	178		342
Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	183		156
Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	457		407
Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	440		628
Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Non-US [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	315		428
Equity Securities [Member] | Portion at Net Asset Value [Member] | Pension Plans Defined Benefit [Member] | U.S. | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	805		410
Government (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets			38
Government (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	902		470
Corporate (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	2		57
Corporate (Debt Securities) [Member] | Portion at Net Asset Value [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	172		155
Agency and Mortgage Backed Securities(Debt Securities) [Member] | Portion at Net Asset Value [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	15		27
Debt Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	648		385
Debt Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	144		137
Debt Securities [Member] | Portion at Net Asset Value [Member] | Pension Plans Defined Benefit [Member] | U.S. | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	1,042		312
Cash and Cash Equivalents [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	111		48
Cash and Cash Equivalents [Member] | Portion at Net Asset Value [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	17		36
Cash and Cash Equivalents [Member] | Portion at Net Asset Value [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	24		11
Bank Time Deposits [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	3
Derivatives [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	5		18
Real Estate [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	123		111
Real Estate [Member] | Portion at Net Asset Value [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	74		69
Real Estate [Member] | Portion at Net Asset Value [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	94		76
Fair Value, Inputs, Level 1 [Member] | Fair Value, Disclosure Item Amounts [Domain] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	485		1,036
Fair Value, Inputs, Level 1 [Member] | Fair Value, Disclosure Item Amounts [Domain] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	2,212		1,997
Fair Value, Inputs, Level 1 [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	485		1,036
Fair Value, Inputs, Level 1 [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	2,212		1,997
Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	146		62
Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	161		632
Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | Non-US [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	178		342
Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	292		268
Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	440		628
Fair Value, Inputs, Level 1 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Non-US [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	315		428
Fair Value, Inputs, Level 1 [Member] | Government (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets			0
Fair Value, Inputs, Level 1 [Member] | Government (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	902		470
Fair Value, Inputs, Level 1 [Member] | Corporate (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 1 [Member] | Debt Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 1 [Member] | Debt Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	144		137
Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	111		48
Fair Value, Inputs, Level 1 [Member] | Bank Time Deposits [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	3
Fair Value, Inputs, Level 1 [Member] | Derivatives [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	5		18
Fair Value, Inputs, Level 1 [Member] | Real Estate [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Fair Value, Disclosure Item Amounts [Domain] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	2		92
Fair Value, Inputs, Level 2 [Member] | Fair Value, Disclosure Item Amounts [Domain] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	996	[1],[2]	680
Fair Value, Inputs, Level 2 [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	2		92
Fair Value, Inputs, Level 2 [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	996		680
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | Non-US [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	183		156
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	165		139
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Non-US [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Government (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets			38
Fair Value, Inputs, Level 2 [Member] | Government (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Corporate (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	2		54
Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	648		385
Fair Value, Inputs, Level 2 [Member] | Debt Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Bank Time Deposits [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0
Fair Value, Inputs, Level 2 [Member] | Derivatives [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 2 [Member] | Real Estate [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Fair Value, Disclosure Item Amounts [Domain] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	14		17
Fair Value, Inputs, Level 3 [Member] | Fair Value, Disclosure Item Amounts [Domain] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	123		111
Fair Value, Inputs, Level 3 [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	14		17
Fair Value, Inputs, Level 3 [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	123		111
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	14		14
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | U.S. | Non-US [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Equity Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Non-US [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Government (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets			0
Fair Value, Inputs, Level 3 [Member] | Government (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Corporate (Debt Securities) [Member] | Pension Plans Defined Benefit [Member] | U.S. | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		3
Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Equity Securities Common or Collective Trusts [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Cash and Cash Equivalents [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Bank Time Deposits [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0
Fair Value, Inputs, Level 3 [Member] | Derivatives [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0		0
Fair Value, Inputs, Level 3 [Member] | Real Estate [Member] | Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member] | Transfers And Servicing Of Financial Instruments [Domain]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	$ 123		$ 111
[1]	*In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets.
[2]	Excludes the participating interest in the annuity contract with a net asset value of $99 million and net payables related to security transactions of $14 million.

Employee Benefit Plans - Benefi

Employee Benefit Plans - Benefit payments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:
Compensation cost	$ 227	$ 272	$ 362
Tax benefit	76	$ 92	$ 123
Pension Plans Defined Benefit [Member] | U.S.
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:
2,018	383
2,019	302
2,020	290
2,021	286
2,022	291
2023-2027	1,247
Pension Plans Defined Benefit [Member] | Foreign Pension Plans, Defined Benefit [Member]
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:
2,018	122
2,019	141
2,020	135
2,021	144
2,022	144
2023-2027	780
Other Postretirement Benefit Plans, Defined Benefit [Member]
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:
2,018	40
2,019	37
2,020	34
2,021	31
2,022	28
2023-2027	$ 91

Employee Benefit Plans - Severa

Employee Benefit Plans - Severances (Details) - Short term supplemental unemployment benefits [Member] $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)
Supplemental Unemployment Benefits [Line Items]
Balance at December 31, 2017	$ 30
Employee Severance [Member]
Supplemental Unemployment Benefits [Line Items]
Balance at December 31, 2016	80
Accruals	65
Benefit payments	(93)
Foreign currency translation adjustments	1
Balance at December 31, 2017	$ 53

Employee Benefit Plans - Weight

Employee Benefit Plans - Weighted Average Assumptions (Details)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Assumptions used
Risk-free interest rate	2.24%	1.55%	1.79%
Dividend yield	4.00%	4.00%	4.00%
Volatility factor	28.12%	26.80%	23.32%
Expected life (years)	6 years 4 months 21 days	6 years 4 months 13 days	5 years 9 months 15 days

Employee Benefit Plans - Stock

Employee Benefit Plans - Stock option activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Summary of Stock Options Activity
Weighted-Average Exercise Price at the beginning of year	$ 52.14
Weighted-Average Exercise Price, granted	49.76
Weighted-Average Exercise Price, exercised	37.24
Weighted-Average Exercise Price, forfeited	48.55
Weighted-Average Exercise Price, expired or canceled	50.61
Weighted-Average Exercise Price at the end of year	52.18	$ 52.14
Weighted-Average Exercise Price, Vested	52.52
Weighted-Average Exercise Price, Exercisable	54.34
Weighted-Average Grant-Date Fair Value, granted	$ 9.18	$ 5.39	$ 9.54
Aggregate Intrinsic Value, outstanding at the beginning of the year	$ 128
Aggregate Intrinsic Value, exercised	4		$ 10
Aggregate Intrinsic Value, outstanding at the end of the year	177	$ 128
Aggregate Intrinsic Value, vested	162
Aggregate Intrinsic Value, exercisable	$ 101
Stock option, Outstanding at the beginning of year	23,712,112
Stock options, granted	2,670,200
Stock option, exercised	(360,396)
Stock option, forfeited	(50,696)
Stock option, expired or cancelled	(1,248,417)
Stock options, Outstanding at the end of year	24,722,803	23,712,112
Stock option, Vested	23,424,010
Stock option, Exercisable at End of Year	18,074,088

Employee Benefit Plans - Sto106

Employee Benefit Plans - Stock unit activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Summary of stock unit activity
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Number	18,074,088
Restricted Stock Units (RSUs) [Member]
Summary of stock unit activity
Stock Units, Outstanding Beginning of year	8,507,504
Stock Units, Granted	3,011,903
Stock Units, Forfeited	(372,871)
Stock Units, Issued/Settled	3,319,684
Stock Units, Outstanding End of year	7,826,852	8,507,504
Not Vested at End of Year	5,396,027
Weighted-Average Grant-Date Fair Value, beginning of year	$ 48.65
Weighted-Average Grant-Date Fair Value, Granted	48.77
Weighted-Average Grant-Date Fair Value, Forfeited	45.99
Weighted-Average Grant-Date Fair Value, ending of year	45.75	$ 48.65
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 45.58
Total Fair Value, Issued	$ 159	$ 191	$ 316

Employee Benefit Plans - Perfor

Employee Benefit Plans - Performance Share Stock Program (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Stock Settled Performance Share Program [Member]
Summary of Performance Share Program activity
Stock Units, Outstanding Beginning of year	3,889,524
Stock Units, Granted	30,953
Stock Units, Issued/Settled	(1,167,012)
Stock Units, Outstanding End of year	2,753,465	3,889,524
Not Vested at End of Year	67,083
Weighted-Average Grant-Date Fair Value, beginning of year	$ 51.93
Weighted-Average Grant-Date Fair Value, Granted	49.76
Weighted-Average Grant-Date Fair Value, ending of year	50.79	$ 51.93
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 48.17
Total Fair Value, Issued	$ 57	$ 17	$ 25
Cash Settled Performance Share Program [Member]
Summary of Performance Share Program activity
Stock Units, Outstanding Beginning of year	1,274,762
Stock Units, Granted	456,909
Stock Units, Issued/Settled	(517,138)
Stock Units, Outstanding End of year	1,214,533	1,274,762
Not Vested at End of Year	122,228
Weighted-Average Grant-Date Fair Value, beginning of year	$ 50.39
Weighted-Average Grant-Date Fair Value, Granted	49.76
Weighted-Average Grant-Date Fair Value, ending of year	55.19	$ 50.39
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 55.19
Total Fair Value, Issued	$ 24	$ 31	$ 6

Employee Benefit Plans - Restri

Employee Benefit Plans - Restricted shares and units (Details) - Restricted Stock Units (RSUs) [Member] - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Summary of aggregate activity of restricted shares and units
Stock Units, Outstanding Beginning of year	8,507,504
Stock Units, Granted	3,011,903
Stock Units, Forfeited	(372,871)
Stock Units, Issued/Settled	3,319,684
Stock Units, Outstanding End of year	7,826,852	8,507,504
Not Vested at End of Year	5,396,027
Weighted-Average Grant-Date Fair Value, beginning of year	$ 48.65
Weighted-Average Grant-Date Fair Value, Granted	48.77
Weighted-Average Grant-Date Fair Value, Forfeited	45.99
Weighted-Average Grant-Date Fair Value, ending of year	45.75	$ 48.65
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 45.58
Total Fair Value, Issued	$ 159	$ 191	$ 316
Discontinued Operations [Member]
Summary of aggregate activity of restricted shares and units
Stock Units, Outstanding Beginning of year	1,317,964
Stock Units, Granted	87,980
Stock Units, Forfeited	(24,486)
Stock Units, Issued/Settled	(80,418)
Stock Units, Outstanding End of year	1,301,040	1,317,964
Not Vested at End of Year	0
Weighted-Average Grant-Date Fair Value, beginning of year	$ 33.16
Weighted-Average Grant-Date Fair Value, Granted	48.87
Weighted-Average Grant-Date Fair Value, Forfeited	21.37
Weighted-Average Grant-Date Fair Value, ending of year	$ 32.66	$ 33.16
Total Fair Value, Issued	$ 4

Employee Benefits Plans (Detail

Employee Benefits Plans (Details Textual) - USD ($) shares in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan, Employer Matching Contribution, Percent			0.00%
Company contributions charged to expense for defined contribution plan	$ 51,000,000	$ 58,000,000	$ 109,000,000
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	(2,000,000)	(23,000,000)	(301,000,000)
Defined Benefit Plan Recognized Net Gain Loss Due To Curtailments	$ 0
Percent Amortized Of Unamortized Balance For Net Actuarial Gain And Losses	10.00%
Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension settlement losses	$ 131,000,000	202,000,000	204,000,000
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	0	0	0
Defined Benefit Plan, Actual Return on Plan Assets	0	0
Pension settlement losses	0	0	0
Defined Benefit Plan, Plan Amendments	0	(27,000,000)
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	0	27,000,000
Defined Benefit Plan Recognized Net Gain Loss Due To Curtailments	0	(1,000,000)	(2,000,000)
Defined Benefit Plan Special Termination Benefits	0	0
Post Sixty Five Retiree [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Plan Amendments	$ 27,000,000
Share-based Compensation Plan
Defined Benefit Plan Disclosure [Line Items]
Share Based Compensation Plan, number of shares authorized	79
Share-based Compensation Plan | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Deferred Compensation Arrangement with Individual, Maximum Contractual Term	10 years
Share-based Compensation Plan | Incentive Stock Options [Member]
Defined Benefit Plan Disclosure [Line Items]
Share Based Compensation Plan, number of shares authorized	40
Unfunded Plan [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation	$ 578,000,000	586,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation	503,000,000	496,000,000
Qualified Plan [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Projected Benefit Obligation	5,634,000,000	5,498,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Accumulated Benefit Obligation	5,226,000,000	5,145,000,000
Defined Benefit Plan, Pension Plans with Accumulated Benefit Obligations in Excess of Plan Assets, Aggregate Fair Value of Plan Assets	$ 5,113,000,000	4,208,000,000
U.S.
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan Maximum Annual Contributions Per Employee Percent	75.00%
Defined Contribution Plan, Employer Matching Contribution, Percent	1.00%
Defined Contribution Plan Employer Matching Contribution Percent Of Match	6.00%
Employer Matching Discretionary Contribution Percent	6.00%
Company contributions charged to expense for defined contribution plan	$ 51,000,000	58,000,000	109,000,000
Defined Benefit Plan Recognized Net Gain Loss Due To Curtailments		15,000,000	33,000,000
Defined Benefit Plan Special Termination Benefits		14,000,000	46,000,000
U.S. | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	2,541,000,000	2,081,000,000	2,606,000,000
Defined Benefit Plan Accumulated Benefit Obligation	3,076,000,000	3,246,000,000
Defined Benefit Plan, Actual Return on Plan Assets	336,000,000	133,000,000
Pension settlement losses	131,000,000	202,000,000	197,000,000
Defined Benefit Plan, Plan Amendments	0	0
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	0	0
Defined Benefit Plan Recognized Net Gain Loss Due To Curtailments	0	(14,000,000)	(35,000,000)
Defined Benefit Plan Special Termination Benefits	0	14,000,000
U.S. | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	$ 80,000,000
Number Of Investment Funds In Which Employee Can Contribute [Member]	34
U.S. | Pre 65 Retiree [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year	6.25%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	2,023
U.S. | Post Sixty Five Retiree [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate	5.00%
Defined Benefit Plan, Year that Rate Reaches Ultimate Trend Rate	2,018
Foreign Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Company contributions charged to expense for defined contribution plan	$ 35,000,000	44,000,000	55,000,000
Foreign Plan [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	3,647,000,000	3,068,000,000	3,063,000,000
Defined Benefit Plan Accumulated Benefit Obligation	3,404,000,000	3,067,000,000
Defined Benefit Plan, Actual Return on Plan Assets	313,000,000	397,000,000
Pension settlement losses	0	0	7,000,000
Defined Benefit Plan, Plan Amendments	0	0
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	2,000,000	(4,000,000)
Defined Benefit Plan Recognized Net Gain Loss Due To Curtailments	0	0	4,000,000
Defined Benefit Plan Special Termination Benefits	0	1,000,000
Foreign Plan [Member] | Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	$ 130,000,000
Europe [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Special Termination Benefits		$ 1,000,000	$ 78,000,000
Special pension termination benefits recoverable from partner		62.00%
Equity Securities [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets	43.00%
Debt Securities [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets	50.00%
Real Estate [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets	6.00%
Other Investments [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets	1.00%
Fair Value, Inputs, Level 3 [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan Accumulated Benefit Obligation	$ 166,000,000	$ 167,000,000
Fair Value, Inputs, Level 3 [Member] | Participating interest in annuity contract | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	99,000,000	121,000,000
Fair Value, Inputs, Level 3 [Member] | Debt Securities [Member] | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair values of our pension plan assets	265,000,000	$ 288,000,000
Fair Value, Inputs, Level 3 [Member] | U.S. | Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Benefit Obligation, Period Increase (Decrease)	(1,000,000)
Defined Benefit Plan, Actual Return on Plan Assets	$ (23,000,000)

Employee Benefits Plans (Det110

Employee Benefits Plans (Details Textual 1) - USD ($) $ / shares in Units, shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted	$ 9.18	$ 5.39	$ 9.54
Aggregate Intrinsic Value, exercised	$ 4		$ 10
Authorized common stock for compensation plan, maximum	79
Employee Stock Option [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-average remaining contractual term of outstanding options	5 years 6 months 7 days
Weighted-average remaining contractual term exercisable	4 years 6 months
Cash received from exercise of stock options	$ 13
Tax benefit from exercise of options	12
Unrecognized compensation cost from stock options	$ 5
Weighted average period of recognition of unvested options, in months	1 year 3 months 29 days
Stock Options Terms of Award	Stock options granted under the provisions of the Plan and prior plans permit purchase of our common stock at exercise prices equivalent to the average market price of ConocoPhillips common stock on the date the options were granted. The options have terms of 10 years and generally vest ratably, with one-third of the options awarded vesting and becoming exercisable on each anniversary date following the date of grant. Options awarded to certain employees already eligible for retirement vest within six months of the grant date, but those options do not become exercisable until the end of the normal vesting period
Employee Stock Option [Member] | Maximum [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Longest weighted-average period of recognition of unvested options, in months	2 years 1 month 13 days
Employee Stock Option [Member] | Share-based Compensation Plan
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-average remaining contractual term of outstanding options	5 years 6 months 7 days
Stock Options Vested [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-average remaining contractual term of outstanding options	5 years 4 months 10 days
Restricted Stock Units (RSUs) [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 32.15	$ 65.4
Unrecognized compensation cost from stock options	$ 93
Weighted average period of recognition of unvested options, in months	1 year 8 months 1 day
Total Fair Value, Issued	$ 159	$ 191	$ 316
Stock Options Terms of Award	Stock Unit Program—Generally, restricted stock units are granted annually under the provisions of the Plan. Restricted stock units granted prior to 2013 generally vest ratably in three equal annual installments beginning on the third anniversary of the grant date. Beginning in 2013, restricted stock units granted will vest in an aggregate installment on the third anniversary of the grant date. In addition, beginning in 2012, restricted stock units granted under the Plan for a variable long-term incentive program vest ratably in three equal annual installments beginning on the first anniversary of the grant date. Restricted stock units are also granted ad hoc to attract or retain key personnel, and the terms and conditions under which these restricted stock units vest vary by award. Upon vesting, the restricted stock units are settled by issuing one share of ConocoPhillips common stock per unit. Units awarded to retirement eligible employees vest six months from the grant date; however, those units are not issued as common stock until the earlier of separation from the company or the end of the regularly scheduled vesting period. Until issued as stock, most recipients of the restricted stock units receive a quarterly cash payment of a dividend equivalent that is charged to retained earnings. The grant date fair market value of these restricted stock units is deemed equal to the average ConocoPhillips stock price on the grant date. The grant date fair market value of units that do not receive a dividend equivalent while unvested is deemed equal to the average ConocoPhillips stock price on the grant date, less the net present value of the dividends that will not be received.
Restricted Stock Units (RSUs) [Member] | Maximum [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Longest weighted-average period of recognition of unvested options, in months	2 years 9 months
Performance Shares [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Unrecognized compensation cost from stock options	$ 1
Weighted average period of recognition of unvested options, in months	2 years
Performance Shares [Member] | Maximum [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Longest weighted-average period of recognition of unvested options, in months	3 years
Phillips 66 [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Unrecognized compensation cost from stock options	$ 0
Stock Settled Performance Share Program [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 33.13	$ 69.25
Total Fair Value, Issued	$ 57	$ 17	$ 25
Stock Options Terms of Award	For performance periods beginning before 2009, PSUs do not vest until the employee becomes eligible for retirement by reaching age 55 with five years of service, and restrictions do not lapse until the employee separates from the company. With respect to awards for performance periods beginning in 2009 through 2012, PSUs do not vest until the earlier of the date the employee becomes eligible for retirement by reaching age 55 with five years of service or five years after the grant date of the award, and restrictions do not lapse until the earlier of the employee’s separation from the company or five years after the grant date (although recipients can elect to defer the lapsing of restrictions until separation). We recognize compensation expense for these awards beginning on the grant date and ending on the date the PSUs are scheduled to vest. Since these awards are authorized three years prior to the grant date, for employees eligible for retirement by or shortly after the grant date, we recognize compensation expense over the period beginning on the date of authorization and ending on the date of grant. Until issued as stock, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to retained earnings. Beginning in 2013, PSUs authorized for future grants will vest, absent employee election to defer, upon settlement following the conclusion of the three-year performance period. We recognize compensation expense over the period beginning on the date of authorization and ending on the conclusion of the performance period. PSUs are settled by issuing one share of ConocoPhillips common stock per unit.
Cash Settled Performance Share Program [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 33.13	$ 69.25
PSU termination date	Dec. 31, 2016	Dec. 31, 2015
Unrecognized compensation cost from stock options	$ 2
Weighted average period of recognition of unvested options, in months	1 year 7 months 21 days
Longest weighted-average period of recognition of unvested options, in months	2 years 1 month 17 days
Total Fair Value, Issued	$ 24	$ 31	$ 6
Stock Options Terms of Award	In connection with and immediately following the separation of our Downstream businesses in 2012, grants of new PSUs, subject to a shortened performance period, were authorized. Once granted, these PSUs vest, absent employee election to defer, on the earlier of five years after the grant date of the award or the date the employee becomes eligible for retirement. For employees eligible for retirement by or shortly after the grant date, we recognize compensation expense over the period beginning on the date of authorization and ending on the date of grant. Otherwise, we recognize compensation expense beginning on the grant date and ending on the date the PSUs are scheduled to vest. These PSUs are settled in cash equal to the fair market value of a share of ConocoPhillips common stock per unit on the settlement date and thus are classified as liabilities on the balance sheet. Until settlement occurs, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to compensation expense. Beginning in 2013, PSUs authorized for future grants will vest upon settlement following the conclusion of the three-year performance period.
Other [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 40.36	$ 58.66
Total Fair Value, Issued		$ 2	$ 3

Income Taxes - Components of pr

Income Taxes - Components of provision (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Federal
Current	$ 79	$ (9)	$ (718)
Deferred	(3,046)	(1,634)	(1,443)
Foreign
Current	1,729	393	745
Deferred	(510)	(519)	(1,315)
State and local
Current	51	(135)	8
Deferred	(125)	(67)	(145)
Total provision (benefit) for income taxes	$ (1,822)	$ (1,971)	$ (2,868)

Income Taxes - Components of de

Income Taxes - Components of deferred tax liabilties and assets (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Deferred Tax Liabilities
Properties, plants and equipment, and intangibles	$ 9,692	$ 15,099
Investments in joint ventures (Liability)	0	933
Inventory	61	36
Deferred state income tax	178	203
Other	464	486
Total deferred tax liabilities	10,395	16,757
Deferred Tax Assets
Benefit plan accruals	786	1,280
Asset retirement obligations and accrued environmental costs	3,060	3,514
Investments in joint ventures (Asset)	57	0
Other financial accruals and deferrals	166	317
Loss and credit carryforwards	2,310	3,522
Other	152	250
Total deferred tax assets	6,531	8,883
Less valuation allowance	(1,254)	(675)
Net deferred tax assets	5,277	8,208
Total deferred tax liabilities	$ 5,118	$ 8,549

Income Taxes - Unrecognized Tax

Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Reconciliation of the beginning and ending unrecognized tax benefits
Unrecognized Tax Benefits, Balance at January 1	$ 381	$ 459	$ 442
Additions based on tax positions related to the current year	612	32	54
Additions for tax positions of prior years	109	19	4
Reductions for tax positions of prior years	(129)	(118)	(37)
Settlements	(5)	(9)	(4)
Lapse of statute	(86)	(2)	0
Unrecognized Tax Benefits, Balance at December 31	$ 882	$ 381	$ 459

Income Taxes - Carryforwards (D

Income Taxes - Carryforwards (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Income Taxes [Abstract]
U.S. foreign tax credits	$ 856
U.S. general business credits	227
State net operating losses and tax credits	420
Foreign net operating losses and tax credits	807
Total loss and credit carryforwards	2,310	$ 3,522
DTA Net of Valuation Allowance, U.S. foreign tax credits	567
DTA Net of Valuation Allowance, U.S. general business tax credits	227
DTA Net of Valuation Allowance, State net operating losses and tax credits	0
DTA Net of Valuation Allowance, Foreign net operating losses and tax credits	786
Total DTA, Net of Valuation Allowance, Tax Credits And Operating Loss Carryforwards	$ 1,580
Epiration date of U.S. foreign tax credits	2025-2027
Expiration date of U.S. general business credits	2036-2037
Expiration date of Foreign net operating losses and tax credits	Post 2,025

Income Taxes - U.S. and foreign

Income Taxes - U.S. and foreign income (loss) from continuing operations before income taxes, with a reconciliation of tax at the federal statutory rate with the provision for income taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes [Abstract]
Income (loss) before taxes - United States	$ (5,250)	$ (4,410)	$ (4,150)
Income Loss Before Income Taxes Foreign	2,635	(1,120)	(3,089)
Income (loss) before income taxes	(2,615)	(5,530)	(7,239)
Federal statutory income tax	(915)	(1,936)	(2,534)
Non-U.S. effective tax rates	625	361	301
Impact of U.S. tax legislation	(852)	0	0
Canada disposition	(1,277)	0	0
Recovery of outside basis	(962)	(60)	(491)
Adjustment to tax reserves	881	55	42
APLNG impairment	834	0	525
State income tax	(84)	(122)	(85)
Enhanded oil recovery credit	(68)	(62)	0
U. K Rate Change	0	(161)	(555)
Canada Rate Change	0	0	129
U.S. fair value election	0	0	(185)
Other	(4)	(46)	(15)
Total provision (benefit) for income taxes	$ (1,822)	$ (1,971)	$ (2,868)
Income (loss) before income taxes, United States, Percentage	200.80%	79.70%	57.30%
Income (loss) before income taxes, foreign, percentage	(100.80%)	20.30%	42.70%
Income (Loss) Before Income Taxes In Percent	100.00%	100.00%	100.00%
Federal statutory rate percentage	35.00%	35.00%	35.00%
Non US effective tax rates percentage	(23.90%)	(6.50%)	(4.20%)
Impact of U.S. tax legislation, percentage	32.60%	0.00%	0.00%
Canada disposition, percentage	48.80%	0.00%	0.00%
Recovery of outside basis, percentage	36.80%	1.10%	6.80%
Adjustment to tax reserves, percentage	(33.70%)	(1.00%)	(0.60%)
APLNG Impairment, percentage	(31.90%)	0.00%	(7.30%)
State income tax, percentage	3.20%	2.20%	1.20%
Enhanced oil recovery, percentage	2.60%	1.10%	0.00%
U.K. Rate Change	0.00%	2.90%	7.70%
Canada rate change, percentage	0.00%	0.00%	(1.80%)
U.S. Fair value election, percentage	0.00%	0.00%	2.60%
Other, percentage	0.20%	0.80%	0.20%
Effective Income Tax Rate, Continuing Operations, percetage	69.70%	35.60%	39.60%

Income Taxes - Textuals (Detail

Income Taxes - Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Examination [Line Items]
Deferred taxes Included in long-term assets	$ 164	$ 400
Deferred taxes Included in long-term liabilities	5,282	8,949
Undistributed Earnings of Foreign Subsidiaries	2,600
Unrecognized tax benefits that if recognized, would affect effective tax rate	882	359	$ 354
Impact of U.S. tax legislation	(852)	0	0
Impact of remeasurement of deferred taxes	(908)
One time tranisition tax	56
Tax impact of Canada disposition	(1,277)	0	0
Adjustment to tax reserves	881	55	42
U. K Rate Change	0	(161)	(555)
Canada Rate Change	0	0	129
U.S. fair value election	0	0	185
Estimated Tax Payable On Undistributed Unremitted Foreign Income	130
Interest and penalties (benefiting) charging earnings	0	(18)	11
Accrued liabilities for interest and penalties	54	54	79
Increase (decrease) in valuation allowance	579
Income Tax Expense (Benefit)	(1,822)	(1,971)	(2,868)
Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member]
Income Tax Examination [Line Items]
Tax impact of Canada disposition	(1,277)
Foster Creek Christina Lake (FCCL) and western Canada gas properties [Member] | Scenario Plan [Member]
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance	882
Income Tax Expense (Benefit)	(882)
Canada [Member]
Income Tax Examination [Line Items]
Canada Rate Change			129
Her Majesty's Revenue and Customs (HMRC) [Member]
Income Tax Examination [Line Items]
U. K Rate Change		(161)	(555)
Certain Jurisdictions Outside Of Domestic [Member]
Income Tax Examination [Line Items]
Worthless Security Deduction	$ 962	$ 60	$ 491

Accumulated Other Comprehens117

Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Defined Benefit Plans, Beginning Balance	$ (547)	$ (443)	$ (1,261)
Other Comprehensive Income (Loss), Defined Benefit Plans	(147)	104	(818)
Defined Benefit Plans, Ending Balance	(400)	(547)	(443)
Unrealized loss on securities, net of tax	(58)	0	0
Net Unrealized Gain on Securities, Ending Balance	(58)
Foreign Currency Translation, Beginning Balance	(5,646)	(5,804)	(641)
Other comprehensive income (loss), Foreign Currency Translation	586	158	(5,163)
Foreign Currency Translation, Ending Balance	(5,060)	(5,646)	(5,804)
Accumulated Other Comprehensive Income (loss), Beginning Balance	(6,193)	(6,247)	(1,902)
Other comprehensive income (loss), net of tax	675	54	(4,345)
Accumulated Other Comprehensive Income (loss), Ending Balance	$ (5,518)	$ (6,193)	$ (6,247)

Accumulated Other Comprehens118

Accumulated Other Comprehensive Income - Reclassifications out of other comprehensive income (loss) (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive (Income) Loss Reclassification Adjustment From AOCI Pension And Other Postretirement Benefit Plans, Net Of Tax	[1],[2]	$ (135)	$ (179)
Other Comprehensive (Income) Loss Reclassification Adjustment From AOCI Pension And Other Postretirement Benefit Plans, Tax		$ 74	$ 95
[1]	Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $74 $95
[2]	See Note 17—Employee Benefit Plans, for additional information.

Cash Flow Information (Details)

Cash Flow Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Increase in PP&E related to increase in asset retirement obligations		$ (37)	$ (1,017)	$ 402
Interest Paid, Net		1,163	1,151	920
Income Taxes Paid, Net	[1]	1,168	(318)	523
Payments for (Proceeds from) Short-term Investments [Abstract]
Short-term investments purchased		(6,617)	(1,753)
Short-term investments sold		4,827	1,702
Net Sales (Purchases) of Short-Term Investments		$ 1,790	$ 51	$ 0
[1]	Net of $585 million and $642 million in 2016 and 2015, respectively, related to refunds received rom the Internal Revenue Service.

Cash Flow Information - Parenth

Cash Flow Information - Parenthetical (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Cash Flow Information [Abstract]
Proceeds From Income Tax Refunds	$ 585	$ 642

Other Financial Information (De

Other Financial Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		$ 31	$ (26)	$ (64)
Incurred
Debt		1,114	1,279	1,130
Other		103	123	84
Interest Costs Incurred, Total		1,217	1,402	1,214
Capitalized		(119)	(157)	(294)
Expensed		1,098	1,245	920
Other Income
Interest income		112	57	45
Other, net		417	198	80
Other Nonoperating Income		529	255	125
Research and Development Expenditures - expensed		100	116	222
Shipping and Handling Costs	[1]	1,058	1,139	1,181
Alaska Segment [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		0	0	0
Lower 48 Segment [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		0	0	0
Lower 48 Segment [Member] | Operating Segments [Member]
Other Income
Interest income		0	0	0
Canada Segment [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		3	1	0
Europe and North Africa Segment [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		7	(7)	(22)
Europe and North Africa Segment [Member] | Operating Segments [Member]
Other Income
Interest income		2	2	2
Asia Pacific and Middle East Segment [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		23	(9)	(78)
Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]
Other Income
Interest income		9	8	6
Other International Segment [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		1	7	(9)
Other International Segment [Member] | Operating Segments [Member]
Other Income
Interest income		0	0	1
Corporate and Other [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		$ (3)	$ (18)	$ 45
[1]	*Amounts included in production and operating expenses.

Other Financial Information - P

Other Financial Information - Property, Plant and Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016
Properties, Plants And Equipment
Proved properties	$ 102,044	$ 119,970
Unproved properties	4,491	5,150
Other	3,896	6,286
Gross properties, plants and equipment	110,431	131,406
Accumulated depreciation	(64,748)	(73,075)
Properties, plants and equipment, net	$ 45,683	$ 58,331

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017		Dec. 31, 2016		Dec. 31, 2015
Related Party Transaction [Line Items]
Operating revenues and other income	$ 118		$ 133		$ 107
Purchases	97		101		99
Operating expenses and selling, general and administrative expenses	62		63		59
Affiliated Entity [Member]
Related Party Transaction [Line Items]
Net interest (income) expense *	$ (9)	[1]	$ (12)	[2]	$ (13)	[3]
[1]	*We paid interest to, or received interest from, various affiliates. See Note ##NILALTR—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.
[2]	*We paid interest to, or received interest from, various affiliates. See Note ##NILALTR—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.
[3]	*We paid interest to, or received interest from, various affiliates. See Note ##NILALTR—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Segment Disclosures - Analysis

Segment Disclosures - Analysis of Results by Operating Segment (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Sales and Operating Revenues by Segment
Sales and other operating revenues	$ 29,106	$ 23,693	$ 29,564
Operating Segments [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	29,106	23,693	29,564
Corporate and Other [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	104	169	312
Alaska Segment [Member] | Operating Segments [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	4,224	3,681	4,351
Lower 48 Segment [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	12,968	10,719	11,976
Lower 48 Segment [Member] | Operating Segments [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	12,964	10,702	11,913
Lower 48 Segment [Member] | Intersegment Elimination [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	(4)	(17)	(63)
Canada Segment [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	3,178	2,192	2,454
Canada Segment [Member] | Operating Segments [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	2,619	1,974	2,136
Canada Segment [Member] | Intersegment Elimination [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	(559)	(218)	(318)
Europe and North Africa Segment [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	5,181	3,462	6,110
Europe and North Africa Segment [Member] | Operating Segments [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	5,181	3,462	6,106
Europe and North Africa Segment [Member] | Intersegment Elimination [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	0	0	(4)
Asia Pacific and Middle East [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	4,014	3,705	4,746
Asia Pacific and Middle East [Member] | Operating Segments [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	4,014	3,705	4,745
Asia Pacific and Middle East [Member] | Intersegment Elimination [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	0	0	(1)
Other International Segment [Member] | Operating Segments [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	0	$ 0	$ 1
Certain refining company
Product Information [Line Items]
Sales Revenue	$ 3,000
Concentration Risk, Percentage	11.00%

Segment Disclosures - Depreciat

Segment Disclosures - Depreciation, Equity Earnings, Income Tax (Details) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	$ 13,446,000,000	$ 9,201,000,000	$ 11,358,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	772,000,000	52,000,000	655,000,000
Income Taxes
Total provision (benefit) for income taxes	(1,822,000,000)	(1,971,000,000)	(2,868,000,000)
Corporate and Other [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	134,000,000	140,000,000	107,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	0	(11,000,000)	(3,000,000)
Income Taxes
Total provision (benefit) for income taxes	399,000,000	(421,000,000)	(612,000,000)
Alaska Segment [Member] | Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	1,026,000,000	868,000,000	690,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	7,000,000	9,000,000	4,000,000
Income Taxes
Total provision (benefit) for income taxes	(689,000,000)	(59,000,000)	(71,000,000)
Lower 48 Segment [Member] | Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	6,693,000,000	4,358,000,000	4,227,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	5,000,000	(6,000,000)	(5,000,000)
Income Taxes
Total provision (benefit) for income taxes	(2,453,000,000)	(1,328,000,000)	(1,119,000,000)
Canada Segment [Member] | Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	461,000,000	975,000,000	788,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	197,000,000	89,000,000	78,000,000
Income Taxes
Total provision (benefit) for income taxes	(616,000,000)	(383,000,000)	(223,000,000)
Europe and North Africa Segment [Member] | Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	1,313,000,000	1,253,000,000	2,565,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	10,000,000	22,000,000	23,000,000
Income Taxes
Total provision (benefit) for income taxes	1,165,000,000	(46,000,000)	(854,000,000)
Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	3,819,000,000	1,606,000,000	2,981,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	553,000,000	(51,000,000)	550,000,000
Income Taxes
Total provision (benefit) for income taxes	351,000,000	306,000,000	467,000,000
Other International Segment [Member] | Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	0	1,000,000	0
Equity in Earnings of Affiliates
Equity in earnings of affiliates	0	0	8,000,000
Income Taxes
Total provision (benefit) for income taxes	$ 21,000,000	$ (40,000,000)	$ (456,000,000)

Segment Disclosures - Net Incom

Segment Disclosures - Net Income (Loss), Investments, Total Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	$ (855)	$ (3,615)	$ (4,428)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	9,590	20,945	20,546
Total Assets
Total assets	73,362	89,772	97,484
Corporate and Other [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	(2,136)	(1,329)	(809)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	0	4	15
Total Assets
Total assets	11,456	4,962	4,473
Alaska Segment [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	1,466	319	4
Investments In and Advances To Affiliates
Investments in and advances to affiliates	56	58	61
Total Assets
Total assets	12,108	12,314	12,555
Lower 48 Segment [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	(2,371)	(2,257)	(1,932)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	402	426	455
Total Assets
Total assets	14,632	22,673	26,932
Canada Segment [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	2,564	(935)	(1,044)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	0	8,784	8,165
Total Assets
Total assets	6,214	17,548	17,221
Europe and North Africa Segment [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	553	394	409
Investments In and Advances To Affiliates
Investments in and advances to affiliates	55	62	70
Total Assets
Total assets	11,870	11,727	13,703
Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	(1,098)	209	(463)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	9,077	11,611	11,780
Total Assets
Total assets	16,985	20,451	22,318
Other International Segment [Member] | Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	167	(16)	(593)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	0	0	0
Total Assets
Total assets	$ 97	$ 97	$ 282

Segment Disclosures - Capital E

Segment Disclosures - Capital Expenditures and Interest (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Capital Expenditures and Investments
Consolidated capital expenditures and investments	$ 4,591	$ 4,869	$ 10,050
Interest Income and Expense
Interest income	112	57	45
Interest and debt expense	1,098	1,245	920
Corporate and Other [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	63	64	120
Interest Income and Expense
Interest income	101	47	36
Interest and debt expense	1,098	1,245	920
Alaska Segment [Member] | Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	815	883	1,352
Lower 48 Segment [Member] | Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	2,136	1,262	3,765
Interest Income and Expense
Interest income	0	0	0
Canada Segment [Member] | Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	202	698	1,255
Europe and North Africa Segment [Member] | Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	872	1,020	1,573
Interest Income and Expense
Interest income	2	2	2
Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	482	838	1,812
Interest Income and Expense
Interest income	9	8	6
Other International Segment [Member] | Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	21	104	173
Interest Income and Expense
Interest income	$ 0	$ 0	$ 1

Segment Disclosures - Sales by

Segment Disclosures - Sales by Product (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Sales Revenue, Net		$ 29,106	$ 23,693	$ 29,564
Natural Gas [Member]
Segment Reporting Information [Line Items]
Sales Revenue, Net		10,773	9,401	11,888
Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Sales Revenue, Net		1,102	837	952
Crude Oil [Member]
Segment Reporting Information [Line Items]
Sales Revenue, Net		13,260	10,801	12,830
Other Products [Member]
Segment Reporting Information [Line Items]
Sales Revenue, Net	[1]	$ 3,971	$ 2,654	$ 3,894
[1]	*Includes LNG and bitumen.

Segment Disclosures - Geographi

Segment Disclosures - Geographic Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Geographic Information
Sales and other operating revenues		$ 29,106	$ 23,693	$ 29,564
Long-Lived Assets	[1]	55,273	79,276	86,992
U.S.
Geographic Information
Sales and other operating revenues		17,204	14,400	16,284
Long-Lived Assets		23,623	32,949	37,445
AUSTRALIA
Geographic Information
Sales and other operating revenues		1,448	1,353	2,127
Long-Lived Assets	[2]	9,657	12,259	12,788
Canada [Member]
Geographic Information
Sales and other operating revenues		2,619	1,974	2,136
Long-Lived Assets		5,613	16,846	16,766
CHINA
Geographic Information
Sales and other operating revenues		712	551	782
Long-Lived Assets		1,275	1,372	1,647
INDONESIA
Geographic Information
Sales and other operating revenues		757	938	1,165
Long-Lived Assets		758	856	1,191
MALAYSIA
Geographic Information
Sales and other operating revenues		1,103	735	598
Long-Lived Assets		2,736	3,323	3,599
NORWAY
Geographic Information
Sales and other operating revenues		2,348	1,645	2,107
Long-Lived Assets		6,154	6,228	6,933
UNITED KINGDOM
Geographic Information
Sales and other operating revenues		2,248	1,816	4,005
Long-Lived Assets		3,335	3,209	4,154
Segment Geographical Groups of Countries Other [Member]
Geographic Information
Sales and other operating revenues		667	281	360
Long-Lived Assets		$ 2,122	$ 2,234	$ 2,469
[1]	2) Defined as net PP&E plus investments in and advances to affiliated companies.
[2]	3) Includes amounts related to the joint petroleum development area with shared 3)ownership held by Australia and Timor-Leste.

Segment Disclosures - Textuals

Segment Disclosures - Textuals (Details Textual)	12 Months Ended
	Dec. 31, 2017
Segment Disclosures and Related Information (Textual) [Abstract]
Number of operating segments	6

New Accounting Standards (Detai

New Accounting Standards (Details) - Scenario, Forecast [Member] $ in Millions	Dec. 31, 2018USD ($)
New Accounting Pronouncement, Early Adoption [Line Items]
Impact to Retained Earnings	$ (220)
Accounting Standards Update 2016-01 [Member]
New Accounting Pronouncement, Early Adoption [Line Items]
Impact to Retained Earnings	$ (58)

Supplementary Information - 132

Supplementary Information - Condensed Consolidating Financial Information Income Statement (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Revenues and Other Income
Sales and other operating revenues	$ 29,106	$ 23,693	$ 29,564
Equity in earnings of affiliates	772	52	655
Gain on dispositions	2,177	360	591
Other income (loss)	529	255	125
Intercompany revenues	0	0	0
Total Revenues and Other Income	32,584	24,360	30,935
Cost and expenses
Purchased commodities	12,475	9,994	12,426
Production and operating expenses	5,173	5,667	7,016
Selling, general and administrative expenses	561	723	953
Exploration expenses	938	1,915	4,192
Depreciation, depletion and amortization	6,845	9,062	9,113
Impairments	6,601	139	2,245
Taxes other than income taxes	809	739	901
Accretion on discounted liabilities	362	425	483
Interest and debt expense	1,098	1,245	920
Foreign currency transaction (gains) losses	35	(19)	(75)
Other Expenses	302
Total Costs and Expenses	35,199	29,890	38,174
Income (loss) before income taxes	(2,615)	(5,530)	(7,239)
Income Tax Expense (Benefit)	(1,822)	(1,971)	(2,868)
Net income (loss)	(793)	(3,559)	(4,371)
Less: net income attributable to noncontrolling interests	(62)	(56)	(57)
Net income (loss) attributable to ConocoPhillips	(855)	(3,615)	(4,428)
Comprehensive Income (Loss) Attributable to ConocoPhillips	(180)	(3,561)	(8,773)
ConocoPhillips [Member]
Revenues and Other Income
Sales and other operating revenues	0	0	0
Equity in earnings of affiliates	(454)	(3,351)	(4,081)
Gain on dispositions	0	0	0
Other income (loss)	2	1	0
Intercompany revenues	48	88	74
Total Revenues and Other Income	(404)	(3,262)	(4,007)
Cost and expenses
Purchased commodities	0	0	0
Production and operating expenses	0	0	0
Selling, general and administrative expenses	9	8	9
Exploration expenses	0	0	0
Depreciation, depletion and amortization	0	0	0
Impairments	0	0	0
Taxes other than income taxes	0	0	0
Accretion on discounted liabilities	0	0	0
Interest and debt expense	420	506	485
Foreign currency transaction (gains) losses	(43)	(19)	114
Other Expenses	267
Total Costs and Expenses	653	495	608
Income (loss) before income taxes	(1,057)	(3,757)	(4,615)
Income Tax Expense (Benefit)	(202)	(142)	(187)
Net income (loss)	(855)	(3,615)	(4,428)
Less: net income attributable to noncontrolling interests	0	0	0
Net income (loss) attributable to ConocoPhillips	(855)	(3,615)	(4,428)
Comprehensive Income (Loss) Attributable to ConocoPhillips	(180)	(3,561)	(8,773)
Reportable Legal Entities [Member] | ConocoPhillips Company [Member]
Revenues and Other Income
Sales and other operating revenues	12,433	10,352	11,473
Equity in earnings of affiliates	2,047	(1,051)	(1,950)
Gain on dispositions	916	120	332
Other income (loss)	35	(11)	12
Intercompany revenues	291	277	341
Total Revenues and Other Income	15,722	9,687	10,208
Cost and expenses
Purchased commodities	11,145	9,144	9,905
Production and operating expenses	832	779	1,469
Selling, general and administrative expenses	476	581	744
Exploration expenses	544	1,231	2,093
Depreciation, depletion and amortization	855	1,178	1,201
Impairments	1,159	67	15
Taxes other than income taxes	140	162	173
Accretion on discounted liabilities	32	46	58
Interest and debt expense	664	622	423
Foreign currency transaction (gains) losses	11	2	1
Other Expenses	35
Total Costs and Expenses	15,893	13,812	16,082
Income (loss) before income taxes	(171)	(4,125)	(5,874)
Income Tax Expense (Benefit)	283	(774)	(1,793)
Net income (loss)	(454)	(3,351)	(4,081)
Less: net income attributable to noncontrolling interests	0	0	0
Net income (loss) attributable to ConocoPhillips	(454)	(3,351)	(4,081)
Comprehensive Income (Loss) Attributable to ConocoPhillips	221	(3,297)	(8,426)
Reportable Legal Entities [Member] | ConocoPhillips Canada Funding Company I [Member]
Revenues and Other Income
Sales and other operating revenues	0	0	0
Equity in earnings of affiliates	0	0	0
Gain on dispositions	0	0	0
Other income (loss)	0	0	0
Intercompany revenues	170	220	246
Total Revenues and Other Income	170	220	246
Cost and expenses
Purchased commodities	0	0	0
Production and operating expenses	0	0	0
Selling, general and administrative expenses	0	0	1
Exploration expenses	0	0	0
Depreciation, depletion and amortization	0	0	0
Impairments	0	0	0
Taxes other than income taxes	0	0	0
Accretion on discounted liabilities	0	0	0
Interest and debt expense	147	207	226
Foreign currency transaction (gains) losses	156	174	(708)
Other Expenses	0
Total Costs and Expenses	303	381	(481)
Income (loss) before income taxes	(133)	(161)	727
Income Tax Expense (Benefit)	7	(9)	21
Net income (loss)	(140)	(152)	706
Less: net income attributable to noncontrolling interests	0	0	0
Net income (loss) attributable to ConocoPhillips	(140)	(152)	706
Comprehensive Income (Loss) Attributable to ConocoPhillips	23	(27)	71
Reportable Legal Entities [Member] | All Other Subsidiaries [Member]
Revenues and Other Income
Sales and other operating revenues	16,673	13,341	18,091
Equity in earnings of affiliates	630	(91)	1,364
Gain on dispositions	1,261	240	259
Other income (loss)	492	265	113
Intercompany revenues	3,405	3,036	3,365
Total Revenues and Other Income	22,461	16,791	23,192
Cost and expenses
Purchased commodities	4,580	3,562	5,838
Production and operating expenses	4,358	5,131	5,585
Selling, general and administrative expenses	82	140	209
Exploration expenses	394	684	2,099
Depreciation, depletion and amortization	5,990	7,884	7,912
Impairments	5,442	72	2,230
Taxes other than income taxes	669	577	728
Accretion on discounted liabilities	330	379	425
Interest and debt expense	508	570	447
Foreign currency transaction (gains) losses	(89)	(176)	518
Other Expenses	0
Total Costs and Expenses	22,264	18,823	25,991
Income (loss) before income taxes	197	(2,032)	(2,799)
Income Tax Expense (Benefit)	(1,910)	(1,046)	(909)
Net income (loss)	2,107	(986)	(1,890)
Less: net income attributable to noncontrolling interests	(62)	(56)	(57)
Net income (loss) attributable to ConocoPhillips	2,045	(1,042)	(1,947)
Comprehensive Income (Loss) Attributable to ConocoPhillips	2,703	(952)	(6,705)
Consolidating Adjustments [Member]
Revenues and Other Income
Sales and other operating revenues	0	0	0
Equity in earnings of affiliates	(1,451)	4,545	5,322
Gain on dispositions	0	0	0
Other income (loss)	0	0	0
Intercompany revenues	(3,914)	(3,621)	(4,026)
Total Revenues and Other Income	(5,365)	924	1,296
Cost and expenses
Purchased commodities	(3,250)	(2,712)	(3,317)
Production and operating expenses	(17)	(243)	(38)
Selling, general and administrative expenses	(6)	(6)	(10)
Exploration expenses	0	0	0
Depreciation, depletion and amortization	0	0	0
Impairments	0	0	0
Taxes other than income taxes	0	0	0
Accretion on discounted liabilities	0	0	0
Interest and debt expense	(641)	(660)	(661)
Foreign currency transaction (gains) losses	0	0	0
Other Expenses	0
Total Costs and Expenses	(3,914)	(3,621)	(4,026)
Income (loss) before income taxes	(1,451)	4,545	5,322
Income Tax Expense (Benefit)	0	0	0
Net income (loss)	(1,451)	4,545	5,322
Less: net income attributable to noncontrolling interests	0	0	0
Net income (loss) attributable to ConocoPhillips	(1,451)	4,545	5,322
Comprehensive Income (Loss) Attributable to ConocoPhillips	$ (2,947)	$ 4,276	$ 15,060

Supplementary Information - 133

Supplementary Information - Condensed Consolidating Financial Information Balance Sheet (Details 1) - USD ($) $ in Millions	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Assets
Cash and cash equivalents	$ 6,325	$ 3,610	$ 2,368	$ 5,062
Short-term investments	1,873	50
Accounts and notes receivable	4,320	3,414
Investment in Cenovus Energy	1,899
Inventories	1,060	1,018
Prepaid expenses and other current assets	1,035	517
Total Current Assets	16,512	8,609
Investments, loans and long-term receivables	10,060	21,672
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $64,748 million in 2017 and $73,075 million in 2016)	45,683	58,331
Other assets	1,107	1,160
Total Assets	73,362	89,772	97,484
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	4,030	3,653
Short-term debt	2,575	1,089
Accrued income and other taxes	1,038	484
Employee benefit obligations	725	689
Other accruals	1,029	994
Total Current Liabilities	9,397	6,909
Long-term debt	17,128	26,186
Total asset retirement obligations and accrued environmental costs	7,631	8,425
Deferred income taxes	5,282	8,949
Employee benefit obligations	1,854	2,552
Other liabilities and deferred credits	1,269	1,525
Total Liabilities	42,561	54,546
Retained earnings	29,391	31,548
Other common stockholders' equity	1,216	3,426
Noncontrolling interests	194	252
Total Liabilities and Equity	73,362	89,772
ConocoPhillips [Member]
Assets
Cash and cash equivalents	0	0	0
Short-term investments	0	0
Accounts and notes receivable	24	22
Investment in Cenovus Energy	0
Inventories	0	0
Prepaid expenses and other current assets	1	2
Total Current Assets	25	24
Investments, loans and long-term receivables	29,400	37,901
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $64,748 million in 2017 and $73,075 million in 2016)	0	0
Other assets	15	40
Total Assets	29,440	37,965
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	0	0
Short-term debt	(5)	(10)
Accrued income and other taxes	0	0
Employee benefit obligations	0	0
Other accruals	85	171
Total Current Liabilities	80	161
Long-term debt	3,787	8,975
Deferred income taxes	0	0
Employee benefit obligations	0	0
Other liabilities and deferred credits	1,528	417
Total Liabilities	5,395	9,553
Retained earnings	22,867	25,025
Other common stockholders' equity	1,178	3,387
Noncontrolling interests	0	0
Total Liabilities and Equity	29,440	37,965
Reportable Legal Entities [Member] | ConocoPhillips Company [Member]
Assets
Cash and cash equivalents	234	358	4	770
Short-term investments	0	0
Accounts and notes receivable	2,255	1,968
Investment in Cenovus Energy	1,899
Inventories	163	84
Prepaid expenses and other current assets	278	116
Total Current Assets	4,829	2,526
Investments, loans and long-term receivables	47,974	64,434
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $64,748 million in 2017 and $73,075 million in 2016)	4,230	6,301
Other assets	1,146	2,194
Total Assets	58,179	75,455
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	3,094	4,683
Short-term debt	2,505	999
Accrued income and other taxes	107	85
Employee benefit obligations	554	489
Other accruals	314	271
Total Current Liabilities	6,574	6,527
Long-term debt	9,321	12,635
Total asset retirement obligations and accrued environmental costs	432	925
Deferred income taxes	0	0
Employee benefit obligations	1,335	1,901
Other liabilities and deferred credits	5,229	10,391
Total Liabilities	22,891	32,379
Retained earnings	13,317	14,015
Other common stockholders' equity	21,971	29,061
Noncontrolling interests	0	0
Total Liabilities and Equity	58,179	75,455
Reportable Legal Entities [Member] | ConocoPhillips Canada Funding Company I [Member]
Assets
Cash and cash equivalents	4	13	15	7
Short-term investments	0	0
Accounts and notes receivable	35	23
Investment in Cenovus Energy	0
Inventories	0	0
Prepaid expenses and other current assets	6	8
Total Current Assets	45	44
Investments, loans and long-term receivables	2,533	2,296
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $64,748 million in 2017 and $73,075 million in 2016)	0	0
Other assets	186	220
Total Assets	2,764	2,560
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	1	1
Short-term debt	7	6
Accrued income and other taxes	0	0
Employee benefit obligations	0	0
Other accruals	48	40
Total Current Liabilities	56	47
Long-term debt	1,703	1,710
Deferred income taxes	0	0
Employee benefit obligations	0	0
Other liabilities and deferred credits	926	748
Total Liabilities	2,685	2,505
Retained earnings	(681)	(541)
Other common stockholders' equity	760	596
Noncontrolling interests	0	0
Total Liabilities and Equity	2,764	2,560
Reportable Legal Entities [Member] | All Other Subsidiaries [Member]
Assets
Cash and cash equivalents	6,087	3,239	2,349	$ 4,285
Short-term investments	1,873	50
Accounts and notes receivable	4,870	6,103
Investment in Cenovus Energy	0
Inventories	897	934
Prepaid expenses and other current assets	779	415
Total Current Assets	14,506	10,741
Investments, loans and long-term receivables	15,050	31,643
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $64,748 million in 2017 and $73,075 million in 2016)	41,930	52,030
Other assets	1,302	1,240
Total Assets	72,788	95,654
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	3,799	3,671
Short-term debt	77	94
Accrued income and other taxes	931	399
Employee benefit obligations	171	200
Other accruals	612	536
Total Current Liabilities	5,590	4,900
Long-term debt	2,794	2,866
Total asset retirement obligations and accrued environmental costs	7,199	7,500
Deferred income taxes	6,263	10,972
Employee benefit obligations	519	651
Other liabilities and deferred credits	9,215	17,832
Total Liabilities	31,580	44,721
Retained earnings	11,958	12,883
Other common stockholders' equity	29,056	37,798
Noncontrolling interests	194	252
Total Liabilities and Equity	72,788	95,654
Consolidating Adjustments [Member]
Assets
Cash and cash equivalents	0	0	0
Short-term investments	0	0
Accounts and notes receivable	(2,864)	(4,702)
Investment in Cenovus Energy	0
Inventories	0	0
Prepaid expenses and other current assets	(29)	(24)
Total Current Assets	(2,893)	(4,726)
Investments, loans and long-term receivables	(84,897)	(114,602)
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $64,748 million in 2017 and $73,075 million in 2016)	(477)	0
Other assets	(1,542)	(2,534)
Total Assets	(89,809)	(121,862)
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	(2,864)	(4,702)
Short-term debt	(9)	0
Accrued income and other taxes	0	0
Employee benefit obligations	0	0
Other accruals	(30)	(24)
Total Current Liabilities	(2,903)	(4,726)
Long-term debt	(477)	0
Deferred income taxes	(981)	(2,023)
Employee benefit obligations	0	0
Other liabilities and deferred credits	(15,629)	(27,863)
Total Liabilities	(19,990)	(34,612)
Retained earnings	(18,070)	(19,834)
Other common stockholders' equity	(51,749)	(67,416)
Noncontrolling interests	0	0
Total Liabilities and Equity	$ (89,809)	$ (121,862)
Consolidating Adjustments [Member] | All Other Subsidiaries [Member]
Assets
Cash and cash equivalents			$ 0

Supplementary Information - 134

Supplementary Information - Condensed Consolidating Financial Information Balance Sheet (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Condensed Financial Statements, Captions [Line Items]
Inercompany Distribution of Earnings	$ 605	$ 398	$ 876
Repayment of Debt	7,876	2,251	103
ConocoPhillips Company [Member] | Return Of Capital from Consolidated Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Return of Capital	7,800
Reportable Legal Entities [Member] | ConocoPhillips [Member] | Return Of Capital from Consolidated Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Return of Capital	7,800	2,300	3,500
Intercompany Dividend Paid	200
Reportable Legal Entities [Member] | ConocoPhillips Company [Member]
Condensed Financial Statements, Captions [Line Items]
Intercompany other liabilities	(1,400)
Repayment of Debt	4,411	164	100
Reportable Legal Entities [Member] | ConocoPhillips Company [Member] | Return Of Capital from Consolidated Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Return of Capital	9,800
Intercompany other liabilities	8,000	2,300	3,500
Reportable Legal Entities [Member] | ConocoPhillips Canada Funding Company I [Member]
Condensed Financial Statements, Captions [Line Items]
Repayment of Debt	0	1,250	0
Reportable Legal Entities [Member] | All other nonguarantor subsidiaries of ConocoPhillips.
Condensed Financial Statements, Captions [Line Items]
Intercompany other liabilities	1,400
Repayment of Debt	2,272	$ 2,492	$ 103
Reportable Legal Entities [Member] | All other nonguarantor subsidiaries of ConocoPhillips. | Return Of Capital from Consolidated Subsidiaries [Member]
Condensed Financial Statements, Captions [Line Items]
Intercompany other liabilities	$ 9,800

Supplementary Information - 135

Supplementary Information - Condensed Consolidating Financial Information Cash Flow (Details 2) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash Flows From Operating Activities
Net Cash Provided by (Used in) Operating Activities	$ 7,077	$ 4,403	$ 7,572
Cash Flows From Investing Activities
Capital expenditures and investments	(4,591)	(4,869)	(10,050)
Increase (Decrease) In Capital Accrual Associated With Investing Activities	132	(331)	(968)
Proceeds from asset dispositions	13,860	1,286	1,952
Net Sales (Purchases) of Short-Term Investments	(1,790)	(51)	0
Long-term advances/loans-related parties	0	0
Collection of advances/loans-related parties	115	108	105
Intercompany Cash Management	0	0
Other	36	(2)	306
Net Cash Provided by (Used in) Investing Activities	7,762	(3,859)	(8,655)
Cash Flows From Financing Activities
Issuance of debt	0	4,594	2,498
Repayment of debt	(7,876)	(2,251)	(103)
Change in restricted cash	0	0	0
Issuance of company common stock	(63)	(63)	(82)
Repurchase of company common stock	(3,000)	(126)	0
Dividends paid	(1,305)	(1,253)	(3,664)
Other	(112)	(137)	(78)
Net Cash Provided by (Used in) Financing Activities	(12,356)	764	(1,429)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	232	(66)	(182)
Net Change in Cash and Cash Equivalents	2,715	1,242	(2,694)
Cash and cash equivalents at beginning of period	3,610	2,368	5,062
Cash and Cash Equivalents at End of Period	6,325	3,610	2,368
ConocoPhillips [Member]
Cash Flows From Operating Activities
Net Cash Provided by (Used in) Operating Activities	71	(306)	(225)
Cash Flows From Investing Activities
Capital expenditures and investments		0	0
Increase (Decrease) In Capital Accrual Associated With Investing Activities		0	0
Proceeds from asset dispositions	7,765	2,300	3,500
Net Sales (Purchases) of Short-Term Investments	0	0	0
Long-term advances/loans-related parties	0	0	0
Collection of advances/loans-related parties	658	0	0
Intercompany Cash Management	1,151	(2,214)	102
Other	0	0	0
Net Cash Provided by (Used in) Investing Activities	9,574	86	3,602
Cash Flows From Financing Activities
Issuance of debt	0	1,600	0
Repayment of debt	(5,459)	(150)	0
Issuance of company common stock	115	148	283
Repurchase of company common stock	(3,000)	(126)
Dividends paid	(1,305)	(1,253)	(3,664)
Other	4	1	4
Net Cash Provided by (Used in) Financing Activities	(9,645)	220	(3,377)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0	0
Net Change in Cash and Cash Equivalents	0	0	0
Cash and cash equivalents at beginning of period	0	0
Cash and Cash Equivalents at End of Period	0	0	0
Reportable Legal Entities [Member] | ConocoPhillips [Member]
Cash Flows From Investing Activities
Capital expenditures and investments	0
Increase (Decrease) In Capital Accrual Associated With Investing Activities	0
Reportable Legal Entities [Member] | ConocoPhillips Company [Member]
Cash Flows From Operating Activities
Net Cash Provided by (Used in) Operating Activities	1,183	(322)	245
Cash Flows From Investing Activities
Capital expenditures and investments	(1,663)	(989)	(3,064)
Increase (Decrease) In Capital Accrual Associated With Investing Activities	194	(126)	(4)
Proceeds from asset dispositions	11,146	266	826
Net Sales (Purchases) of Short-Term Investments	0	0
Long-term advances/loans-related parties	(214)	(812)	(278)
Collection of advances/loans-related parties	1,527	391	0
Intercompany Cash Management	101	1,433	46
Other	(8)	1	304
Net Cash Provided by (Used in) Investing Activities	11,083	164	(2,170)
Cash Flows From Financing Activities
Issuance of debt	20	2,994	4,743
Repayment of debt	(4,411)	(164)	(100)
Change in restricted cash		0
Issuance of company common stock	0	0	0
Repurchase of company common stock	0	0
Dividends paid	(235)	0	0
Other	(7,765)	(2,315)	(3,484)
Net Cash Provided by (Used in) Financing Activities	(12,391)	515	1,159
Effect of Exchange Rate Changes on Cash and Cash Equivalents	1	(3)
Net Change in Cash and Cash Equivalents	(124)	354	(766)
Cash and cash equivalents at beginning of period	358	4	770
Cash and Cash Equivalents at End of Period	234	358	4
Reportable Legal Entities [Member] | ConocoPhillips Canada Funding Company I [Member]
Cash Flows From Operating Activities
Net Cash Provided by (Used in) Operating Activities	(74)	(2)	9
Cash Flows From Investing Activities
Capital expenditures and investments	0	0	0
Increase (Decrease) In Capital Accrual Associated With Investing Activities	0	0	0
Proceeds from asset dispositions	0	0	0
Net Sales (Purchases) of Short-Term Investments	0	0
Long-term advances/loans-related parties	0	0	0
Collection of advances/loans-related parties	0	1,250	0
Intercompany Cash Management	0	0	0
Other	0	0	0
Net Cash Provided by (Used in) Investing Activities	0	1,250	0
Cash Flows From Financing Activities
Issuance of debt	65	0	0
Repayment of debt	0	(1,250)	0
Change in restricted cash		0
Issuance of company common stock	0	0	0
Repurchase of company common stock	0	0
Dividends paid	0	0	0
Other	0	0	0
Net Cash Provided by (Used in) Financing Activities	65	(1,250)	0
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0	(1)
Net Change in Cash and Cash Equivalents	(9)	(2)	8
Cash and cash equivalents at beginning of period	13	15	7
Cash and Cash Equivalents at End of Period	4	13	15
Reportable Legal Entities [Member] | All Other Subsidiaries [Member]
Cash Flows From Operating Activities
Net Cash Provided by (Used in) Operating Activities	8,931	5,903	7,519
Cash Flows From Investing Activities
Capital expenditures and investments	(3,795)	(4,281)	(8,386)
Increase (Decrease) In Capital Accrual Associated With Investing Activities	(62)	(205)	(964)
Proceeds from asset dispositions	12,796	1,114	1,225
Net Sales (Purchases) of Short-Term Investments	(1,790)	(51)
Long-term advances/loans-related parties	(85)	0	(2,245)
Collection of advances/loans-related parties	2,196	272	205
Intercompany Cash Management	(1,252)	781	(148)
Other	44	(3)	1
Net Cash Provided by (Used in) Investing Activities	8,052	(2,373)	(10,312)
Cash Flows From Financing Activities
Issuance of debt	214	812	278
Repayment of debt	(2,272)	(2,492)	(103)
Change in restricted cash		0
Issuance of company common stock	0	0	(2)
Repurchase of company common stock	0	0
Dividends paid	(2,977)	(1,081)	(339)
Other	(9,331)	184	1,204
Net Cash Provided by (Used in) Financing Activities	(14,366)	(2,577)	1,038
Effect of Exchange Rate Changes on Cash and Cash Equivalents	231	(63)	(181)
Net Change in Cash and Cash Equivalents	2,848	890	(1,936)
Cash and cash equivalents at beginning of period	3,239	2,349	4,285
Cash and Cash Equivalents at End of Period	6,087	3,239	2,349
Consolidation, Eliminations [Member]
Cash Flows From Operating Activities
Net Cash Provided by (Used in) Operating Activities	(3,034)	(870)	24
Cash Flows From Investing Activities
Capital expenditures and investments	867	401	1,400
Increase (Decrease) In Capital Accrual Associated With Investing Activities	0	0
Proceeds from asset dispositions	(17,847)	(2,394)	(3,599)
Net Sales (Purchases) of Short-Term Investments	0	0
Long-term advances/loans-related parties	299	812	2,523
Collection of advances/loans-related parties	(4,266)	(1,805)	(100)
Intercompany Cash Management	0	0
Other	0	0	1
Net Cash Provided by (Used in) Investing Activities	(20,947)	(2,986)	225
Cash Flows From Financing Activities
Issuance of debt	(299)	(812)	(2,523)
Repayment of debt	4,266	1,805	100
Change in restricted cash		0
Issuance of company common stock	(178)	(211)	(363)
Repurchase of company common stock	0	0
Dividends paid	3,212	1,081	339
Other	16,980	1,993	2,198
Net Cash Provided by (Used in) Financing Activities	23,981	3,856	(249)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	0
Net Change in Cash and Cash Equivalents		0
Cash and cash equivalents at beginning of period	0	0
Cash and Cash Equivalents at End of Period	$ 0	0	0
Consolidation, Eliminations [Member] | All Other Subsidiaries [Member]
Cash Flows From Financing Activities
Effect of Exchange Rate Changes on Cash and Cash Equivalents			0
Net Change in Cash and Cash Equivalents			0
Cash and cash equivalents at beginning of period		$ 0
Cash and Cash Equivalents at End of Period			$ 0