ConocoPhillips (COP) 10-K 21 Feb 17 2016 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2016	Jan. 31, 2017
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, 2016
Amendment Flag	false
Document Fiscal Year Focus	2,016
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		1,235,832,469
Trading Symbol	COP

Consolidated Income Statement

Consolidated Income Statement - USD ($)		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenues and Other Income
Sales and other operating revenues		$ 23,693,000,000	$ 29,564,000,000	$ 52,524,000,000
Equity in earnings of affiliates		52,000,000	655,000,000	2,529,000,000
Gain on dispositions		360,000,000	591,000,000	98,000,000
Other income		255,000,000	125,000,000	366,000,000
Total Revenues and Other Income		24,360,000,000	30,935,000,000	55,517,000,000
Costs and Expenses
Purchased commodities		9,994,000,000	12,426,000,000	22,099,000,000
Production and operating expenses		5,667,000,000	7,016,000,000	8,909,000,000
Selling, general and administrative expenses		723,000,000	953,000,000	735,000,000
Exploration expenses		1,915,000,000	4,192,000,000	2,045,000,000
Depreciation, depletion and amortization		9,062,000,000	9,113,000,000	8,329,000,000
Impairments		139,000,000	2,245,000,000	856,000,000
Taxes other than income taxes		739,000,000	901,000,000	2,088,000,000
Accretion on discounted liabilities		425,000,000	483,000,000	484,000,000
Interest and debt expense		1,245,000,000	920,000,000	648,000,000
Foreign currency transaction (gains) losses		(19,000,000)	(75,000,000)	(66,000,000)
Total Costs and Expenses		29,890,000,000	38,174,000,000	46,127,000,000
Income (loss) from continuing operations before income taxes		(5,530,000,000)	(7,239,000,000)	9,390,000,000
Provision (benefit) for income taxes		(1,971,000,000)	(2,868,000,000)	3,583,000,000
Income (Loss) From Continuing Operations		(3,559,000,000)	(4,371,000,000)	5,807,000,000
Income (loss) from discontinued operations	[1]			1,131,000,000
Net income (loss)		(3,559,000,000)	(4,371,000,000)	6,938,000,000
Less: net income attributable to noncontrolling interests		(56,000,000)	(57,000,000)	(69,000,000)
Net Income (Loss) Attributable to ConocoPhillips		(3,615,000,000)	(4,428,000,000)	6,869,000,000
Amounts Attributable to ConocoPhillips Common Shareholders:
Income (loss) from continuing operations		(3,615,000,000)	(4,428,000,000)	5,738,000,000
Income from discontinued operations	[1]	0	0	1,131,000,000
Net income (loss) attributable to ConocoPhillips		$ (3,615,000,000)	$ (4,428,000,000)	$ 6,869,000,000
Basic
Continuing operations		$ (2.91)	$ (3.58)	$ 4.63
Discontinued operations		0	0	0.91
Net Income (Loss) Attributable to ConocoPhillips Per Share of Common Stock		(2.91)	(3.58)	5.54
Diluted
Continuing operations		(2.91)	(3.58)	4.6
Discontinued operations		0	0	0.91
Net Income (Loss) Attributable to ConocoPhillips Per Share of Common Stock		(2.91)	(3.58)	5.51
Dividends Paid Per Share of Common Stock (dollars)		$ 1	$ 2.94	$ 2.84
Average Common Shares Outstanding (in thousands)
Basic		1,245,440	1,241,919	1,237,325
Diluted		1,245,440	1,241,919	1,245,863
[1]	Net of provision for income taxes on discontinued operations of: $0, $0, $16

Consolidated Income Statement (

Consolidated Income Statement (Parenthetical) $ in Millions	12 Months Ended
	Dec. 31, 2014USD ($)
Consolidated Income Statement [Abstract]
Net of provision for income taxes on discontinued operations of	$ 16

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Consolidated Statement of Comprehensive Income
Net income (loss)		$ (3,559)	$ (4,371)	$ 6,938
Defined benefit plans
Prior service (cost) credit arising during the period		23	301	(3)
Amortization of prior service cost (credit) included in income		(35)	(19)	(6)
Net change		(12)	282	(9)
Net actuarial gain (loss) arising during the period		(481)	592	(840)
Reclassification adjustment for amortization of prior service credit included in net income (loss)		309	403	131
Net change		(172)	995	(709)
Nonsponsored plans	[1]	2	1	0
Income taxes on defined benefit plans		78	(460)	281
Defined benefit plans, net of tax		(104)	818	(437)
Foreign currency translation adjustments		153	(5,199)	(3,539)
Reclassification adjustment for gain included in net income (loss)		5	0	0
Income taxes on foreign currency translation adjustments		0	36	72
Foreign currency translation adjustments, net of tax		158	(5,163)	(3,467)
Hedging activities				0
Hedging activities, net of tax				0
Other comprehensive income (loss), net of tax		54	(4,345)	(3,904)
Comprehensive income (loss)		(3,505)	(8,716)	3,034
Less: comprehensive income attributable to noncontrolling interests		(56)	(57)	(69)
Comprehensive Income (Loss) Attributable to ConocoPhillips		$ (3,561)	$ (8,773)	$ 2,965
[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, 2016	Dec. 31, 2015
Assets
Cash and cash equivalents	$ 3,610	$ 2,368
Short-term Investments	50
Accounts and notes receivable (net of allowance of $5 million in 2016 and $7 million in 2015)	3,249	4,314
Accounts and notes receivable-related parties	165	200
Inventories	1,018	1,124
Prepaid expenses and other current assets	517	783
Total Current Assets	8,609	8,789
Investments and long-term receiavables	21,091	20,490
Loans and advances-related parties	581	696
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $73,075 million in 2016 and $70,413 million in 2015)	58,331	66,446
Other assets	1,160	1,063
Total Assets	89,772	97,484
Liabilities
Accounts payable	3,631	4,895
Accounts payable-related parties	22	38
Short-term debt	1,089	1,427
Accrued income and other taxes	484	499
Employee benefit obligations	689	887
Other accruals	994	1,510
Total Current Liabilities	6,909	9,256
Long-term debt	26,186	23,453
Long-term asset retirement obligations and accrued environmental costs	8,425	9,580
Deferred income taxes	8,949	10,999
Employee benefit obligations	2,552	2,286
Other liabilities and deferred credits	1,525	1,828
Total Liabilities	54,546	57,402
Equity
Common stock (2,500,000,000 shares authorized at $.01 par value)	18	18
Capital in excess of par	46,507	46,357
Treasury stock (at cost: 2016-544,809,771; 2015-542,230,673)	(36,906)	(36,780)
Accumulated other comprehensive income (loss)	(6,193)	(6,247)
Retained earnings	31,548	36,414
Total Common Stockholders' Equity	34,974	39,762
Noncontrolling interests	252	320
Total Equity	35,226	40,082
Total Liabilities and Equity	$ 89,772	$ 97,484

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Consolidated Balance Sheet [Abstract]
Allowance for accounts and notes receivable	$ 5	$ 7
Accumulated depreciation, depletion and amortization	$ 73,075	$ 70,413
Common stock, shares authorized	2,500,000,000	2,500,000,000
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares issued	1,782,079,107	1,778,226,388
Treasury stock, shares	544,809,771	542,230,673

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($)		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flows From Operating Activities
Net income (loss)		$ (3,559,000,000)	$ (4,371,000,000)	$ 6,938,000,000
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization		9,062,000,000	9,113,000,000	8,329,000,000
Impairments		139,000,000	2,245,000,000	856,000,000
Dry hole costs and leasehold impairments		1,184,000,000	3,065,000,000	1,166,000,000
Accretion on discounted liabilities		425,000,000	483,000,000	484,000,000
Deferred taxes		(2,221,000,000)	(2,772,000,000)	709,000,000
Undistributed equity earnings		299,000,000	101,000,000	77,000,000
Gain on dispositions		(360,000,000)	(591,000,000)	(98,000,000)
Income from discontinued operations	[1]			(1,131,000,000)
Other		(85,000,000)	321,000,000	(233,000,000)
Working capital adjustments
Decrease (increase) in accounts and notes receivable		820,000,000	1,810,000,000	1,227,000,000
Decrease (increase) in inventories		44,000,000	166,000,000	(193,000,000)
Decrease (increase) in prepaid expenses and other current assets		105,000,000	239,000,000	(190,000,000)
Increase (decrease) in accounts payable		(524,000,000)	(1,647,000,000)	(963,000,000)
Increase (decrease) in taxes and other accruals		(926,000,000)	(590,000,000)	(566,000,000)
Net cash provided by continuing operating activities		4,403,000,000	7,572,000,000	16,412,000,000
Net cash provided by discontinued operations		0	0	157,000,000
Net Cash Provided by Operating Activities		4,403,000,000	7,572,000,000	16,569,000,000
Cash Flows From Investing Activities
Capital expenditures and investments		(4,869,000,000)	(10,050,000,000)	(17,085,000,000)
Working capital changes associated with investing activities		(331,000,000)	(968,000,000)	180,000,000
Proceeds from asset dispositions		1,286,000,000	1,952,000,000	1,603,000,000
Net sales (purchases) of short-term investments		(51,000,000)	0	253,000,000
Collection of advances/loans-related parties		108,000,000	105,000,000	603,000,000
Other		(2,000,000)	306,000,000	(446,000,000)
Net cash used in continuing investing activities		(3,859,000,000)	(8,655,000,000)	(14,892,000,000)
Net cash provided by (used in) discontinued operations		0	0	(73,000,000)
Net Cash Provided by (Used in) Investing Activities		(3,859,000,000)	(8,655,000,000)	(14,965,000,000)
Cash Flows From Financing Activities
Issuance of debt		4,594,000,000	2,498,000,000	2,994,000,000
Repayment of debt		(2,251,000,000)	(103,000,000)	(2,014,000,000)
Change in restricted cash		0	0	0
Issuance of company common stock		(63,000,000)	(82,000,000)	35,000,000
Repurchase of company common stock		(126,000,000)
Dividends paid		(1,253,000,000)	(3,664,000,000)	(3,525,000,000)
Other		(137,000,000)	(78,000,000)	(64,000,000)
Net cash provided by (used in) financing activities		764,000,000	(1,429,000,000)	(2,574,000,000)
Net cash used in discontinued operations		0	0	0
Net Cash Used in Financing Activities		764,000,000	(1,429,000,000)	(2,574,000,000)
Effect of Exchange Rate Changes on Cash and Cash Equivalents		(66,000,000)	(182,000,000)	(214,000,000)
Net Change in Cash and Cash Equivalents		1,242,000,000	(2,694,000,000)	(1,184,000,000)
Cash and cash equivalents at beginning of period		2,368,000,000	5,062,000,000	6,246,000,000
Cash and Cash Equivalents at End of Period		$ 3,610,000,000	$ 2,368,000,000	$ 5,062,000,000
[1]	Net of provision for income taxes on discontinued operations of: $0, $0, $16

Consolidated Statement of Chang

Consolidated Statement of Changes in Equity - USD ($) $ in Millions	Total	Common Stock [Member]	Additional Paid-in Capital [Member]	Treasury Stock [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Retained Earnings [Member]	Noncontrolling Interest [Member]
Beginning Balance at Dec. 31, 2013	$ 52,492	$ 18	$ 45,690	$ (36,780)	$ 2,002	$ 41,160	$ 402
Net income (loss)	6,938					6,869	69
Other comprehensive income (loss)	(3,904)				(3,904)
Dividends paid	(3,525)					(3,525)
Distributions to noncontrolling interests and other	(109)						(109)
Distributed under benefit plans	381		381
Ending 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
Recognition of unearned compensation	0
Other	2					2	0
Ending Balance at Dec. 31, 2016	$ 35,226	$ 18	$ 46,507	$ (36,906)	$ (6,193)	$ 31,548	$ 252

Accounting Policies

Accounting Policies	12 Months Ended
	Dec. 31, 2016
Accounting Policies [Abstract]
Accounting Policies	Notes to Consolidated Financial Statements ConocoPhillips 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 24 —Segment Disclosures and Related Information. Unless indicated otherwise, the information in the Notes to the Consolidated Financial Statements relates to our continuing operations. 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 earnings. Most of our foreign operations use their local currency as the functional currency. Use of Estimates — The preparatio n 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 disclos ures 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 recogn ized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry. Revenues ass ociated 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, whic h are deemed to be nonrecoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropriate. 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 li ne) . Shipping and Handling Costs — We include shipping and handling costs in production and operating expenses for production activities. Transportation costs related to marketing activities are recorded in purchased commodities. Freight costs billed to cu stomers 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 inventories and consistently use the following methods for each type of inventory. Commodity-related inventories are valued at the lower of cost or market in the aggregate, primarily on the last-in, first-out (LIFO) basis. 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 m atch current inventory costs with current revenues. Costs include both direct and indirect expenditures 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 equipment, are valued using various methods, including the weighted-average-cost method, and the first-in, first-out (FIFO) method, consistent with industry practice. F air Value Measurements — A ssets and liabilities measured at fair value and required to be categorized 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. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corrob orated 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 other criteria are met, derivative assets and liabilities with the same counterparty are netted on the balance sheet and the collateral payable or receivable is net ted 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. G ains and losses from derivatives not accounted for as hedges are recognized immediately in earnings. For derivative instruments that are designated and qualify as a fair value hedge, the gains or losses from adjusting the derivative to its fair value will be immediately recognized in earnings and, to the extent the hedge is effective, offset the concurrent recognition of changes in the fair value of the hedged item. 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 res erves have been found. If economically recoverable reserves are not found, exploratory well costs are expensed as dry holes. If exploratory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance s heet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For complex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on the balance sheet for se veral years while we perform additional appraisal drilling and seismic work on the potential oil and gas field or while we seek government or co-venturer approval of development plans or seek environmental permitting. Once all required approvals and permi ts have been obtained, the projects are moved into the development phase, and the oil and gas resources are designated as proved reserves. 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 8 —Suspended Wells and Other Exploration Expenses , f or 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 interest is added to the cost of the underlying asset and is amortized over the useful lives of the assets in the same manne r as the underlying assets. Depreciation and Amortization — Depreciation and amortization of PP&E on producing hydrocarbon properties and certain pipeline assets (those which are expected to have a declining utilization pattern), are determined by the unit-o f-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 o f 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 updat es 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 future 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 dep reciation 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 in dependent 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 determined 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 similar 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 av ailable, 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 available 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 reserves 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 wri tten 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 p articipants, 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 deprecia ble 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 l ong-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 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 is increased for the change in its present value, and the capitalized cost in PP&E is de preciated over the useful life of the related asset. For additional information, see Note 10 —Asset Retirement Obligations and Accrued Environmental C osts . Environmental expenditures are expensed or capitalized, depending upon their future economic b enefit. 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 b usiness 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 the ir 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 nature 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 there 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 ear n the award) or the period beginning at the start of 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 liabilit ies, except for deferred taxes on income and temporary 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 app lied currently as reductions of the provision for income 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 — 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 participating securities. Diluted net income per share of common stock includes unvested stock, unit or option awards granted under our compensation plans and vested but unexercise d 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 from the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the pa rticipating securities is immaterial.

Change in Accounting Principles

Change in Accounting Principles	12 Months Ended
	Dec. 31, 2016
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Changes in Accounting Principles [Text Block]	Note 2 —Change in Accounting Principles We adopted the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) No. 2015-02 , “Amendments to the Consolidation Analysis,” beginning January 1, 2016. The ASU amends existing requirements applicable to reporting entities that are required to evaluate whether certain legal entities, including variable interest entities (VIEs), should be consolidated. The adoption of this ASU did not have an impact on our consolidated f inancial statements and disclosures. See Note 4 —Variable Interest Entities, for additional infor mation on our significant VIEs.

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2016
Discontinued Operations [Abstract]
Discontinued Operations Disclosure [Text Block]	Note 3 —Discontinued Operations On December 20, 2012, we entered into agreements with affiliates of Oando PLC to sell our Nigeria business, which was previously part of the Other International operating segment. O n July 30 , 2014, we completed the sale for $ 1,359 million, inclusive of $ 550 million deposits previously received. The deposits had been included in the “Other accruals” line on our consolidated balance sheet and in the “Other” line of cash flows from investing activities on our consolidated statement of cash flows. The deposits received included $ 435 million in 2012, $ 15 million in 2013, and $ 100 million in 2014. We recognized a before-tax gain of $ 1,052 million, which is included in the “Income from discontinued operations” li ne on our consolidated income statement. Sales and other operating revenues and income from discontinued operations related to the Nigeria business during 2014 were as follows: Millions of Dollars 2014 Sales and other operating revenues from discontinued operations $ 480 Income from discontinued operations before-tax $ 1,147 Income tax expense 16 Income from discontinued operations $ 1,131

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	12 Months Ended
	Dec. 31, 2016
Variable Interest Entities VIEs [Abstract]
Variable Interest Entities (VIEs)	Note 4 —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, 2016 , 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 7 —Investments, Loans and Long-Term Receivables, and Note 12 —Guarantees, for additional information. Marine Well Containment Compa ny, 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 Membe r and exercise significant influence through our permanent seat on the ten member Executive Committee responsible for overseeing the affairs of MWCC. During the year ended December 31, 2016, MWCC executed a $ 154 million term loan financin g arrangement with an external 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 credi t 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 balan ce sheet. MWCC is considered 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 busin ess and operation of the company and to undertake certain obligations that most significantly impact its economic performance with nine other unaffiliated owners of MWCC. At December 31, 2016, the book value of our equity method investment in MWCC was $ 148 million. 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, 2016
Inventories [Abstract]
Inventories	Note 5 —Inventories Inventories at December 31 were: Millions of Dollars 2016 2015 Crude oil and natural gas $ 418 406 Materials and supplies 600 718 $ 1,018 1,124 Inventories valued on the LIFO basis totaled $ 269 million and $ 317 million at December 31, 2016 and 2015 , respectively. The estimated excess of current replacement cost over LIFO cost of inventories was approximately $ 104 million and $ 6 million at December 31, 2016 and December 31, 2015 , respectively . In 2016 , liquidation of LIFO inventory values increased the net loss from continuing operations by $ 9 million.

Assets Held for Sale or Sold

Assets Held for Sale or Sold	12 Months Ended
	Dec. 31, 2016
Disposal Group Excluding Discontinued Operation Additional Disclosures [Abstract]
Disposal Groups Exluding Discontinued Operations Disclosure [Text Block]	Note 6 —Assets Held for Sale or Sold 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. 2016 On April 22, 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 disposition, the net carryi ng 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 asset retirement obligations (ARO). On October 13, 2016, we completed an asset exchange with Bonavista 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 i n northeast British Columbia. The fair value of the transaction 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 sal e, to reduce the carrying value to fair value. In the fourth quarter, a loss on disposition of approximately $ 1 million was recognized upon completion of the transaction. The divested properties were included in the Canada segment. On October 28, 2016, we sold ConocoPhillips Senegal B.V., the entity that held our 35 percent interest in three exploration blocks offshore Senegal for $ 442 million and recognized a gain on disposition of $ 146 million. At the time of dis position, the carrying value of our interest was $ 286 million, which was primarily PP&E. Senegal results of operations were reported within our Other International segment . On November 17, 2016, we completed the sale of our 40 perc ent 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 Asia Pacific and Middle East segment. Previously, in the third quarter of 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 was 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. On December 8, 2016, we completed the sale of certain mineral and non-mineral fee lands in northeastern Minnesota, which was 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 and in November 2016, upon completion of the wind-down period, documents 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 included 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 $ 201 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 South 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 mil lion of PP&E and $ 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. A t 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. 2014 For information on the sale of our Nigeria business, which is included in the “Income from discontinued operations” line on our consolidated income statement, s ee Note 3 — Discontinued Operations.

Investments, Loans and Long-Ter

Investments, Loans and Long-Term Receivables	12 Months Ended
	Dec. 31, 2016
Investments, Loans and Long-Term Receivables and Joint Venture Acquisition Obligation [Abstract]
Investments, Loans and Long-Term Receivables	Note 7 —Investments, Loans and Long-Term Receivables Components of investments, loans and long-term receivables at December 31 were: Millions of Dollars 2016 2015 Equity investments $ 20,364 19,850 Loans and advances—related parties 581 696 Long-term receivables 631 519 Other investments 96 121 $ 21,672 21,186 Equity Investments Affiliated companies in which we had a significant equity investment at December 31, 2016 , 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. FCCL Partnership— 50 percent owned business venture with Cenovus Energy Inc.—produces bitumen in the Athabasca oil sands in northeastern Alberta and sells the bitumen blend. 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 2016 2015 2014 Revenues $ 10,149 11,003 19,243 Income before income taxes 660 1,866 6,746 Net income 799 1,801 6,630 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2016 2015 Current assets $ 3,578 2,504 Noncurrent assets 60,243 58,431 Current liabilities 2,352 1,863 Noncurrent liabilities 23,764 24,820 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, 2016 , retained earnings included $ 1,392 million related to the undistributed earnings of affiliated companies. Dividends received from affiliates were $ 398 million , $ 876 million and $ 2,648 million in 2016 , 2015 and 2014 , respectively. APL NG APLNG is focused on coalbed methane production from the Bowen and Surat basins in Queensland, Australia, and 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, 2016 , $ 8.5 billion ha d been drawn from the facility. In connection 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 reac hed financial completion for Train 1, which reduced our associated guarantee by 60 percent. See Note 12 — 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 4 — Variable Interest Entities (VIEs) for additional information. On July 1, 2016, APLNG changed 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 APLNG for the deferred tax effect of $ 174 million in the “ Equity in earnings (losses) 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 time, 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 third quarter of 2016, the outlook for crude oil prices weakened again , and as a result, the estimated fair value of our investment in APLNG declined to an amount below book value as of September 30, 2016. Based on a review of the facts and circumstances surrounding this decline in fair value, we concluded the impairment was not other than temporary under the guidance of FASB Accounting Standards Codification (ASC) Topic 323, “Investments – Equity Method and Joint Ventures.” During the fourth quarter of 2016, primarily due to the impact of accretion on discounted cash flows from the passage of time and strengthening of the U.S. dollar, the estimated fair value of our investment increased and is above book value as of December 31, 2016. The expected future cash flows used for the impairment review of our investment in APLNG are based on estimated future production, an outlook of future prices from a combination of exchanges (short-term) and pricing service co mpanies (long-term), costs, a market outlook of foreign exchange rates provided by a third party, and a discount rate believed t o be consistent with those used by principal market participants. Unfavorable changes in any of these assumptions could result in a reduction in future cash flows and could indicate impairment in the future. Subsequent to December 31, 2016, the outlook f or crude prices and the U.S. dollar exchange rate relative to the Australian dollar has weakened. If these outlooks remain unchanged, we expect the estimated fair value of our investment in APLNG to be below book value at March 31, 2017. At December 31, 2016 , the book value of our equity method investment in APLNG was $ 10,089 million . The historical cost basis of our 37.5 percent share of net assets on the books of APLNG under U.S. generally accepted accounting principles was $ 8,348 million, resulting in a basis difference of $ 1,741 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 exploration 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. Eac h exploration license area will periodically be reviewed for any indicators 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 amortiz e the basis difference allocated to that license using the unit-of-production method. Included in net income (loss) attributable to ConocoPhillips for 2016 , 2015 and 2014 was after-tax expense of $ 92 million, $ 21 million and $ 24 million, respectively, representing the 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 . We account for our investment in FCCL under the equity method of accounting , with the operating results of our investment in FCCL converted to reflect the use of the successful efforts method of accounting for oil and gas exploration and development activities. At December 31, 2016 , the book value of our investment in FCCL was $ 8,784 million , net of a $ 1,706 million reduction due to cumulative foreign currency translation effects . FCCL’s operating assets consist of the Foster Creek and Christina Lake steam-assisted gravity drainage bitumen projects, both located in the eastern flank of the Athabasca oil s ands in northeastern Alberta . Cenovus is the operator and managing partner of FCCL. We were obligated to contribute $ 7.5 billion, plus accrued interest, to FCCL over a 10-year period that began in 2007. In December 2013, we repaid the remaining balance of the obligation, which totaled $ 2,810 million. In the first quarter of 2014, we received a $ 1.3 billion distribution from FCCL, which is included in the “Undistributed equity earnings” line on our consol idated statement of cash flows. 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 $ 696 million as describ ed below under “Loans and Long-T erm Receivables.” At December 31, 2016 , the book value of our equity method investment in QG3 , excluding the project financing , was $ 869 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 with terminal and pipeline capacity for the receipt, storage and regasification of LNG purchased from QG3. Ho wever, 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 ongoing 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 companies. 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 decrease 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. Through November 2014, we had an agreement with Freeport LNG Development, L.P. (Freeport LNG) to participate i n an LNG receiving terminal in Quintana, Texas. We had no ownership in Freeport LNG ; however, we had a 50 percent interest in Freeport LNG GP, Inc. (Freeport GP), which serves as the general partner managing the ve nture. We had entered into a credit agreement with Freeport LNG, whereby we agreed to provide loan financing for the construction of the terminal. We also entered into a long-term agreement with Freeport LNG to use 0.9 billion cubic feet pe r day of regasification capacity, which would have expired in 2033. When the terminal became operational in June 2008, we began making payments under the terminal use agreement. Freeport LNG began making loan repayments in September 2008. In July 2013, we reached an agreement with Freeport LNG to terminate our long-term agreement at the Freeport LNG Terminal, subject to Freeport LNG obtaining regulatory approval and project financing for an LNG liquefaction and export facility in Texas, in which we are n ot a participant. These conditions were satisfied in 2014 , and we paid Freeport LNG a termination fee of $ 522 million. Freeport LNG repaid the outstanding $ 454 million ConocoPhillips loan used by Freeport LNG to partially fun d the original construction of the terminal. The payment made to Freeport LNG to terminate our long-term agreement is included in the cash flows from operating activities section on our consolidated statement of cash flows, while the receipt of the funds from Freeport LNG to repay the outstanding loan is included in the cash flows from investing activities section in 2014. These transactions, plus miscellaneous items, including the disposal of our 50 percent interest in Freeport GP, resulted in a one-time net cash outflow of $ 63 million for us. In addition, we recognized an after-tax charge to earnings of $ 540 million in 2014, and our terminal regasification capacity was reduced to zero. At December 31 , 2016 , significant loans to affiliated companies include $ 696 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 affilia tes 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 bi llion from ConocoPhillips. The ConocoPhillips loan facilities have substantially the same terms as the ECA and commercial bank facilities. On December 15, 2011, QG3 achieved financial completion and all project loan facilities became nonrecourse to the p roject 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—related parties” line on our consolidated balance sheet, while the short-term portion is in “Accounts and notes receivable—related parties.”

Suspended Wells

Suspended Wells	12 Months Ended
	Dec. 31, 2016
Suspended Wells [Abstract]
Suspended Wells	Note 8 —Suspended Wells and Other Exploration Expenses The following table reflects the net changes in suspended exploratory well costs during 2016, 2015 and 2014: Millions of Dollars 2016 2015 2014 Beginning balance at January 1 $ 1,260 1,299 994 Additions pending the determination of proved reserves 225 331 478 Reclassifications to proved properties (27) (28) (9) Sales of suspended well investment (247) - (57) Charged to dry hole expense (148) (342) (107) Ending balance at December 31 $ 1,063 1,260 1,299 The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2016 2015 2014 Exploratory well costs capitalized for a period of one year or less $ 132 235 466 Exploratory well costs capitalized for a period greater than one year 931 1,025 833 Ending balance $ 1,063 1,260 1,299 Number of projects with exploratory well costs capitalized for a period greater than one year 26 28 30 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, 2016: Millions of Dollars Suspended Since Total 2013–2015 2010–2012 2002–2009 Greater Poseidon—Australia (2) 177 157 15 5 Shenandoah—Lower 48 (1) 161 118 - 43 Greater Clair—UK (2) 131 120 11 - Surmont 3 and beyond—Canada (1) 107 55 29 23 NPRA—Alaska (1) 93 70 - 23 Caldita/Barossa—Australia (1) 77 - - 77 Middle Magdalena Basin—Colombia (1) 31 31 - - Limbayong—Malaysia (1) 23 23 - - Alpine Satellite—Alaska (2) 22 - - 22 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 25 3 15 Total $ 931 648 58 225 (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 the third quarter of 2015. In July 2016, we entered into an agreement to terminate our final Gulf of Mexico deepwater drillship contract. Th e 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 m illion in our Lower 48 segment in 2016. These charges are included in the “Exploration expenses” line on our consolidated income statement. 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 will recognize a before-tax charge of $43 millio n net in the first quarter of 2017.

Impairments

Impairments	12 Months Ended
	Dec. 31, 2016
Impairment Of Long Lived Assets [Abstract]
Impairments	Note 9 —Impairments During 2016, 2015 and 2014, we recognized the following before-tax impairment charges: Millions of Dollars 2016 2015 2014 Alaska $ 1 10 59 Lower 48 149 (2) 208 Canada 88 4 38 Europe and North Africa (160) 724 541 Asia Pacific and Middle East 44 1,508 7 Corporate 17 1 3 $ 139 2,245 856 2016 In 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 lower natural gas prices and increased asset retirement obligation estimates. In Canada, we recorded impairments of $88 million mainly due to plan of development changes, as well as certain developed properties, which were classified as held for sale, being written down to fair value less costs to sell. In Europe, we re corded a credit to impairment of $160 million, primarily in the United Kingdom, due to decreased asset retirement obligation estimates on fields that are nearing the end of life and were impaired in prior years, partly offset by asset impairments due to lo wer natural gas prices in the United Kingdom. In Asia Pacific and Middle East, we recorded impairments of $44 million, mainly due to the 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 conso lidated income statement 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 milli on 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 of capitalized undevelop ed leasehold costs of the Melmar prospect and a $79 million 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 before-tax unproved property impairmen ts of $31 million, primarily due to decisions to discontinue further testing of undeveloped leaseholds. 2015 See the “APLNG” section of Note 7 —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, we recorded impairments of $724 million, primarily in the United Kingdom as a result of lower natural gas prices and increases to asset retirement obligations. 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 impairments of $ 377 million and $ 116 million, respectively, for the associated carrying values of capitalized undeveloped leasehold cos ts. 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 impairment s of $ 399 million for the associat ed 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 an impairment of $ 105 million for the assoc iated carrying values of capitalized undeveloped leasehold cost. In our Alaska segment, we recorded an 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 an impairment of $ 102 million for the Duvernay, Thornbury, Saleski and Crow Lake areas driven primarily by the lack of commerciality of wells . 2014 In Alaska , we recorded impairments of $59 million, primarily due to a cancelled project. In our Lower 48 segment, w e recorded impa irments of $208 million, primarily as a result of reduced volume forecasts for an onshore field, as well as an LNG-related pipeline . W e recorded impairment s of $38 million in our Canada segment , primarily due to reduced volume forecasts and lower natural gas prices. In Europe , we recorded impairments of $541 million, mainly due to reduced volume forecasts, increases in the ARO and lower natural gas prices for properties in the United Kingdom which are nearing the end of their useful lives. 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 Lower 48 segment, w e recorded unproved property impairments of $239 million , primarily due to decisions to discontinue further testing of the undeveloped leaseholds . Additionally, we decided not to pursue future development of the Amauligak discovery. A ccordingly, we recorded a $145 million property impairment for the carrying value of capitalized undeveloped leasehold costs associated with our Amauligak, Arctic Islands and other Beaufort propert ies located offshore Canada .

Asset Retirement Obligations an

Asset Retirement Obligations and Accrued Environmental Costs	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligations and Accrued Environmental Costs [Abstract]
Asset Retirement Obligations and Accrued Environmental Costs	Note 10 —Asset Retirement Obligations and Accrued Environmental Costs Asset retirement obligations and accrued environmental costs at December 31 were: Millions of Dollars 2016 2015 Asset retirement obligations $ 8,405 9,911 Accrued environmental costs 247 258 Total asset retirement obligations and accrued environmental costs 8,652 10,169 Asset retirement obligations and accrued environmental costs due within one year* (227) (589) Long-term asset retirement obligations and accrued environmental costs $ 8,425 9,580 *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 asset retirement obligation 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 estimat e 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 asset retirement obligations 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 2016 and 2015, our overall asset retirement obligation changed as follows: Millions of Dollars 2016 2015 Balance at January 1 $ 9,911 10,939 Accretion of discount 420 480 New obligations 180 135 Changes in estimates of existing obligations (1,197) 267 Spending on existing obligations (314) (437) Property dispositions (150) (726) Foreign currency translation (464) (747) Other 19 - Balance at December 31 $ 8,405 9,911 Accrued Environmental Costs Total accrued environmental costs at December 31, 2016 and 2015 , were $ 247 million and $ 258 million, respectively. We had accrued environmental costs of $ 183 million and $ 184 million at December 31, 2016 and 2015 , respectively, related to remediation activities in the United States and Canada. We had also accrued in Corporate and Other $ 51 million and $ 57 million o f environmental c osts associated with sites no longer in operation at December 31, 2016 and 2015 , respectively. In addition, $ 13 million and $ 17 million were included at both December 31, 2016 and 2015 , 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 $ 92 million at December 31, 2016 . The expected future undiscounted payments related to the portion of the accrued environmental costs that have been discounted are: $ 9 million in 2017 , $ 12 million in 2018 , $ 8 million in 2019 , $ 5 million in 2020 , $ 4 million in 2021 , and $ 110 million for all future years after 2021 .

Debt

Debt	12 Months Ended
	Dec. 31, 2016
Debt [Abstract]
Debt	Note 11 —Debt Long-term debt at December 31 was: Millions of Dollars 2016 2015 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 297 297 6.50% Notes due 2039 2,750 2,750 6.00% Notes due 2020 1,000 1,000 5.951% Notes due 2037 645 645 5.95% Notes due 2036 500 500 5.95% Notes due 2046 500 - 5.90% Notes due 2032 505 505 5.90% Notes due 2038 600 600 5.75% Notes due 2019 2,250 2,250 5.625% Notes due 2016 - 1,250 5.20% Notes due 2018 500 500 4.95% Notes due 2026 1,250 - 4.30% Notes due 2044 750 750 4.20% Notes due 2021 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 750 750 1.05% Notes due 2017 1,000 1,000 Floating rate term loan due 2019 at 1.94% – 2.31% during 2016 1,450 - Floating rate notes due 2018 at 0.69% – 1.24% during 2016 250 250 and 0.61% – 0.69% during 2015 Floating rate notes due 2022 at 1.26% – 1.81% during 2016 500 500 and 1.18% – 1.26% during 2015 Commercial paper at 0.16% – 0.80% during 2015 - 803 Industrial Development Bonds due 2016 through 2038 at 0.01% – 0.91% during 2016 and 0.01% – 0.13% during 2015 18 18 Marine Terminal Revenue Refunding Bonds due 2031 at 0.01% – 0.95% during 2016 and 0.01% – 0.14% during 2015 265 265 Other 24 24 Debt at face value 26,175 23,778 Capitalized leases 852 818 Net unamortized premiums, discounts and debt issuance costs 248 284 Total debt 27,275 24,880 Short-term debt (1,089) (1,427) Long-term debt $ 26,186 23,453 Maturities of long-term borrowings, inclusive of net unamortized premiums and discounts, in 2017 through 2021 are: $ 1,089 million, $ 1,894 million, $ 3,784 million, $ 1,593 million and $ 2,235 million, respectively. In the first quarter of 2016, we reduced our revolving credit facility, expiring in June 2019, from $ 7.0 billion to $ 6.75 billion. Our revolving credit facility may be used for direct bank borro wings, for 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 adve rse change provisions or any covenants requiring maintenance of specified 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 overnigh t 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 thei r approved successors cease to be a majority of the Board of Directors. We have two commercial paper programs supported by our $ 6.75 billion revolving credit facility: the ConocoPhillips $ 6.25 billion program, primarily a funding source for short-term working capital needs, and the ConocoPhillips Qatar Funding Ltd. $ 500 million program, which is used to fund commitments relating to QG3. Commercial paper maturities are generally limited to 90 days. At both December 31, 2016 and 2015 , we had no direct outstanding borrowings under the revolving credit facility, with no letters of credit as of December 31, 2016 and 2015 . Under the ConocoPhillips Qatar Funding Ltd. commercial paper program, no commercial paper was outstanding at December 31, 2016 , compared with $ 803 million at December 31, 2015 . 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, 2016 . In March 2016, we issued notes consisting of: The $ 1,250 million of 4.20 % Notes due 2021. The $ 1,250 million of 4.95 % Notes due 2026 . The $ 500 million of 5.95 % Notes due 2046. In addition, on March 18, 2016, we entered into a $ 1,600 million three-year senior unsecured term loan facility. In December 2016, an early repayment of $ 150 million reduced the loan to $ 1,450 million. We have the right at any time and from time to time to prepay the term loan, in whole or in part, without premium or penalty upon notice to the Administrative Agent. Borrowings will accrue interes t at a base rate or, for certain Eurodollar borrowings, the London Interbank Offered Rate (LIBOR), in each case plus a margin that is set based on our corporate credit ratings. The applicable margin for loans bearing interest based on the base rate ranges from 0.50% to 1.00% and the applicable margin for loans bearing interest based on LIBOR ranges from 1.50% to 2.00%. Based on our current corporate credit ratings, the applicable margin for loans accruing interest at the base rate is 0.50% and the applica ble margin for loans accruing interest at LIBOR is 1.50%. The term loan facility contains customary covenants regarding, among other matters, material compliance with laws and restrictions against certain consolidations, mergers and asset sales and creat ion of certain liens on our assets and consolidated subsidiaries. The term loan facility also contains financial covenants including a total debt to capitalization ratio, excluding the impacts of certain noncash impairments and foreign currency translatio n adjustments as defined in the Term Loan Agreement, which may not exceed 65 percent. At December 31, 2016 , we were in compliance with this covenant. The term loan facility includes customary events of default (subject to specified cure periods, mate riality qualifiers and exceptions), including the failure to pay any interest, principal or fees when due, the failure to perform or the violation of any covenant contained in the term loan facility, the making of materially inaccurate or false representat ions or warranties, a default on certain material indebtedness, insolvency or bankruptcy, a change of control and the occurrence of material Employee Retirement Income Security Act of 1974 (ERISA) events and certain judgments against us or our material sub sidiaries. The net proceeds of the notes and term loan will be used for general corporate purposes. On October 17, 2016, the $ 1,250 million 5.625 % Notes due 2016 were repaid at maturity. At both December 31, 2016 and 2015 , we had $ 283 million of certain variable rate demand bonds (VRDBs) outstanding with maturities ranging through 2035. The VRDBs are redeemable at the option of the bondholders on any business day. The VRDBs are included in the “Long-term debt” line on o ur 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 optio ns or escalation clauses. Adjustments to provisional 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 activiti es. A capital lease asset and capital lease obligation 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. Unitization of the Gumusut development with Brunei was recorded during the fo urth quarter of 2015 and reduced our proportionate interest in the FPS from 33 percent to 29 percent. The net carrying value of the capital lease asset was approximately $ 540 million and $ 707 million a s of December 31, 2016 and December 31, 2015 , 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 depre ciation included in the “Depreciation, depletion and amortization” line on our consolidated income statement. As of December 31, 2016 and December 31, 2015 , accumulated depreciation of the capital lease asset amounted to approximately $ 268 million and $ 122 million , respectively . At December 31, 2016, future minimum payments due under capital leases were: Millions of Dollars 2017 $ 121 2018 102 2019 102 2020 103 2021 88 Remaining years 590 Total 1,106 Less: portion representing imputed interest (254) Capital lease obligations $ 852

Guarantees

Guarantees	12 Months Ended
	Dec. 31, 2016
Guarantees [Abstract]
Guarantees	Note 12 —Guarantees At December 31, 2016 , 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, 2016 , 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 2016 exchange rates: We have 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. We estimate the remaining term of this guarantee is one year . Our maximum po tential amount of future payments related to this guarantee is approximately $ 10 million and would become payable if APLNG cancels the applicable construction contract and does not perform with respect to the amounts owed to the contractor. We have issued a construction completion guarantee related to the third-party project financing secured by APLNG. Our guarantee of the project financing will be released upon meeting certain completion tests with milestones which we estimat e should occur in 201 7. In October 2016, we reached financial completion for Train 1, releasing a portion of our guarantee. Our maximum exposure at December 31, 2016 , is $ 1.3 billion based upon our pro-rata share of the fac ility used at that date , which could be payable if completion of the project is not achieved. At December 31, 2016 , the carrying value of this guarantee is approximately $ 46 million. During the third quarter of 2016, we issued a guara ntee for our pro-rata portion of the funds in a project finance reserve account. We estimate the remaining term of this guarantee is 13 years . Our maximum exposure under this guarantee is approximately $ 60 million a nd may become payable if an enforcement action is commenced by the project finance lenders against APLNG. At December 3 1 , 2016, the carrying value of this guarantee is approximately $ 9 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 AP LNG to deliver natural gas under several sales agreements with remaining terms of 1 to 25 years . Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $ 1.0 billion ($ 1.7 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 consi dered unlikely, 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 guarantee d the performance 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 29 years or the life of the venture . Our maximum potential amount of future payments related to these guarantees is approximately $ 160 million and would become payable if APLNG does not perform. Other Guarantees We have other guarantees with maximum future potential payment amounts totaling approximately $ 540 mi llion, which consist primarily of a guarantee of the residual value of a leased office building, 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 gu arantees have remaining terms of up to six 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 gua ranteed 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, 2016 , 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 case s where the indemnification 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 decline s. Although it is reasonably 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 ca rrying amount at December 31, 2016 , 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 about environmental liabilities, see Note 13 —Contingencies and Commitments. On April 3 0, 2012, the separation of our downstream business was completed, creating two independent energy companies: ConocoPhillips and Phillips 66. In connection with the separation, we entered into an Indemnification and Release Agreement, which provides for cross-indemnities between Phillips 66 and us and established procedures f or handling claims subject to indemnification and related matters. We evaluated the impact of the indemnifications given and the Phillips 66 indemnifications received as of the separation date and concluded those fair values were immaterial. On March 1, 2015 , a supplier to one of 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 liability for future payments under this guarantee, which would become payable if Phillips 66 does not perform its contractual obligations under the supply agreement, is approximate ly $ 1.4 billion. At December 31, 2016 , the carrying value of this guarantee is approximately $ 98 million and the remaining term is eight 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 indemnification asset amount represents the estimated fair value of the guarantee; however, if we are required to perform under t he guarantee, we would expect to recover from Phillips 66 any amounts in excess of that value, provided Phillips 66 is a going concern.

Contingencies and Commitments

Contingencies and Commitments	12 Months Ended
	Dec. 31, 2016
Contingencies and Commitments [Abstract]
Contingencies and Commitments	Note 13 —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 19 —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 10 —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, 2016 , we had performance obligations secured by letters of credit of $ 304 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, as a result of the newly enacted Windfall Profits Tax Law and government-mandated renegotiation of our production sharing contracts. Despite a restraining order issued by the ICSID tribunal, Ecuador confiscated the crude oil production of Bur lington and its co-venturer and sold the seized crude oil. In 2009, Ecuador took over operations in Blocks 7 and 21, fully expropriating our assets. In June 2010, the ICSID tribunal concluded it has jurisdiction to hear the expropriation claim. On April 24, 2012, Ecuador filed supplemental counterclaims asserting environmental damages, which we believe are not material. The ICSID tribunal issued a decision on liability on December 14, 2012, in favor of Burlington, finding that Ecuador's seizure of Block s 7 and 21 was an unlawful expropriation in violation of the Ecuador-U.S. Bilateral Investment Treaty. An additional arbitration phase to determine the damages owed to ConocoPhillips for Ecuador’s actions and to address Ecuador’s counterclaims is complete . In February 2017, the tribunal una nimously 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 limited environmental and infrast ructure impacts associated with the operations of Burlington and its co-venturer. Ecuador recently filed a request for annulment of this decision with ICSID. The schedule for the annulment process has not yet been set. In December 2016, ConocoPhillips Angola filed a notice of arbitration against Sonangol E.P. unde r the Block 36 Production Sharing Contract relating to disputes arising thereunder. The arbitration will be conducted under the United Nations Commission on International Trade Laws (UNCITRAL) rules using a three person tribunal. Long-Term Throughput Agr eements and Take-or-Pay Agreements We have certain throughput agreements 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: 2017 —$ 24 million; 2018 —$ 20 million; 2019 —$ 7 million; 2020 —$ 7 million; 2021 —$ 7 million; and 2022 and after—$ 75 million. Total payments under the agreements were $ 42 million in 2016 , $ 27 million in 2015 and $ 127 million in 2014 .

Derivative and Financial Instru

Derivative and Financial Instruments	12 Months Ended
	Dec. 31, 2016
Derivative and Financial Instruments [Abstract]
Derivative and Financial Instruments	Note 14 —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 2016 2015 Assets Prepaid expenses and other current assets $ 268 768 Other assets 44 60 Liabilities Other accruals 300 754 Other liabilities and deferred credits 34 46 The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars 2016 2015 2014 Sales and other operating revenues $ (198) 231 523 Other income (1) 2 1 Purchased commodities 161 (201) (458) The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts: Open Position Long/(Short) 2016 2015 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (31) (14) Basis 2 (17) 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 and foreign currency exchange rate exposures, such as firm commitments for capital pro gram s or local currency tax payments, dividends, and cash returns from net investments in foreign affiliates. We do not elect hedge accounting on our foreign currency exchan ge 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 2016 2015 Assets Prepaid expenses and other current assets $ 1 47 Liabilities Other accruals 168 8 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 2016 2015 2014 Foreign currency transaction (gains) losses $ 247 (33) 3 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency 2016 2015 Foreign Currency Exchange Derivatives Sell U.S. dollar, buy other currencies* USD 13 347 Buy U.S. dollar, sell other currencies** USD 25 20 Buy British pound, sell other currencies*** GBP 1,069 567 Sell British pound, buy Norwegian krone GBP 51 - *Primarily Canadian dollar, Norwegian krone and British pound. **Primarily Canadian dollar and British pound. ***Primarily Canadian dollar and Euro. Financial Instruments We have certain financial instruments on our consolidated balance sheet related to interest-bearing time deposits and commercial paper. These held-to-maturity financial instruments are included in “Cash and cash equivalents” on our consolidated balance sheet if the maturities at the time we made the investments were 90 days or less ; otherwise, these investments are included in “Short-term investments” on our consolidated balance sheet. Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments 2016 2015 2016 2015 Cash $ 623 528 - - Time deposits Remaining maturities from 1 to 90 days 2,987 1,840 39 - Remaining maturities from 91 to 180 days - - 11 - $ 3,610 2,368 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, 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 forwards and swaps, 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 significant nonperformance. W e 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 thos e 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 national and internationa l 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 counterparties. We do not gen erally 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 these 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 have contracts with fi xed 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 re vert 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. The aggrega te fair value of all derivative instruments with such credit risk-related contingent features that were in a liability position on December 31, 2016 and December 31, 2015 , was $ 42 million and $ 158 million, respe ctively. For these instruments , no collateral was posted as of December 31, 2016 , and $ 2 million of collateral was posted as of December 31, 2015 . If our credit rating had been downgraded below investment grade on December 31, 2016 , we would be required to post $ 42 million of additional collateral, either with cash or letters of credit.

Fair Value Measurement

Fair Value Measurement	12 Months Ended
	Dec. 31, 2016
Fair Value Measurement [Abstract]
Fair Value Measurement	Note 15 —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 val uation 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 observable. Level 3: Unobservable inputs tha t 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 Lev el 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 subsequently reported as Level 3 if corrobor ated market data is no longer available. Transfers occur at the end of the reporting period. There were no material transfers in or out of Level 1 during 2016 or 2015 . 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. Level 2 derivative assets and liabilities primarily represent OTC swaps, options and forward purchase and sale contracts 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 and 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 i s 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 activity 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 t he right of setoff exists for commodity derivatives accounted for at fair value on a recurring basis): Millions of Dollars December 31, 2016 December 31, 2015 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Commodity derivatives $ 194 96 22 312 516 242 70 828 Total assets $ 194 96 22 312 516 242 70 828 Liabilities Commodity derivatives $ 207 105 22 334 515 273 12 800 Total liabilities $ 207 105 22 334 515 273 12 800 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, 2016 Assets $ 312 221 91 - 5 86 Liabilities 334 221 113 12 12 89 December 31, 2015 Assets $ 828 600 228 - 8 220 Liabilities 800 600 200 1 11 188 At December 31, 2016 and December 31, 2015, 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 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, 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 Year ended December 31, 2015 Net PP&E (held for use) March 31, 2015 $ - - - 9 June 30, 2015 42 - 42 70 September 30, 2015 - - - 7 December 31, 2015 440 - 440 595 Net PP&E (unproved property) September 30, 2015 104 - 104 240 Equity method investments December 31, 2015 10,210 - 10,210 1,507 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. Ne t 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. Net PP&E (unproved property) Net PP&E unproved property is comprised of unprove d leaseholds impaired to our best estimate of sales value less costs to sell. 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. An investment using L evel 1 inputs was written down to fair value, less costs to sell, determined by its negotiated selling price. Investments using L evel 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. During 2015, this primarily included our investment in APLNG, which was written down to its fair value of $10,185 million, resulting in a charge of $1,502 million before-tax. For additional information on APLNG, see Note 7 —Investments, Loans and L ong-Term Receivables. 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 re lated party loans is consistent with Loans and advances—related parties. 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 value hierarchy. See Note 7 —Investments, Loans and Long-Term Receivables, for additional information. Accounts payable (including related parties) and floating-rate debt: The carrying amount of accou nts 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 measured using prices available from a pricing service that is corroborated by market data; therefor e, 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 2016 2015 2016 2015 Financial assets Commodity derivatives $ 91 228 91 228 Total loans and advances—related parties 701 808 701 808 Financial liabilities Total debt, excluding capital leases 26,423 24,062 29,307 24,785 Commodity derivatives 101 199 101 199 Commodity derivatives At December 31, 2016 , commodity derivative assets and liabilities appear net with no obligations to return cash collateral and $ 12 million of rights to reclaim cash collateral, respectively. At December 31, 2015 , commodity derivative assets and liabilities appear net with no obligations to re turn cash collateral and $ 1 million of rights to reclaim cash collateral , respectively.

Equity

Equity	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Equity	Note 16 —Equity Common Stock The changes in our shares of common stock, as categorized in the equity section of the balance sheet, were: Shares 2016 2015 2014 Issued Beginning of year 1,778,226,388 1,773,583,368 1,768,169,906 Distributed under benefit plans 3,852,719 4,643,020 5,413,462 End of year 1,782,079,107 1,778,226,388 1,773,583,368 Held in Treasury Beginning of year 542,230,673 542,230,673 542,230,673 Repurchase of common stock 2,579,098 - - End of year 544,809,771 542,230,673 542,230,673 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, 2016 or 2015 . Noncontrolling Interests At December 31, 2016 and 2015 , we had $ 252 million and $ 320 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 over the next three years. Re purchase of shares began i n November and totaled 2,579,098 shares at a cost of $ 126 million, through December 31, 2016 .

Non Mineral Leases

Non Mineral Leases	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Non-Mineral Leases	Note 17 —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 11 —Debt. At December 31, 2016, future minimum rental payments due under noncancelable leases were: Millions of Dollars 2017 $ 277 2018 238 2019 172 2020 390 2021 114 Remaining years 435 Total 1,626 Less: income from subleases (15) Net minimum operating lease payments $ 1,611 Operating lease rental expense for the years ended December 31 was: Millions of Dollars 2016 2015 2014 Total rentals $ 537 432 474 Less: sublease rentals (8) (9) (10) $ 529 423 464

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2016
Employee Benefit Plans [Abstract]
Employee Benefit Plans	Note 18 —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 2016 2015 2016 2015 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 3,772 3,321 4,387 3,984 352 716 Service cost 108 76 138 124 2 4 Interest cost 133 120 161 135 13 22 Plan participant contributions - 3 - 5 24 21 Plan amendments - - - - (27) (303) Actuarial (gain) loss 247 466 (212) (442) (14) (49) Benefits paid (872) (148) (729) (162) (68) (63) Curtailment 14 10 27 (43) 3 8 Settlement - (46) - - - - Recognition of termination benefits 14 1 - 68 - - Foreign currency exchange rate change - (358) - (348) 1 (4) Benefit obligation at December 31* $ 3,416 3,445 3,772 3,321 286 352 *Accumulated benefit obligation portion of above at 3,246 3,067 3,573 2,953 December 31: $ Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 2,606 3,063 3,266 3,278 - - Actual return on plan assets 133 397 (4) 96 - - Company contributions 214 125 73 120 44 42 Plan participant contributions - 3 - 5 24 21 Benefits paid (872) (148) (729) (162) (68) (63) Foreign currency exchange rate change - (372) - (274) - - Fair value of plan assets at December 31 $ 2,081 3,068 2,606 3,063 - - Funded Status $ (1,335) (377) (1,166) (258) (286) (352) Millions of Dollars Pension Benefits Other Benefits 2016 2015 2016 2015 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 164 - 175 - - Current liabilities (101) (7) (99) (34) (44) (45) Noncurrent liabilities (1,234) (534) (1,067) (399) (242) (307) Total recognized $ (1,335) (377) (1,166) (258) (286) (352) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 3.95 % 3.00 4.50 3.95 3.60 3.90 Rate of compensation increase 4.00 3.85 4.00 4.05 - - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.90 % 3.95 4.00 3.55 3.75 4.05 Expected return on plan assets 7.00 5.45 7.00 5.40 - - Rate of compensation increase 4.00 4.05 4.75 4.35 - - 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 2016 2015 2016 2015 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial (gain) loss $ 748 479 773 273 (27) (18) Unrecognized prior service cost (credit) 4 (20) 9 (30) (285) (292) Millions of Dollars Pension Benefits Other Benefits 2016 2015 2016 2015 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ (263) (232) 61 490 14 41 Amortization of (gain) loss included in net loss* 288 26 312 89 (5) 2 Net change during the period $ 25 (206) 373 579 9 43 Prior service credit (cost) arising during the period $ - (4) - (2) 27 303 Amortization of prior service cost (credit) included in net loss 5 (6) 7 (11) (34) (15) Net change during the period $ 5 (10) 7 (13) (7) 288 *Includes settlement losses recognized in 2016 and 2015. 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 . During the year ended December 31, 2015 , there were am endments to the U.S. other postretirement benefit plan. The bene fit obligation decreased by $ 303 million for changes in the plan made to retiree medical benefits. The $ 303 million decrease consists of $ 149 million r elated to the discontinuation of all company premium cost-sharing contributions to the post-65 retiree medical p lan after December 31, 2025, $ 91 million related to updated cost sharing assu mption changes for retirees, $ 49 million associated with excluding employees and retirees of Phillips 66 who were not enrolled in a ConocoPhillips retiree medical plan as of July 1, 2015, and $ 14 million associated with new participants in the post-65 retiree medical plan after De cember 31, 2015 , no longer being eligible for any company premium cost-sharing contributions. The $ 303 million decrease in the benefit obligation resulted in a corresponding decrease in other comprehensive loss. Included in accumulated other comprehensive income (loss) at December 31, 2016, were the following before- tax amounts that are expected to be amortized into net periodic benefit cost during 2017: Millions of Dollars Pension Other Benefits Benefits U.S. Int’l. Unrecognized net actuarial (gain) loss $ 75 48 (3) Unrecognized prior service cost (credit) 4 (5) (36) 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 $ 5,498 million, $ 5,145 million, and $ 4,208 million, respectively, at December 31, 2016 , and $ 5,720 million, $ 5,314 million, and $ 4,759 million, respectively, at December 31, 2015 . For our unfunded nonqualified key employee supplemental pension plans, the projected benefit obligation and the accumulated benefit obligation were $ 586 million and $ 496 million, respectively, at December 31, 2016 , and were $ 639 million and $ 564 million, respectively, at December 31, 2015 . 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 2016 2015 2014 2016 2015 2014 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 108 76 138 124 124 109 2 4 3 Interest cost 133 120 161 135 165 166 13 22 29 Expected return on plan assets (149) (147) (201) (164) (213) (181) - - - Amortization of prior service cost (credit) 5 (6) 6 (7) 6 (8) (34) (17) (4) Recognized net actuarial loss (gain) 86 26 115 82 77 57 (2) 2 (3) Settlements 202 - 197 7 - - - - - Curtailment (gain) loss 14 - 35 (4) - - 1 2 - Net periodic benefit cost $ 399 69 451 173 159 143 (20) 13 25 We recognized pension settlement losses of $ 202 million in 2016 and $ 204 million in 2015 as 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 that 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 t he 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 , respect ively . 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-li ne 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. T he measurement of the U.S. pre-65 retiree medical accumulated postretirement benefit obligation assumes a health care cost trend rate of 6.50 percent in 2017 that declines to 5 percent by 2023 . The measurement of th e U.S. post-65 retiree medical accumulated postretirement benefit obligation assumes a health care cost trend rate of 4 percent in 2017 that increases to 5 percent by 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 57 percent equity securities, 37 percent debt securities and 6 percent real estate. Generally, the plan investments are publicly traded, therefore minimizing liquid ity 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, 2016 and 2015 . Fair values of equity securities and gov ernment 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 securities and government debt securitie s 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 active. 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 represent the net asset value of shar es held. 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 balances held in the form of short-te rm 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 in Level 2, the values are generally calculated from pricing models with market input parameters from third-party sources. Fair values of insurance contracts are v alued 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-p arty sources and sales comparables where available. A portion of U.S. pension plan assets is held as a participating interest in an insurance annuity contract, which is calculated as the market value of investments held under this contract, less the accumu lated 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 p resent value computation for contract obligations. 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. At December 31, 2015 , the participating interest in the annuity contract was valued at $ 125 million and consisted of $ 305 million in debt securities, less $ 180 million for the accumulated benefit obligation covered by the contract. The net change from 2015 to 2016 is due to a decrease in the fair value of the underlying investments of $ 17 million offset by a decrease in the present value of the contract obligation of $ 13 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 2016 Equity Securities U.S. $ 632 - 14 646 628 - - 628 International 342 - - 342 428 - - 428 Common/collective trusts 62 - - 62 - 156 - 156 Mutual funds - - - - 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. 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 2015 Equity Securities U.S. $ 777 3 2 782 609 - - 609 International 485 - - 485 450 - - 450 Common/collective trusts - - - - - 214 - 214 Mutual funds - - - - 234 106 - 340 Debt Securities Government 85 56 - 141 493 - - 493 Corporate - 331 17 348 - - - - Agency and mortgage-backed securities - 80 - 80 - - - - Common/collective trusts - - - - - 406 - 406 Mutual funds - - - - 136 - - 136 Cash and cash equivalents - - - - 46 - - 46 Derivatives - (7) - (7) (26) - - (26) Real estate - - - - - - 104 104 Total in fair value hierarchy $ 1,347 463 19 1,829 1,942 726 104 2,772 Investments measured at net asset value* Equity Securities Common/collective trusts $ - - - 569 - - - - Debt Securities Corporate - - - - - - - 172 Agency and mortgage-backed securities - - - - - - - 36 Cash and cash equivalents - - - 60 - - - 10 Real estate - - - 63 - - - 65 Total** $ 1,347 463 19 2,521 1,942 726 104 3,055 *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 $125 million and net payables related to security transactions of $32 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 2017 , we expect to contribute approximately $ 320 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $ 110 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. 2017 $ 352 116 42 2018 290 131 39 2019 287 124 36 2020 277 129 34 2021 292 137 30 2022–2026 1,374 729 109 Severance Accrual As a result of the current business environment’s impact on our operating and capital plans, a reduction in our overall employee workforce occurred during 2015 and 2016 . Severance accruals of $ 129 million were recorded in 2016 . The following table summarizes our severance accrual activity for the year ended December 31, 2016 : Millions of Dollars Balance at December 31, 2015 $ 156 Accruals 129 Benefit payments (206) Foreign currency translation adjustments 1 Balance at December 31, 2016 $ 80 Of the remaining balance at December 31, 2016 , $ 52 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 funds. I n 2016 , employees who participate in the CPSP and contribute 1 percent of their eligible pay receive a 6 percent company cash match with a pote ntial company discretionary cash contribution of up to 6 percent. Company contributions charged to expense for the CPSP and predecessor plans were $ 58 million in 2016 , $ 109 million in 2015 , and $ 116 million in 2014 . 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 $ 44 million in 2016 , $ 55 million in 2015 , and $ 66 million in 2014 . 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 nonemployee 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 and 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 of 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 gene rally 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 different 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 income (loss) and the associated tax benefit for the years ended December 31 were as follows: Millions of Dollars 2016 2015 2014 Compensation cost $ 272 362 358 Tax benefit 92 123 125 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: 2016 2015 2014 Assumptions used Risk-free interest rate 1.55 % 1.79 1.86 Dividend yield 4.00 % 4.00 4.00 Volatility factor 26.80 % 23.32 25.31 Expected life (years) 6.37 5.79 6.12 There were no ranges in the assumptions used to determine the fair market values of our options granted over the past three years. Due to the separation of our Downstream businesses in 2012, expected volatility for grants of options in 2014 was based on a three-year average historical stock price volatility of a group of peer companies. We believe our historical volatility for periods prior to the separation of our Downstre am businesses is no longer relevant in estimating expected volatility. For 2015 and 2016 , expected volatility was based on the weighted average blend of the company’s historical stock price volatility from May 1, 2012 (the date of separation of our Downstream busi nesses) 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, 2016: Weighted- Weighted- Average Millions of Dollars Average Grant Date Aggregate Options Exercise Price Fair Value Intrinsic Value Outstanding at December 31, 2015 20,184,810 $ 55.88 $ 42 Granted 4,434,400 33.13 $ 5.39 Exercised (62,536) 48.80 - Forfeited (272,646) 34.51 Expired or cancelled (571,916) 45.46 Outstanding at December 31, 2016 23,712,112 $ 52.14 $ 128 Vested at December 31, 2016 20,192,822 $ 52.85 $ 93 Exercisable at December 31, 2016 15,932,144 $ 53.56 $ 55 The weighted-average remaining contractual term of outstanding options, vested options and exercisable options at December 31, 2016 , was 5.74 years , 5.25 years and 4.40 years, respectively . The weighted-average grant date fair value of stock option awards granted during 2015 and 2014 was $ 9.54 and $ 10.17 , respectively. The aggregate intrinsic value of options exercised during 2015 and 2014 was $ 10 million and $ 89 million, respectively. During 2016 , we received $ 3 million in cash and realized a tax benefit of $ 4 million from the exercise of options. At December 31, 2016 , the remaining unrecognized compensation expense from unvested options was $ 8 million, which will be recognized over a weighted-average period of 0.91 years , the longest period being 2.13 years . 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 c ompany 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, 2016: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2015 9,178,165 $ 59.80 Granted 4,613,469 32.15 Forfeited (169,018) 30.46 Issued (5,115,112) $ 191 Outstanding at December 31, 2016 8,507,504 $ 48.65 Not Vested at December 31, 2016 5,990,350 $ 48.29 At December 31, 2016 , the remaining unrecognized compensation cost from the unvested units was $ 105 million, which will be recognized over a weighted-average period of 1.59 years , the longest period being 2.82 years . The weighted - average grant date fair value of stock unit awards granted during 2015 and 2014 was $ 65.40 and $ 62.72 , respectively. The total fair value of stock units issued during 2015 and 2014 was $ 316 million and $ 256 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 c ompany. With respect to awards for performance periods beginning in 2009 through 201 2 , 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 c ompany 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 t o 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, 2016: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2015 4,270,222 $ 51.95 Granted 48,065 33.13 Issued (428,763) $ 17 Outstanding at December 31, 2016 3,889,524 $ 51.93 Not Vested at December 31, 2016 606,085 $ 53.34 At December 31, 2016 , the remaining unrecognized compensation cost from unvested stock-settled performance share awards was $ 3 million, which includes $ 1 million related to unvested stock-settled performance share awards tied to Phillips 66 stock held by ConocoPhillips employees, which will be recognized over a weighted-average period of 1.82 years, the longest period being 3.98 years. The w eighted-average grant date fair value of stock-settled PSUs granted during 2015 and 2014 was $ 69.25 and $ 65.46 , respectively. The total fair value of stock-settled PSUs issued during 2015 and 2014 was $ 25 million and $ 18 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 aft er 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 sched uled 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. We r

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2016
Income Taxes [Abstract]
Income Taxes	Note 19 —Income Taxes Income taxes charged to income (loss) from continuing operations were: Millions of Dollars 2016 2015 2014 Income Taxes Federal Current $ (9) (718) 188 Deferred (1,634) (1,443) 365 Foreign Current 393 745 2,846 Deferred (519) (1,315) 252 State and local Current (135) 8 46 Deferred (67) (145) (114) $ (1,971) (2,868) 3,583 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 2016 2015 Deferred Tax Liabilities PP&E and intangibles $ 15,099 16,378 Investment in joint ventures 933 866 Inventory 36 25 Deferred state income tax 203 128 Partnership income deferral - 44 Other 486 453 Total deferred tax liabilities 16,757 17,894 Deferred Tax Assets Benefit plan accruals 1,280 1,160 Asset retirement obligations and accrued environmental costs 3,514 4,426 Other financial accruals and deferrals 317 616 Loss and credit carryforwards 3,522 1,579 Other 250 134 Total deferred tax assets 8,883 7,915 Less: valuation allowance (675) (734) Net deferred tax assets 8,208 7,181 Net deferred tax liabilities $ 8,549 10,713 A t December 31, 2016 , noncurrent assets and liabilities include deferred taxes of $ 400 million and $ 8,949 million , respectively . At December 31, 2015 , noncurrent assets and liabilities include deferred taxes of $ 286 million and $ 10,999 million , respectively . At December 31, 2016, 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. federal net operating loss $ 1,648 $ 1,648 2036 U.S. foreign tax credits 480 296 2025-2026 U.S. general business credits 96 96 2031 State net operating losses and tax credits 502 49 Post 2024 Foreign net operating losses and tax credits 796 783 Post 2025 $ 3,522 $ 2,872 The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2016, 2015 and 2014: Millions of Dollars 2016 2015 2014 Balance at January 1 $ 459 442 655 Additions based on tax positions related to the current year 32 54 46 Additions for tax positions of prior years 19 4 7 Reductions for tax positions of prior years (118) (37) (228) Settlements (9) (4) (28) Lapse of statute (2) - (10) Balance at December 31 $ 381 459 442 Included in the balance of unrecognized tax benefits for 2016 , 2015 and 2014 were $ 359 million, $ 354 million and $ 348 million, respectively, which, if recognized, would impact our effective tax rate. At December 31, 2016 , 2015 and 2014 , accrued liabilities for interest and penalties totaled $ 54 million, $ 79 million and $ 65 million, respectively, net of accrued income taxes. Interest and penalties res ult ed in a benefit to earnings of $ 18 million in 2016 , a reduction to earnings of $ 11 million in 2015 , and a benefit to earnings of $ 43 million in 2014 . We and our subsidiaries file tax returns in the U.S. federal jurisdiction and in many foreign and state jurisdictions. Audits in major jurisdictions are generally complete as follows: United Kingdom (201 4 ), Canada (2009), United States (2010) and Norway (2015) . Issues in dispute for audited years and audi ts 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 fluctuate from period to period. It is r easonably 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) from continuing operations before income taxes, with a reconciliation of tax at the federal statutory rate with the provision for income taxes, were: Percent of Millions of Dollars Pre-Tax Income (Loss) 2016 2015 2014 2016 2015 2014 Income (loss) before income taxes from continuing operations United States $ (4,410) (4,150) 2,310 79.7 % 57.3 24.6 Foreign (1,120) (3,089) 7,080 20.3 42.7 75.4 $ (5,530) (7,239) 9,390 100.0 % 100.0 100.0 Federal statutory income tax $ (1,936) (2,534) 3,287 35.0 % 35.0 35.0 Non-U.S. effective tax rates 365 381 376 (6.6) (5.3) 4.0 Foreign tax law change (161) (426) - 2.9 5.9 - U.S. fair value election - (185) - - 2.6 - Enhanced Oil Recovery Credit (62) - - 1.1 - - State income tax (131) (89) (44) 2.4 1.2 (0.5) Other (46) (15) (36) 0.8 0.2 (0.4) $ (1,971) (2,868) 3,583 35.6 % 39.6 38.1 The decrease in the effective tax rate for 2016 was primarily due to higher income in high tax jurisdicti ons, lower losses in low tax jurisdictions, and reduced net tax benefit from tax law changes. The increase in the effective tax rate for 2015 was primarily due to the U.K. tax law change and electing the fair market value method of apportioning interest expense for prior years, discussed below; partially offset by lower income in high tax jurisdictions and the Canadian tax law change, discussed below. 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, a $ 161 mill ion net tax benefit for revaluing the U.K. deferred tax liability is reflected in the “Income tax provision (benefit)” line on our consolidated income statement. 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, a $ 555 million net tax benefit for revaluing the U.K. deferred tax liability is refle cted in the “ Income tax provision (benefit) ” line on our consolidated income statement. In Canada, legislation was enacted on June 29, 2015 , to increase the overall Canadian corporation tax rate from 25 percent to 27 percent eff ective July 1, 2015 . As a result, a $ 129 million net tax expense for revaluing the Canadian deferred tax liability is reflected in the “ Income tax provision (benefit) ” line on our consolidated income statement . In December 2015 , we fi led refund claims for prior years electing the fair market value method of apportioning interest in the United States. As a result, a $ 185 million tax benefit was recorded in the fourth quarter of 2015 . Certain operating losses in jurisdictions outside of the U.S. only yield a tax benefit in the U.S. as a worthle ss security deduction. For 2016 , 2015 and 2014 th e amount of the benefit was $ 60 million, $ 491 million and $ 122 milli on, respectively.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Accumulated Other Comprehensive Income	Note 20 —Accumulated Other Comprehensive Income Accumulated other comprehensive income (loss) in the equity section of the balance sheet included: Millions of Dollars Defined Benefit Plans Foreign Currency Translation Accumulated Other Comprehensive Income (Loss) December 31, 2013 $ (824) 2,826 2,002 Other comprehensive loss (437) (3,467) (3,904) 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) There were no items within accumulated other comprehensive income (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 2016 2015 Defined Benefit Plans $ 179 251 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 95 133 See Note 18—Employee Benefit Plans, for additional information.

Cash Flow Information

Cash Flow Information	12 Months Ended
	Dec. 31, 2016
Cash Flow Information [Abstract]
Cash Flow Information	Note 21 —Cash Flow Information Amounts included in continuing operations for the years ended December 31 were: Millions of Dollars 2016 2015 2014 Noncash Investing and Financing Activities Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations* $ (1,017) 402 1,611 Cash Payments (Receipts) Interest $ 1,151 920 669 Income taxes** (318) 523 4,203 Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ (1,753) - (876) Short-term investments sold 1,702 - 1,129 $ (51) - 253 *Includes $68 million in 2014, primarily related to the impact of U.K. tax law changes on the deductibility of decommissioning costs. **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, 2016
Other Financial Information [Abstract]
Other Financial Information	Note 22 —Other Financial Information Amounts included in continuing operations for the years ended December 31 were: Millions of Dollars 2016 2015 2014 Interest and Debt Expense Incurred Debt $ 1,279 1,130 1,063 Other 123 84 73 1,402 1,214 1,136 Capitalized (157) (294) (488) Expensed $ 1,245 920 648 Other Income Interest income $ 57 45 83 Other, net 198 80 283 $ 255 125 366 Research and Development Expenditures —expensed $ 116 222 263 Shipping and Handling Costs* $ 1,139 1,181 1,360 *Amounts included in production and operating expenses. Foreign Currency Transaction (Gains) Losses —after-tax Alaska $ - - - Lower 48 - - - Canada 1 - (4) Europe and North Africa (7) (22) (56) Asia Pacific and Middle East (9) (78) - Other International 7 (9) - Corporate and Other (18) 45 16 $ (26) (64) (44) Millions of Dollars 2016 2015 Properties, Plants and Equipment Proved properties $ 119,970 122,796 Unproved properties 5,150 7,410 Other 6,286 6,653 Gross properties, plants and equipment 131,406 136,859 Less: Accumulated depreciation, depletion and amortization (73,075) (70,413) Net properties, plants and equipment $ 58,331 66,446

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Related Party Transactions	Note 23 —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 2016 2015 2014 Operating revenues and other income $ 133 118 119 Purchases 101 97 190 Operating expenses and selling, general and administrative expenses 63 62 70 Net interest (income) expense* (12) (9) (44) *We paid interest to, or received interest from, various affiliates. See Note 7—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies. The table above includes transactions with Freeport LNG through the date of the termination agreement and excludes the termination fee. See Note 7 —Investments, Loans and Long-Term Receivables , for additional information.

Segment Disclosures and Related

Segment Disclosures and Related Information	12 Months Ended
	Dec. 31, 2016
Segment Disclosures and Related Information [Abstract]
Segment Disclosures and Related Information	Note 24 —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. After agreeing to sell our Nigeria business in 2012, we completed the sale in 2014. Results for these o perations have been reported as discontinued operations in the applicable periods presented. For additional information, see Note 3 — Discontinued Operations . Corporate and Other represents costs not directly associated with an operating segment, su ch as most intere st expense, corporate overhead and certain technology activities, including licensing revenues. Corporate assets include all cash and cash equivalents. We evaluate performance and allocate resources based on net income (loss) attributa ble 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 2016 2015 2014 Sales and Other Operating Revenues Alaska $ 3,681 4,351 8,382 Lower 48 10,719 11,976 21,721 Intersegment eliminations (17) (63) (107) Lower 48 10,702 11,913 21,614 Canada 2,192 2,454 5,162 Intersegment eliminations (218) (318) (753) Canada 1,974 2,136 4,409 Europe and North Africa 3,462 6,110 10,665 Intersegment eliminations - (4) (49) Europe and North Africa 3,462 6,106 10,616 Asia Pacific and Middle East 3,705 4,746 7,425 Intersegment eliminations - (1) (1) Asia Pacific and Middle East 3,705 4,745 7,424 Other International - 1 - Corporate and Other 169 312 79 Consolidated sales and other operating revenues $ 23,693 29,564 52,524 Depreciation, Depletion, Amortization and Impairments Alaska $ 868 690 584 Lower 48 4,358 4,227 3,911 Canada 975 788 962 Europe and North Africa 1,253 2,565 2,345 Asia Pacific and Middle East 1,606 2,981 1,275 Other International 1 - 1 Corporate and Other 140 107 107 Consolidated depreciation, depletion, amortization and impairments $ 9,201 11,358 9,185 Millions of Dollars 2016 2015 2014 Equity in Earnings of Affiliates Alaska $ 9 4 9 Lower 48 (6) (5) 1 Canada 89 78 1,385 Europe and North Africa 22 23 37 Asia Pacific and Middle East (51) 550 1,089 Other International - 8 9 Corporate and Other (11) (3) (1) Consolidated equity in earnings of affiliates $ 52 655 2,529 Income Taxes Alaska $ (59) (71) 1,081 Lower 48 (1,328) (1,119) (92) Canada (383) (223) 236 Europe and North Africa (46) (854) 1,590 Asia Pacific and Middle East 306 467 1,194 Other International (40) (456) (102) Corporate and Other (421) (612) (324) Consolidated income taxes $ (1,971) (2,868) 3,583 Net Income (Loss) Attributable to ConocoPhillips Alaska $ 319 4 2,041 Lower 48 (2,257) (1,932) (22) Canada (935) (1,044) 940 Europe and North Africa 394 409 814 Asia Pacific and Middle East 209 (463) 2,939 Other International (16) (593) (100) Corporate and Other (1,329) (809) (874) Discontinued operations - - 1,131 Consolidated net income (loss) attributable to ConocoPhillips $ (3,615) (4,428) 6,869 Investments In and Advances To Affiliates Alaska $ 58 61 53 Lower 48 426 455 471 Canada 8,784 8,165 9,484 Europe and North Africa 62 70 126 Asia Pacific and Middle East 11,611 11,780 14,022 Other International - - 59 Corporate and Other 4 15 15 Consolidated investments in and advances to affiliates $ 20,945 20,546 24,230 Millions of Dollars 2016 2015 2014 Total Assets Alaska $ 12,314 12,555 12,655 Lower 48 22,673 26,932 30,185 Canada 17,548 17,221 21,764 Europe and North Africa 11,727 13,703 16,970 Asia Pacific and Middle East 20,451 22,318 25,976 Other International 97 282 1,116 Corporate and Other 4,962 4,473 7,815 Discontinued operations - - 58 Consolidated total assets $ 89,772 97,484 116,539 Capital Expenditures and Investments Alaska $ 883 1,352 1,564 Lower 48 1,262 3,765 6,054 Canada 698 1,255 2,340 Europe and North Africa 1,020 1,573 2,540 Asia Pacific and Middle East 838 1,812 3,877 Other International 104 173 520 Corporate and Other 64 120 190 Consolidated capital expenditures and investments $ 4,869 10,050 17,085 Interest Income and Expense Interest income Corporate $ 47 36 40 Lower 48 - - 35 Europe and North Africa 2 2 2 Asia Pacific and Middle East 8 6 6 Other International - 1 - Interest and debt expense Corporate $ 1,245 920 648 Sales and Other Operating Revenues by Product Crude oil $ 10,801 12,830 23,784 Natural gas 9,401 11,888 20,717 Natural gas liquids 837 952 2,245 Other* 2,654 3,894 5,778 Consolidated sales and other operating revenues by product $ 23,693 29,564 52,524 *Includes LNG and bitumen. Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2016 2015 2014 2016 2015 2014 United States $ 14,400 16,284 30,019 32,949 37,445 39,641 Australia (3) 1,353 2,127 3,258 12,259 12,788 14,969 Canada 1,974 2,136 4,409 16,846 16,766 20,874 China 551 782 1,701 1,372 1,647 1,913 Indonesia 938 1,165 1,963 856 1,191 1,526 Malaysia 735 598 403 3,323 3,599 3,811 Norway 1,645 2,107 3,794 6,228 6,933 8,142 United Kingdom 1,816 4,005 6,594 3,209 4,154 5,327 Other foreign countries 281 360 383 2,234 2,469 3,471 Worldwide consolidated $ 23,693 29,564 52,524 79,276 86,992 99,674 (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, 2016
New Accounting Standards [Abstract]
Description Of New Accounting Pronouncements Not Yet Adopted [Text Block]	Note 25 —New Accounting Standards In May 2014, the FASB issued 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. Additional disclosures will be re quired 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 effective date of ASU No. 2014-0 9. 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 standard using either a full ret rospective 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 April 2016 by the provisions of AS U 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. 2016-20, “Technical Corrections an d 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 intend to adopt the new standard usi ng 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 retrospectively only to the most curren t period presented in the financial statements. Overall, the impact to our financial statements is expected to be immaterial. In February 2016, the FASB issued ASU No. 2016-02, “Leases” (ASU No. 2016-02), which establishes comprehensive accounting and fi nancial reporting requirements for leasing arrangements. This ASU supersedes the existing requirements in FASB ASC Topic 840, “Leases,” and requires lessees to recognize substantially all lease assets and lease liabilities on the balance sheet. The provi sions 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 beg inning after December 15, 2018, and early adoption of the standard is permitted. Entities 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 period presented in the financial statements. While we continue to evaluate the ASU, we expect the adoption of the ASU to have a material impact on our consolidated finan cial 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 fo r certain 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 A SU 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, 2016
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 May 2014, we filed a universal shelf registration statement with the SEC under which ConocoPhillips, as a well-known seasoned issuer, has the ability to issue and sell an indeterminate amount of various types of debt and equity securities, with certain debt securities guaranteed by ConocoPhillips Company. Also as part of that registration statement, ConocoPhillips Trust I and ConocoPhillips Trust II have the ability to issue and sell preferred trust securitie s, guaranteed by ConocoPhillips. ConocoPhillips Trust I and ConocoPhillips Trust II have not issued any trust-preferred securities under this registration statement, and thus have no assets or liabilities. Accordingly, columns for these two trusts are no t included in the condensed consolidating financial information. In 2014, ConocoPhillips received $34.5 billion in dividends from ConocoPhillips Company to settle certain accumulated intercompany balances. This consisted of a $17.5 billion distribution o f earnings and a $17 billion return of capital. These transactions had no impact on our consolidated financial statements. 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 statements. In 2016, ConocoPhillips received a $2.3 billion return of capital from C onocoPhillips Company to settle certain accumulated intercompany balances. The transaction had no impact on our consolidated financial statements. In 20 16, ConocoPhillips Canada Funding Company I repaid $1.25 billion of external debt . This transaction is reflected in our conso lidated 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, 2016 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 $ - 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 (loss) 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 from continuing operations 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) 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) Income Statement Year Ended December 31, 2015 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) from continuing operations 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 Year Ended December 31, 2014 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 $ - 20,083 - 32,441 - 52,524 Equity in earnings of affiliates 6,108 8,090 - 2,932 (14,601) 2,529 Gain on dispositions - 9 - 89 - 98 Other income (loss) (6) 67 - 305 - 366 Intercompany revenues 79 465 283 5,883 (6,710) - Total Revenues and Other Income 6,181 28,714 283 41,650 (21,311) 55,517 Costs and Expenses Purchased commodities - 17,591 - 10,415 (5,907) 22,099 Production and operating expenses - 2,600 - 6,368 (59) 8,909 Selling, general and administrative expenses 9 575 1 166 (16) 735 Exploration expenses - 1,036 - 1,009 - 2,045 Depreciation, depletion and amortization - 1,059 - 7,270 - 8,329 Impairments - 127 - 729 - 856 Taxes other than income taxes - 285 - 1,803 - 2,088 Accretion on discounted liabilities - 58 - 426 - 484 Interest and debt expense 571 299 231 275 (728) 648 Foreign currency transaction (gains) losses 62 10 (372) 234 - (66) Total Costs and Expenses 642 23,640 (140) 28,695 (6,710) 46,127 Income from continuing operations before income taxes 5,539 5,074 423 12,955 (14,601) 9,390 Income tax provision (benefit) (199) (1,034) 19 4,797 - 3,583 Income From Continuing Operations 5,738 6,108 404 8,158 (14,601) 5,807 Income from discontinued operations 1,131 1,131 - 113 (1,244) 1,131 Net income 6,869 7,239 404 8,271 (15,845) 6,938 Less: net income attributable to noncontrolling interests - - - (69) - (69) Net Income Attributable to ConocoPhillips $ 6,869 7,239 404 8,202 (15,845) 6,869 Comprehensive Income Attributable to ConocoPhillips $ 2,965 3,335 58 4,589 (7,982) 2,965 Millions of Dollars At December 31, 2016 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated 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 Balance Sheet At December 31, 2015 Assets Cash and cash equivalents $ - 4 15 2,349 - 2,368 Accounts and notes receivable 21 2,905 21 7,228 (5,661) 4,514 Inventories - 142 - 982 - 1,124 Prepaid expenses and other current assets 2 206 252 589 (266) 783 Total Current Assets 23 3,257 288 11,148 (5,927) 8,789 Investments, loans and long-term receivables* 43,532 64,015 3,264 27,839 (117,464) 21,186 Net properties, plants and equipment - 8,110 - 58,336 - 66,446 Other assets 7 950 233 1,158 (1,285) 1,063 Total Assets $ 43,562 76,332 3,785 98,481 (124,676) 97,484 Liabilities and Stockholders’ Equity Accounts payable $ - 5,684 13 4,897 (5,661) 4,933 Short-term debt (9) 1 1,255 180 - 1,427 Accrued income and other taxes - 62 - 437 - 499 Employee benefit obligations - 629 - 258 - 887 Other accruals 170 465 52 1,087 (264) 1,510 Total Current Liabilities 161 6,841 1,320 6,859 (5,925) 9,256 Long-term debt 7,518 10,660 1,716 3,559 - 23,453 Asset retirement obligations and accrued environmental costs - 1,107 - 8,473 - 9,580 Deferred income taxes - - - 11,814 (815) 10,999 Employee benefit obligations - 1,760 - 526 - 2,286 Other liabilities and deferred credits* 2,681 7,291 667 15,181 (23,992) 1,828 Total Liabilities 10,360 27,659 3,703 46,412 (30,732) 57,402 Retained earnings 29,892 17,366 (389) 15,177 (25,632) 36,414 Other common stockholders’ equity 3,310 31,307 471 36,572 (68,312) 3,348 Noncontrolling interests - - - 320 - 320 Total Liabilities and Stockholders’ Equity $ 43,562 76,332 3,785 98,481 (124,676) 97,484 *Includes intercompany loans. Millions of Dollars Statement of Cash Flows Year Ended December 31, 2016 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 $ (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 sales 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 Statement of Cash Flows Year Ended December 31, 2015 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 Millions of Dollars Statement of Cash Flows Year Ended December 31, 2014 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) continuing operating activities $ 17,259 2,948 27 16,941 (20,763) 16,412 Net cash provided by discontinued operations - 202 - 408 (453) 157 Net Cash Provided by (Used in) Operating Activities 17,259 3,150 27 17,349 (21,216) 16,569 Cash Flows From Investing Activities Capital expenditures and investments - (6,507) - (14,840) 4,262 (17,085) Working capital changes associated with investing activities - 17 - 163 - 180 Proceeds from asset dispositions 16,912 1,588 - 253 (17,150) 1,603 Net purchases of short-term investments - - - 253 - 253 Long-term advances/loans—related parties - (736) (241) (7) 984 - Collection of advances/loans—related parties - 593 - 112 (102) 603 Intercompany cash management (29,113) 31,993 - (2,880) - - Other - (415) - (31) - (446) Net cash provided by (used in) continuing investing activities (12,201) 26,533 (241) (16,977) (12,006) (14,892) Net cash provided by (used in) discontinued operations - 133 - (73) (133) (73) Net Cash Provided by (Used in) Investing Activities (12,201) 26,666 (241) (17,050) (12,139) (14,965) Cash Flows From Financing Activities Issuance of debt - 2,994 - 984 (984) 2,994 Repayment of debt (1,909) (16) - (191) 102 (2,014) Issuance of company common stock 377 - - - (342) 35 Dividends paid (3,525) (17,588) - (3,768) 21,356 (3,525) Other (1) (16,870) - 3,919 12,888 (64) Net cash used in continuing financing activities (5,058) (31,480) - 944 33,020 (2,574) Net cash used in discontinued operations - - - (335) 335 - Net Cash Used in Financing Activities (5,058) (31,480) - 609 33,355 (2,574) Effect of Exchange Rate Changes on Cash and Cash Equivalents - - (8) (206) - (214) Net Change in Cash and Cash Equivalents - (1,664) (222) 702 - (1,184) Cash and cash equivalents at beginning of period - 2,434 229 3,583 - 6,246 Cash and Cash Equivalents at End of Period $ - 770 7 4,285 - 5,062

Schedule ll

Schedule ll	12 Months Ended
	Dec. 31, 2016
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 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) (c) 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) (c) 156 2014 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 8 - (2) (1) (b) 5 Deferred tax asset valuation allowance 969 127 (26) (100) 970 Included in other liabilities: Restructuring accruals 19 71 (6) (23) (c) 61 (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)Benefit payments.

Accounting Policies (Policies)

Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2016
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 24 —Segment Disclosures and Related Information. Unless indicated otherwise, the information in the Notes to the Consolidated Financial Statements relates to our continuing operations.
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 earnings. Most of our foreign operations use their local currency as the functional currency.
Use of Estimates	Use of Estimates — The preparatio n 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 disclos ures 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 recogn ized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry. Revenues ass ociated 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, whic h are deemed to be nonrecoverable through remaining production, are recognized as accounts receivable or accounts payable, as appropriate. 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 li ne) .
Shipping and Handling Costs	Shipping and Handling Costs — We include shipping and handling costs in production and operating expenses for production activities. Transportation costs related to marketing activities are recorded in purchased commodities. Freight costs billed to cu stomers 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 inventories and consistently use the following methods for each type of inventory. Commodity-related inventories are valued at the lower of cost or market in the aggregate, primarily on the last-in, first-out (LIFO) basis. 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 m atch current inventory costs with current revenues. Costs include both direct and indirect expenditures 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 equipment, 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	F air Value Measurements — A ssets and liabilities measured at fair value and required to be categorized 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. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corrob orated 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 other criteria are met, derivative assets and liabilities with the same counterparty are netted on the balance sheet and the collateral payable or receivable is net ted 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. G ains and losses from derivatives not accounted for as hedges are recognized immediately in earnings. For derivative instruments that are designated and qualify as a fair value hedge, the gains or losses from adjusting the derivative to its fair value will be immediately recognized in earnings and, to the extent the hedge is effective, offset the concurrent recognition of changes in the fair value of the hedged item.
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 res erves have been found. If economically recoverable reserves are not found, exploratory well costs are expensed as dry holes. If exploratory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance s heet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For complex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on the balance sheet for se veral years while we perform additional appraisal drilling and seismic work on the potential oil and gas field or while we seek government or co-venturer approval of development plans or seek environmental permitting. Once all required approvals and permi ts have been obtained, the projects are moved into the development phase, and the oil and gas resources are designated as proved reserves. 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 8 —Suspended Wells and Other Exploration Expenses , f or 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 interest is added to the cost of the underlying asset and is amortized over the useful lives of the assets in the same manne r as the underlying assets.
Depreciation and Amortization	Depreciation and Amortization — Depreciation and amortization of PP&E on producing hydrocarbon properties and certain pipeline assets (those which are expected to have a declining utilization pattern), are determined by the unit-o f-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 o f 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 updat es 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 future 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 dep reciation 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 in dependent 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 determined 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 similar 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 av ailable, 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 available 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 reserves 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 wri tten 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 p articipants, 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 deprecia ble 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 l ong-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 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 is increased for the change in its present value, and the capitalized cost in PP&E is de preciated over the useful life of the related asset. For additional information, see Note 10 —Asset Retirement Obligations and Accrued Environmental C osts . Environmental expenditures are expensed or capitalized, depending upon their future economic b enefit. 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 b usiness 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 the ir 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 nature 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 there 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 ear n the award) or the period beginning at the start of 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 liabilit ies, except for deferred taxes on income and temporary 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 app lied currently as reductions of the provision for income 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 Governmental Authorities — S ales and value-added taxes are recorded net.
Net Income 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 participating securities. Diluted net income per share of common stock includes unvested stock, unit or option awards granted under our compensation plans and vested but unexercise d 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 from the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the pa rticipating securities is immaterial.

Discontinured Operations (Table

Discontinured Operations (Tables)	12 Months Ended
	Dec. 31, 2016
Discontinued Operations and Disposal Groups [Abstract]
The carrying value of the major categories of assets and liabilities and operting results	Sales and other operating revenues and income from discontinued operations related to the Nigeria business during 2014 were as follows: Millions of Dollars 2014 Sales and other operating revenues from discontinued operations $ 480 Income from discontinued operations before-tax $ 1,147 Income tax expense 16 Income from discontinued operations $ 1,131

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2016
Inventories [Abstract]
Inventories	Note 5 —Inventories Inventories at December 31 were: Millions of Dollars 2016 2015 Crude oil and natural gas $ 418 406 Materials and supplies 600 718 $ 1,018 1,124

Investments, Loans and Long-T39

Investments, Loans and Long-Term Receivables (Tables)	12 Months Ended
	Dec. 31, 2016
Investments, Loans and Long-Term Receivables and Joint Venture Acquisition Obligation [Abstract]
Components of investments, loans and long-term receivables	Note 7 —Investments, Loans and Long-Term Receivables Components of investments, loans and long-term receivables at December 31 were: Millions of Dollars 2016 2015 Equity investments $ 20,364 19,850 Loans and advances—related parties 581 696 Long-term receivables 631 519 Other investments 96 121 $ 21,672 21,186
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 2016 2015 2014 Revenues $ 10,149 11,003 19,243 Income before income taxes 660 1,866 6,746 Net income 799 1,801 6,630 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2016 2015 Current assets $ 3,578 2,504 Noncurrent assets 60,243 58,431 Current liabilities 2,352 1,863 Noncurrent liabilities 23,764 24,820

Suspended Wells (Tables)

Suspended Wells (Tables)	12 Months Ended
	Dec. 31, 2016
Suspended Wells [Abstract]
Net changes in suspended exploratory well costs	Note 8 —Suspended Wells and Other Exploration Expenses The following table reflects the net changes in suspended exploratory well costs during 2016, 2015 and 2014: Millions of Dollars 2016 2015 2014 Beginning balance at January 1 $ 1,260 1,299 994 Additions pending the determination of proved reserves 225 331 478 Reclassifications to proved properties (27) (28) (9) Sales of suspended well investment (247) - (57) Charged to dry hole expense (148) (342) (107) Ending balance at December 31 $ 1,063 1,260 1,299
Aging of suspended well cost	The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2016 2015 2014 Exploratory well costs capitalized for a period of one year or less $ 132 235 466 Exploratory well costs capitalized for a period greater than one year 931 1,025 833 Ending balance $ 1,063 1,260 1,299 Number of projects with exploratory well costs capitalized for a period greater than one year 26 28 30
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, 2016: Millions of Dollars Suspended Since Total 2013–2015 2010–2012 2002–2009 Greater Poseidon—Australia (2) 177 157 15 5 Shenandoah—Lower 48 (1) 161 118 - 43 Greater Clair—UK (2) 131 120 11 - Surmont 3 and beyond—Canada (1) 107 55 29 23 NPRA—Alaska (1) 93 70 - 23 Caldita/Barossa—Australia (1) 77 - - 77 Middle Magdalena Basin—Colombia (1) 31 31 - - Limbayong—Malaysia (1) 23 23 - - Alpine Satellite—Alaska (2) 22 - - 22 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 25 3 15 Total $ 931 648 58 225 (1)Additional appraisal wells planned. (2)Appraisal drilling complete; costs being incurred to assess development.

Impairments (Tables)

Impairments (Tables)	12 Months Ended
	Dec. 31, 2016
Impairment Of Long Lived Assets [Abstract]
Impairment Charges By Segment Before Tax	Note 9 —Impairments During 2016, 2015 and 2014, we recognized the following before-tax impairment charges: Millions of Dollars 2016 2015 2014 Alaska $ 1 10 59 Lower 48 149 (2) 208 Canada 88 4 38 Europe and North Africa (160) 724 541 Asia Pacific and Middle East 44 1,508 7 Corporate 17 1 3 $ 139 2,245 856

Asset Retirement Obligations 42

Asset Retirement Obligations and Accrued Environmental Costs (Tables)	12 Months Ended
	Dec. 31, 2016
Asset Retirement Obligations and Accrued Environmental Costs [Abstract]
Asset retirement obligations and accrued environmental costs	Note 10 —Asset Retirement Obligations and Accrued Environmental Costs Asset retirement obligations and accrued environmental costs at December 31 were: Millions of Dollars 2016 2015 Asset retirement obligations $ 8,405 9,911 Accrued environmental costs 247 258 Total asset retirement obligations and accrued environmental costs 8,652 10,169 Asset retirement obligations and accrued environmental costs due within one year* (227) (589) Long-term asset retirement obligations and accrued environmental costs $ 8,425 9,580 *Classified as a current liability on the balance sheet under "Other accruals."
Changes in overall asset retirement obligation changed	During 2016 and 2015, our overall asset retirement obligation changed as follows: Millions of Dollars 2016 2015 Balance at January 1 $ 9,911 10,939 Accretion of discount 420 480 New obligations 180 135 Changes in estimates of existing obligations (1,197) 267 Spending on existing obligations (314) (437) Property dispositions (150) (726) Foreign currency translation (464) (747) Other 19 - Balance at December 31 $ 8,405 9,911

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2016
Debt [Abstract]
Long-term debt	Note 11 —Debt Long-term debt at December 31 was: Millions of Dollars 2016 2015 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 297 297 6.50% Notes due 2039 2,750 2,750 6.00% Notes due 2020 1,000 1,000 5.951% Notes due 2037 645 645 5.95% Notes due 2036 500 500 5.95% Notes due 2046 500 - 5.90% Notes due 2032 505 505 5.90% Notes due 2038 600 600 5.75% Notes due 2019 2,250 2,250 5.625% Notes due 2016 - 1,250 5.20% Notes due 2018 500 500 4.95% Notes due 2026 1,250 - 4.30% Notes due 2044 750 750 4.20% Notes due 2021 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 750 750 1.05% Notes due 2017 1,000 1,000 Floating rate term loan due 2019 at 1.94% – 2.31% during 2016 1,450 - Floating rate notes due 2018 at 0.69% – 1.24% during 2016 250 250 and 0.61% – 0.69% during 2015 Floating rate notes due 2022 at 1.26% – 1.81% during 2016 500 500 and 1.18% – 1.26% during 2015 Commercial paper at 0.16% – 0.80% during 2015 - 803 Industrial Development Bonds due 2016 through 2038 at 0.01% – 0.91% during 2016 and 0.01% – 0.13% during 2015 18 18 Marine Terminal Revenue Refunding Bonds due 2031 at 0.01% – 0.95% during 2016 and 0.01% – 0.14% during 2015 265 265 Other 24 24 Debt at face value 26,175 23,778 Capitalized leases 852 818 Net unamortized premiums, discounts and debt issuance costs 248 284 Total debt 27,275 24,880 Short-term debt (1,089) (1,427) Long-term debt $ 26,186 23,453
Capital lease payment table	At December 31, 2016, future minimum payments due under capital leases were: Millions of Dollars 2017 $ 121 2018 102 2019 102 2020 103 2021 88 Remaining years 590 Total 1,106 Less: portion representing imputed interest (254) Capital lease obligations $ 852

Derivative and Financial Inst44

Derivative and Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2016
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 2016 2015 Assets Prepaid expenses and other current assets $ 268 768 Other assets 44 60 Liabilities Other accruals 300 754 Other liabilities and deferred credits 34 46 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 2016 2015 Assets Prepaid expenses and other current assets $ 1 47 Liabilities Other accruals 168 8
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 2016 2015 2014 Sales and other operating revenues $ (198) 231 523 Other income (1) 2 1 Purchased commodities 161 (201) (458) 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 2016 2015 2014 Foreign currency transaction (gains) losses $ 247 (33) 3
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) 2016 2015 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (31) (14) Basis 2 (17) We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency 2016 2015 Foreign Currency Exchange Derivatives Sell U.S. dollar, buy other currencies* USD 13 347 Buy U.S. dollar, sell other currencies** USD 25 20 Buy British pound, sell other currencies*** GBP 1,069 567 Sell British pound, buy Norwegian krone GBP 51 - *Primarily Canadian dollar, Norwegian krone and British pound. **Primarily Canadian dollar and British pound. ***Primarily Canadian dollar and Euro.
Net carrying amount of held to maturity investments	Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments 2016 2015 2016 2015 Cash $ 623 528 - - Time deposits Remaining maturities from 1 to 90 days 2,987 1,840 39 - Remaining maturities from 91 to 180 days - - 11 - $ 3,610 2,368 50 -

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2016
Fair Value Measurement [Abstract]
Fair value hierarchy for gross financial assets and liabilities	Millions of Dollars December 31, 2016 December 31, 2015 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Commodity derivatives $ 194 96 22 312 516 242 70 828 Total assets $ 194 96 22 312 516 242 70 828 Liabilities Commodity derivatives $ 207 105 22 334 515 273 12 800 Total liabilities $ 207 105 22 334 515 273 12 800
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, 2016 Assets $ 312 221 91 - 5 86 Liabilities 334 221 113 12 12 89 December 31, 2015 Assets $ 828 600 228 - 8 220 Liabilities 800 600 200 1 11 188 At December 31, 2016 and December 31, 2015, 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 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, 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 Year ended December 31, 2015 Net PP&E (held for use) March 31, 2015 $ - - - 9 June 30, 2015 42 - 42 70 September 30, 2015 - - - 7 December 31, 2015 440 - 440 595 Net PP&E (unproved property) September 30, 2015 104 - 104 240 Equity method investments December 31, 2015 10,210 - 10,210 1,507
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 2016 2015 2016 2015 Financial assets Commodity derivatives $ 91 228 91 228 Total loans and advances—related parties 701 808 701 808 Financial liabilities Total debt, excluding capital leases 26,423 24,062 29,307 24,785 Commodity derivatives 101 199 101 199

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Changes in shares of common stock	Note 16 —Equity Common Stock The changes in our shares of common stock, as categorized in the equity section of the balance sheet, were: Shares 2016 2015 2014 Issued Beginning of year 1,778,226,388 1,773,583,368 1,768,169,906 Distributed under benefit plans 3,852,719 4,643,020 5,413,462 End of year 1,782,079,107 1,778,226,388 1,773,583,368 Held in Treasury Beginning of year 542,230,673 542,230,673 542,230,673 Repurchase of common stock 2,579,098 - - End of year 544,809,771 542,230,673 542,230,673

Non Mineral Leases (Tables)

Non Mineral Leases (Tables)	12 Months Ended
	Dec. 31, 2016
Leases [Abstract]
Future minimum rental payments due under noncancelable leases	At December 31, 2016, future minimum rental payments due under noncancelable leases were: Millions of Dollars 2017 $ 277 2018 238 2019 172 2020 390 2021 114 Remaining years 435 Total 1,626 Less: income from subleases (15) Net minimum operating lease payments $ 1,611
Operating leases rental expense	Operating lease rental expense for the years ended December 31 was: Millions of Dollars 2016 2015 2014 Total rentals $ 537 432 474 Less: sublease rentals (8) (9) (10) $ 529 423 464

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2016
Employee Benefit Plans [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 2016 2015 2016 2015 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 3,772 3,321 4,387 3,984 352 716 Service cost 108 76 138 124 2 4 Interest cost 133 120 161 135 13 22 Plan participant contributions - 3 - 5 24 21 Plan amendments - - - - (27) (303) Actuarial (gain) loss 247 466 (212) (442) (14) (49) Benefits paid (872) (148) (729) (162) (68) (63) Curtailment 14 10 27 (43) 3 8 Settlement - (46) - - - - Recognition of termination benefits 14 1 - 68 - - Foreign currency exchange rate change - (358) - (348) 1 (4) Benefit obligation at December 31* $ 3,416 3,445 3,772 3,321 286 352 *Accumulated benefit obligation portion of above at 3,246 3,067 3,573 2,953 December 31: $ Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 2,606 3,063 3,266 3,278 - - Actual return on plan assets 133 397 (4) 96 - - Company contributions 214 125 73 120 44 42 Plan participant contributions - 3 - 5 24 21 Benefits paid (872) (148) (729) (162) (68) (63) Foreign currency exchange rate change - (372) - (274) - - Fair value of plan assets at December 31 $ 2,081 3,068 2,606 3,063 - - Funded Status $ (1,335) (377) (1,166) (258) (286) (352)
Weighted-Average Assumptions Used to Determine Benefit Obligations and Net Periodic Benefit Cost	Millions of Dollars Pension Benefits Other Benefits 2016 2015 2016 2015 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 164 - 175 - - Current liabilities (101) (7) (99) (34) (44) (45) Noncurrent liabilities (1,234) (534) (1,067) (399) (242) (307) Total recognized $ (1,335) (377) (1,166) (258) (286) (352) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 3.95 % 3.00 4.50 3.95 3.60 3.90 Rate of compensation increase 4.00 3.85 4.00 4.05 - - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.90 % 3.95 4.00 3.55 3.75 4.05 Expected return on plan assets 7.00 5.45 7.00 5.40 - - Rate of compensation increase 4.00 4.05 4.75 4.35 - -
Sources of change in other comprehensive income	Millions of Dollars Pension Benefits Other Benefits 2016 2015 2016 2015 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ (263) (232) 61 490 14 41 Amortization of (gain) loss included in net loss* 288 26 312 89 (5) 2 Net change during the period $ 25 (206) 373 579 9 43 Prior service credit (cost) arising during the period $ - (4) - (2) 27 303 Amortization of prior service cost (credit) included in net loss 5 (6) 7 (11) (34) (15) Net change during the period $ 5 (10) 7 (13) (7) 288 *Includes settlement losses recognized in 2016 and 2015.
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 2016 2015 2016 2015 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial (gain) loss $ 748 479 773 273 (27) (18) Unrecognized prior service cost (credit) 4 (20) 9 (30) (285) (292) Included in accumulated other comprehensive income (loss) at December 31, 2016, were the following before- tax amounts that are expected to be amortized into net periodic benefit cost during 2017: Millions of Dollars Pension Other Benefits Benefits U.S. Int’l. Unrecognized net actuarial (gain) loss $ 75 48 (3) Unrecognized prior service cost (credit) 4 (5) (36)
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 2016 2015 2014 2016 2015 2014 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 108 76 138 124 124 109 2 4 3 Interest cost 133 120 161 135 165 166 13 22 29 Expected return on plan assets (149) (147) (201) (164) (213) (181) - - - Amortization of prior service cost (credit) 5 (6) 6 (7) 6 (8) (34) (17) (4) Recognized net actuarial loss (gain) 86 26 115 82 77 57 (2) 2 (3) Settlements 202 - 197 7 - - - - - Curtailment (gain) loss 14 - 35 (4) - - 1 2 - Net periodic benefit cost $ 399 69 451 173 159 143 (20) 13 25
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 2016 Equity Securities U.S. $ 632 - 14 646 628 - - 628 International 342 - - 342 428 - - 428 Common/collective trusts 62 - - 62 - 156 - 156 Mutual funds - - - - 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. 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 2015 Equity Securities U.S. $ 777 3 2 782 609 - - 609 International 485 - - 485 450 - - 450 Common/collective trusts - - - - - 214 - 214 Mutual funds - - - - 234 106 - 340 Debt Securities Government 85 56 - 141 493 - - 493 Corporate - 331 17 348 - - - - Agency and mortgage-backed securities - 80 - 80 - - - - Common/collective trusts - - - - - 406 - 406 Mutual funds - - - - 136 - - 136 Cash and cash equivalents - - - - 46 - - 46 Derivatives - (7) - (7) (26) - - (26) Real estate - - - - - - 104 104 Total in fair value hierarchy $ 1,347 463 19 1,829 1,942 726 104 2,772 Investments measured at net asset value* Equity Securities Common/collective trusts $ - - - 569 - - - - Debt Securities Corporate - - - - - - - 172 Agency and mortgage-backed securities - - - - - - - 36 Cash and cash equivalents - - - 60 - - - 10 Real estate - - - 63 - - - 65 Total** $ 1,347 463 19 2,521 1,942 726 104 3,055 *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 $125 million and net payables related to security transactions of $32 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. 2017 $ 352 116 42 2018 290 131 39 2019 287 124 36 2020 277 129 34 2021 292 137 30 2022–2026 1,374 729 109
Share-based compensation expense recognized in income and the associated tax benefit	Compensation Expense — Total share-based compensation expense recognized in income (loss) and the associated tax benefit for the years ended December 31 were as follows: Millions of Dollars 2016 2015 2014 Compensation cost $ 272 362 358 Tax benefit 92 123 125
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: 2016 2015 2014 Assumptions used Risk-free interest rate 1.55 % 1.79 1.86 Dividend yield 4.00 % 4.00 4.00 Volatility factor 26.80 % 23.32 25.31 Expected life (years) 6.37 5.79 6.12
Summary of stock option activity	The following summarizes our stock option activity for the year ended December 31, 2016: Weighted- Weighted- Average Millions of Dollars Average Grant Date Aggregate Options Exercise Price Fair Value Intrinsic Value Outstanding at December 31, 2015 20,184,810 $ 55.88 $ 42 Granted 4,434,400 33.13 $ 5.39 Exercised (62,536) 48.80 - Forfeited (272,646) 34.51 Expired or cancelled (571,916) 45.46 Outstanding at December 31, 2016 23,712,112 $ 52.14 $ 128 Vested at December 31, 2016 20,192,822 $ 52.85 $ 93 Exercisable at December 31, 2016 15,932,144 $ 53.56 $ 55 The following summarizes our stock unit activity for the year ended December 31, 2016: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2015 9,178,165 $ 59.80 Granted 4,613,469 32.15 Forfeited (169,018) 30.46 Issued (5,115,112) $ 191 Outstanding at December 31, 2016 8,507,504 $ 48.65 Not Vested at December 31, 2016 5,990,350 $ 48.29
Summary of Performance Share Program activity	The following summarizes our stock-settled Performance Share Program activity for the year ended December 31, 2016: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2015 4,270,222 $ 51.95 Granted 48,065 33.13 Issued (428,763) $ 17 Outstanding at December 31, 2016 3,889,524 $ 51.93 Not Vested at December 31, 2016 606,085 $ 53.34 The following summarizes our cash-settled Performance Share Program activity for the year ended December 31, 2016: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2015 1,459,236 $ 46.54 Granted 684,386 33.13 Settled (868,860) $ 31 Outstanding at December 31, 2016 1,274,762 $ 50.39 Not Vested at December 31, 2016 584,789 $ 50.39
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, 2016: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2015 1,272,136 $ 33.25 Granted 99,300 40.36 Cancelled (15,964) 20.69 Issued (37,508) $ 2 Outstanding at December 31, 2016 1,317,964 $ 33.16 Not Vested at December 31, 2016 -
Severance accrual	Millions of Dollars Balance at December 31, 2015 $ 156 Accruals 129 Benefit payments (206) Foreign currency translation adjustments 1 Balance at December 31, 2016 $ 80

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2016
Income Taxes [Abstract]
Income taxes charged to income (loss)	Note 19 —Income Taxes Income taxes charged to income (loss) from continuing operations were: Millions of Dollars 2016 2015 2014 Income Taxes Federal Current $ (9) (718) 188 Deferred (1,634) (1,443) 365 Foreign Current 393 745 2,846 Deferred (519) (1,315) 252 State and local Current (135) 8 46 Deferred (67) (145) (114) $ (1,971) (2,868) 3,583
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 2016 2015 Deferred Tax Liabilities PP&E and intangibles $ 15,099 16,378 Investment in joint ventures 933 866 Inventory 36 25 Deferred state income tax 203 128 Partnership income deferral - 44 Other 486 453 Total deferred tax liabilities 16,757 17,894 Deferred Tax Assets Benefit plan accruals 1,280 1,160 Asset retirement obligations and accrued environmental costs 3,514 4,426 Other financial accruals and deferrals 317 616 Loss and credit carryforwards 3,522 1,579 Other 250 134 Total deferred tax assets 8,883 7,915 Less: valuation allowance (675) (734) Net deferred tax assets 8,208 7,181 Net deferred tax liabilities $ 8,549 10,713
Reconciliation of the beginning and ending unrecognized tax benefits	The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2016, 2015 and 2014: Millions of Dollars 2016 2015 2014 Balance at January 1 $ 459 442 655 Additions based on tax positions related to the current year 32 54 46 Additions for tax positions of prior years 19 4 7 Reductions for tax positions of prior years (118) (37) (228) Settlements (9) (4) (28) Lapse of statute (2) - (10) Balance at December 31 $ 381 459 442
Amounts of U.S. and foreign income (loss) before income taxes	The amounts of 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, were: Percent of Millions of Dollars Pre-Tax Income (Loss) 2016 2015 2014 2016 2015 2014 Income (loss) before income taxes from continuing operations United States $ (4,410) (4,150) 2,310 79.7 % 57.3 24.6 Foreign (1,120) (3,089) 7,080 20.3 42.7 75.4 $ (5,530) (7,239) 9,390 100.0 % 100.0 100.0 Federal statutory income tax $ (1,936) (2,534) 3,287 35.0 % 35.0 35.0 Non-U.S. effective tax rates 365 381 376 (6.6) (5.3) 4.0 Foreign tax law change (161) (426) - 2.9 5.9 - U.S. fair value election - (185) - - 2.6 - Enhanced Oil Recovery Credit (62) - - 1.1 - - State income tax (131) (89) (44) 2.4 1.2 (0.5) Other (46) (15) (36) 0.8 0.2 (0.4) $ (1,971) (2,868) 3,583 35.6 % 39.6 38.1
ComponentsofCarryforwardsTableTextBlock	At December 31, 2016, 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. federal net operating loss $ 1,648 $ 1,648 2036 U.S. foreign tax credits 480 296 2025-2026 U.S. general business credits 96 96 2031 State net operating losses and tax credits 502 49 Post 2024 Foreign net operating losses and tax credits 796 783 Post 2025 $ 3,522 $ 2,872

Accumulated Other Comprehensi50

Accumulated Other Comprehensive Income (Tables)	12 Months Ended
	Dec. 31, 2016
Equity [Abstract]
Accumulated other comprehensive income in the equity section of the balance sheet included	Note 20 —Accumulated Other Comprehensive Income Accumulated other comprehensive income (loss) in the equity section of the balance sheet included: Millions of Dollars Defined Benefit Plans Foreign Currency Translation Accumulated Other Comprehensive Income (Loss) December 31, 2013 $ (824) 2,826 2,002 Other comprehensive loss (437) (3,467) (3,904) 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) There were no items within accumulated other comprehensive income (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 2016 2015 Defined Benefit Plans $ 179 251 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 95 133 See Note 18—Employee Benefit Plans, for additional information.

Cash Flow Information (Tables)

Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2016
Cash Flow Information [Abstract]
Cash Flow Information	Note 21 —Cash Flow Information Amounts included in continuing operations for the years ended December 31 were: Millions of Dollars 2016 2015 2014 Noncash Investing and Financing Activities Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations* $ (1,017) 402 1,611 Cash Payments (Receipts) Interest $ 1,151 920 669 Income taxes** (318) 523 4,203 Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ (1,753) - (876) Short-term investments sold 1,702 - 1,129 $ (51) - 253 *Includes $68 million in 2014, primarily related to the impact of U.K. tax law changes on the deductibility of decommissioning costs. **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, 2016
Other Financial Information [Abstract]
Other Financial Information	Note 22 —Other Financial Information Amounts included in continuing operations for the years ended December 31 were: Millions of Dollars 2016 2015 2014 Interest and Debt Expense Incurred Debt $ 1,279 1,130 1,063 Other 123 84 73 1,402 1,214 1,136 Capitalized (157) (294) (488) Expensed $ 1,245 920 648 Other Income Interest income $ 57 45 83 Other, net 198 80 283 $ 255 125 366 Research and Development Expenditures —expensed $ 116 222 263 Shipping and Handling Costs* $ 1,139 1,181 1,360 *Amounts included in production and operating expenses. Foreign Currency Transaction (Gains) Losses —after-tax Alaska $ - - - Lower 48 - - - Canada 1 - (4) Europe and North Africa (7) (22) (56) Asia Pacific and Middle East (9) (78) - Other International 7 (9) - Corporate and Other (18) 45 16 $ (26) (64) (44)
Property, Plant And Equipment [Table Text Block]	Millions of Dollars 2016 2015 Properties, Plants and Equipment Proved properties $ 119,970 122,796 Unproved properties 5,150 7,410 Other 6,286 6,653 Gross properties, plants and equipment 131,406 136,859 Less: Accumulated depreciation, depletion and amortization (73,075) (70,413) Net properties, plants and equipment $ 58,331 66,446

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2016
Related Party Transactions [Abstract]
Significant transactions with related parties	Note 23 —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 2016 2015 2014 Operating revenues and other income $ 133 118 119 Purchases 101 97 190 Operating expenses and selling, general and administrative expenses 63 62 70 Net interest (income) expense* (12) (9) (44) *We paid interest to, or received interest from, various affiliates. See Note 7—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Segment Disclosures and Relat54

Segment Disclosures and Related Information (Tables)	12 Months Ended
	Dec. 31, 2016
Segment Disclosures and Related Information [Abstract]
Sales and Other Operating Revenues	Analysis of Results by Operating Segment Millions of Dollars 2016 2015 2014 Sales and Other Operating Revenues Alaska $ 3,681 4,351 8,382 Lower 48 10,719 11,976 21,721 Intersegment eliminations (17) (63) (107) Lower 48 10,702 11,913 21,614 Canada 2,192 2,454 5,162 Intersegment eliminations (218) (318) (753) Canada 1,974 2,136 4,409 Europe and North Africa 3,462 6,110 10,665 Intersegment eliminations - (4) (49) Europe and North Africa 3,462 6,106 10,616 Asia Pacific and Middle East 3,705 4,746 7,425 Intersegment eliminations - (1) (1) Asia Pacific and Middle East 3,705 4,745 7,424 Other International - 1 - Corporate and Other 169 312 79 Consolidated sales and other operating revenues $ 23,693 29,564 52,524
Depreciation, Depletion, Amortization and Impairments	Depreciation, Depletion, Amortization and Impairments Alaska $ 868 690 584 Lower 48 4,358 4,227 3,911 Canada 975 788 962 Europe and North Africa 1,253 2,565 2,345 Asia Pacific and Middle East 1,606 2,981 1,275 Other International 1 - 1 Corporate and Other 140 107 107 Consolidated depreciation, depletion, amortization and impairments $ 9,201 11,358 9,185
Equity in Earnings of Affiliates	Millions of Dollars 2016 2015 2014 Equity in Earnings of Affiliates Alaska $ 9 4 9 Lower 48 (6) (5) 1 Canada 89 78 1,385 Europe and North Africa 22 23 37 Asia Pacific and Middle East (51) 550 1,089 Other International - 8 9 Corporate and Other (11) (3) (1) Consolidated equity in earnings of affiliates $ 52 655 2,529
Income Taxes	Income Taxes Alaska $ (59) (71) 1,081 Lower 48 (1,328) (1,119) (92) Canada (383) (223) 236 Europe and North Africa (46) (854) 1,590 Asia Pacific and Middle East 306 467 1,194 Other International (40) (456) (102) Corporate and Other (421) (612) (324) Consolidated income taxes $ (1,971) (2,868) 3,583
Net Income Attributable to ConocoPhillips	Net Income (Loss) Attributable to ConocoPhillips Alaska $ 319 4 2,041 Lower 48 (2,257) (1,932) (22) Canada (935) (1,044) 940 Europe and North Africa 394 409 814 Asia Pacific and Middle East 209 (463) 2,939 Other International (16) (593) (100) Corporate and Other (1,329) (809) (874) Discontinued operations - - 1,131 Consolidated net income (loss) attributable to ConocoPhillips $ (3,615) (4,428) 6,869
Investments In and Advances To Affiliates	Investments In and Advances To Affiliates Alaska $ 58 61 53 Lower 48 426 455 471 Canada 8,784 8,165 9,484 Europe and North Africa 62 70 126 Asia Pacific and Middle East 11,611 11,780 14,022 Other International - - 59 Corporate and Other 4 15 15 Consolidated investments in and advances to affiliates $ 20,945 20,546 24,230
Total Assets	Millions of Dollars 2016 2015 2014 Total Assets Alaska $ 12,314 12,555 12,655 Lower 48 22,673 26,932 30,185 Canada 17,548 17,221 21,764 Europe and North Africa 11,727 13,703 16,970 Asia Pacific and Middle East 20,451 22,318 25,976 Other International 97 282 1,116 Corporate and Other 4,962 4,473 7,815 Discontinued operations - - 58 Consolidated total assets $ 89,772 97,484 116,539
Capital Expenditures and Investments	Capital Expenditures and Investments Alaska $ 883 1,352 1,564 Lower 48 1,262 3,765 6,054 Canada 698 1,255 2,340 Europe and North Africa 1,020 1,573 2,540 Asia Pacific and Middle East 838 1,812 3,877 Other International 104 173 520 Corporate and Other 64 120 190 Consolidated capital expenditures and investments $ 4,869 10,050 17,085
Interest Income and Expense	Interest Income and Expense Interest income Corporate $ 47 36 40 Lower 48 - - 35 Europe and North Africa 2 2 2 Asia Pacific and Middle East 8 6 6 Other International - 1 - Interest and debt expense Corporate $ 1,245 920 648
Geographic Information	Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2016 2015 2014 2016 2015 2014 United States $ 14,400 16,284 30,019 32,949 37,445 39,641 Australia (3) 1,353 2,127 3,258 12,259 12,788 14,969 Canada 1,974 2,136 4,409 16,846 16,766 20,874 China 551 782 1,701 1,372 1,647 1,913 Indonesia 938 1,165 1,963 856 1,191 1,526 Malaysia 735 598 403 3,323 3,599 3,811 Norway 1,645 2,107 3,794 6,228 6,933 8,142 United Kingdom 1,816 4,005 6,594 3,209 4,154 5,327 Other foreign countries 281 360 383 2,234 2,469 3,471 Worldwide consolidated $ 23,693 29,564 52,524 79,276 86,992 99,674 (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 $ 10,801 12,830 23,784 Natural gas 9,401 11,888 20,717 Natural gas liquids 837 952 2,245 Other* 2,654 3,894 5,778 Consolidated sales and other operating revenues by product $ 23,693 29,564 52,524 *Includes LNG and bitumen.

Supplementary Information - C55

Supplementary Information - Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2016
Supplementary Information - Condensed Consolidating Financial Information [Abstract]
Condensed Consolidated Income Statement	Millions of Dollars Year Ended December 31, 2016 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 $ - 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 (loss) 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 from continuing operations 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) 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) Income Statement Year Ended December 31, 2015 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) from continuing operations 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 Year Ended December 31, 2014 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 $ - 20,083 - 32,441 - 52,524 Equity in earnings of affiliates 6,108 8,090 - 2,932 (14,601) 2,529 Gain on dispositions - 9 - 89 - 98 Other income (loss) (6) 67 - 305 - 366 Intercompany revenues 79 465 283 5,883 (6,710) - Total Revenues and Other Income 6,181 28,714 283 41,650 (21,311) 55,517 Costs and Expenses Purchased commodities - 17,591 - 10,415 (5,907) 22,099 Production and operating expenses - 2,600 - 6,368 (59) 8,909 Selling, general and administrative expenses 9 575 1 166 (16) 735 Exploration expenses - 1,036 - 1,009 - 2,045 Depreciation, depletion and amortization - 1,059 - 7,270 - 8,329 Impairments - 127 - 729 - 856 Taxes other than income taxes - 285 - 1,803 - 2,088 Accretion on discounted liabilities - 58 - 426 - 484 Interest and debt expense 571 299 231 275 (728) 648 Foreign currency transaction (gains) losses 62 10 (372) 234 - (66) Total Costs and Expenses 642 23,640 (140) 28,695 (6,710) 46,127 Income from continuing operations before income taxes 5,539 5,074 423 12,955 (14,601) 9,390 Income tax provision (benefit) (199) (1,034) 19 4,797 - 3,583 Income From Continuing Operations 5,738 6,108 404 8,158 (14,601) 5,807 Income from discontinued operations 1,131 1,131 - 113 (1,244) 1,131 Net income 6,869 7,239 404 8,271 (15,845) 6,938 Less: net income attributable to noncontrolling interests - - - (69) - (69) Net Income Attributable to ConocoPhillips $ 6,869 7,239 404 8,202 (15,845) 6,869 Comprehensive Income Attributable to ConocoPhillips $ 2,965 3,335 58 4,589 (7,982) 2,965
Schedule of Condensed Balance Sheet	Millions of Dollars At December 31, 2016 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated 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 Balance Sheet At December 31, 2015 Assets Cash and cash equivalents $ - 4 15 2,349 - 2,368 Accounts and notes receivable 21 2,905 21 7,228 (5,661) 4,514 Inventories - 142 - 982 - 1,124 Prepaid expenses and other current assets 2 206 252 589 (266) 783 Total Current Assets 23 3,257 288 11,148 (5,927) 8,789 Investments, loans and long-term receivables* 43,532 64,015 3,264 27,839 (117,464) 21,186 Net properties, plants and equipment - 8,110 - 58,336 - 66,446 Other assets 7 950 233 1,158 (1,285) 1,063 Total Assets $ 43,562 76,332 3,785 98,481 (124,676) 97,484 Liabilities and Stockholders’ Equity Accounts payable $ - 5,684 13 4,897 (5,661) 4,933 Short-term debt (9) 1 1,255 180 - 1,427 Accrued income and other taxes - 62 - 437 - 499 Employee benefit obligations - 629 - 258 - 887 Other accruals 170 465 52 1,087 (264) 1,510 Total Current Liabilities 161 6,841 1,320 6,859 (5,925) 9,256 Long-term debt 7,518 10,660 1,716 3,559 - 23,453 Asset retirement obligations and accrued environmental costs - 1,107 - 8,473 - 9,580 Deferred income taxes - - - 11,814 (815) 10,999 Employee benefit obligations - 1,760 - 526 - 2,286 Other liabilities and deferred credits* 2,681 7,291 667 15,181 (23,992) 1,828 Total Liabilities 10,360 27,659 3,703 46,412 (30,732) 57,402 Retained earnings 29,892 17,366 (389) 15,177 (25,632) 36,414 Other common stockholders’ equity 3,310 31,307 471 36,572 (68,312) 3,348 Noncontrolling interests - - - 320 - 320 Total Liabilities and Stockholders’ Equity $ 43,562 76,332 3,785 98,481 (124,676) 97,484 *Includes intercompany loans.
Condensed Consolidated Statement of Cash Flows	Millions of Dollars Statement of Cash Flows Year Ended December 31, 2016 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 $ (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 sales 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 Statement of Cash Flows Year Ended December 31, 2015 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 Millions of Dollars Statement of Cash Flows Year Ended December 31, 2014 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) continuing operating activities $ 17,259 2,948 27 16,941 (20,763) 16,412 Net cash provided by discontinued operations - 202 - 408 (453) 157 Net Cash Provided by (Used in) Operating Activities 17,259 3,150 27 17,349 (21,216) 16,569 Cash Flows From Investing Activities Capital expenditures and investments - (6,507) - (14,840) 4,262 (17,085) Working capital changes associated with investing activities - 17 - 163 - 180 Proceeds from asset dispositions 16,912 1,588 - 253 (17,150) 1,603 Net purchases of short-term investments - - - 253 - 253 Long-term advances/loans—related parties - (736) (241) (7) 984 - Collection of advances/loans—related parties - 593 - 112 (102) 603 Intercompany cash management (29,113) 31,993 - (2,880) - - Other - (415) - (31) - (446) Net cash provided by (used in) continuing investing activities (12,201) 26,533 (241) (16,977) (12,006) (14,892) Net cash provided by (used in) discontinued operations - 133 - (73) (133) (73) Net Cash Provided by (Used in) Investing Activities (12,201) 26,666 (241) (17,050) (12,139) (14,965) Cash Flows From Financing Activities Issuance of debt - 2,994 - 984 (984) 2,994 Repayment of debt (1,909) (16) - (191) 102 (2,014) Issuance of company common stock 377 - - - (342) 35 Dividends paid (3,525) (17,588) - (3,768) 21,356 (3,525) Other (1) (16,870) - 3,919 12,888 (64) Net cash used in continuing financing activities (5,058) (31,480) - 944 33,020 (2,574) Net cash used in discontinued operations - - - (335) 335 - Net Cash Used in Financing Activities (5,058) (31,480) - 609 33,355 (2,574) Effect of Exchange Rate Changes on Cash and Cash Equivalents - - (8) (206) - (214) Net Change in Cash and Cash Equivalents - (1,664) (222) 702 - (1,184) Cash and cash equivalents at beginning of period - 2,434 229 3,583 - 6,246 Cash and Cash Equivalents at End of Period $ - 770 7 4,285 - 5,062

Schedule II (Tables)

Schedule II (Tables)	12 Months Ended
	Dec. 31, 2016
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 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) (c) 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) (c) 156 2014 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 8 - (2) (1) (b) 5 Deferred tax asset valuation allowance 969 127 (26) (100) 970 Included in other liabilities: Restructuring accruals 19 71 (6) (23) (c) 61 (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)Benefit payments.

Accounting Policies - Textuals

Accounting Policies - Textuals (Details Textual)	12 Months Ended
	Dec. 31, 2016
Accounting Policies Textual [Abstract]
Number of Operating Segments	6

Discontinued Operations (Detail

Discontinued Operations (Details) $ in Millions	12 Months Ended
	Dec. 31, 2014USD ($)
Sales and other operating revenues and income (loss) from discontinued operations
Income tax expense (benefit)	$ 16
Income from discontinued operations	1,131	[1]
Nigeria [Member]
Sales and other operating revenues and income (loss) from discontinued operations
Sales and other operating revenues from discontinued operations	480
Discontinued operation, income	1,147
Income tax expense (benefit)	16
Income from discontinued operations	$ 1,131
[1]	Net of provision for income taxes on discontinued operations of: $0, $0, $16

Discontinued Operations - Textu

Discontinued Operations - Textuals (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2016	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Other Discontinued Operations [Abstract]
Impairment of asset held for sale	$ 99
Deposit		$ 550
Nigeria Upstream Affiliates [Member]
Other Discontinued Operations [Abstract]
Deposit		100	$ 15	$ 435
Proceeds from asset dispositions		1,359
Gain on sale, before tax		$ 1,052

Variable Interest Entities (V60

Variable Interest Entities (VIEs) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Schedule of Equity Method Investments [Line Items]
Equity Method Investments	$ 20,364	$ 19,850
MWCC [Member]
Schedule of Equity Method Investments [Line Items]
Equity Method Investment, Ownership Percentage	10.00%
MWCC Additional Information	nine
MWCC Term Loan Financing	$ 154
Equity Method Investments	148
MWCC Letter of Credit	$ 22
MWCC Board Members [Member]
Schedule of Equity Method Investments [Line Items]
MWCC Additional Information	ten

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Inventories
Crude oil and natural gas	$ 418	$ 406
Materials, supplies and other	600	718
Total Inventories	1,018	1,124
Inventories (Textual) [Abstract]
Inventories valued on the LIFO basis	269	317
Excess of current replacement cost over LIFO cost of inventories	104	$ 6
Effect of LIFO Inventory Liquidation on Income	$ 9

Assets Held for Sale or Sold (D

Assets Held for Sale or Sold (Details)	3 Months Ended	12 Months Ended
	Sep. 30, 2016USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Assets Held for Sale or Sold (Textual) [Abstract]
Other Nonoperating Income		$ 255,000,000	$ 125,000,000	$ 366,000,000
Impairment of asset held for sale	$ 99,000,000
western Canadian Properties [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions			198,000,000
Gain (Loss) on Sale of Oil and Gas Property			66,000,000
Net carrying value			132,000,000
Amount of PP&E in carrying value of asset			379,000,000
Asset retirement obligation at disposal			248,000,000
western Canadian Properties Alberta [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions			130,000,000
Gain (Loss) on Sale of Oil and Gas Property			(235,000,000)
Net carrying value			365,000,000
Amount of PP&E in carrying value of asset			488,000,000
Asset retirement obligation at disposal			126,000,000
east Texas North Louisiana [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions			412,000,000
Gain (Loss) on Sale of Oil and Gas Property			189,000,000
Net carrying value			223,000,000
Amount of PP&E in carrying value of asset			351,000,000
Asset retirement obligation at disposal			128,000,000
South Texas Properties [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions			358,000,000
Gain (Loss) on Sale of Oil and Gas Property			201,000,000
Net carrying value			157,000,000
Amount of PP&E in carrying value of asset			369,000,000
Asset retirement obligation at disposal			212,000,000
Texas Pipeline Gathering Assets [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions			201,000,000
Gain (Loss) on Sale of Oil and Gas Property			193,000,000
Net carrying value			8,000,000
Amount of PP&E in carrying value of asset			24,000,000
Asset retirement obligation at disposal			$ 18,000,000
PolarLightsCompany [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Equity Method Investment, Ownership Percentage			50.00%
Equity Method Investment Sales Proceeds			$ 98,000,000
Carrying Value of Equity Investment Sold			40,000,000
Gain (Loss) on sale of equity investment			$ 58,000,000
Beluga River Unit [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions		134,000,000
Gain (Loss) on Sale of Oil and Gas Property		56,000,000
Net carrying value		78,000,000
Amount of PP&E in carrying value of asset		100,000,000
Asset retirement obligation at disposal		19,000,000
Canada Asset Exchange [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Gain (Loss) on Sale of Oil and Gas Property		$ (1,000,000)
Net Acres Given		141,000
Net Acres Received		40,000
Impairment of assets in exchange		$ 57,000,000
Fair value of assets exchanged		69,000,000
Senegal [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions		442,000,000
Gain (Loss) on Sale of Oil and Gas Property		146,000,000
Net carrying value		$ 286,000,000
Investment Owned Percent Of Net Assets		35.00%
Block B [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions		$ 225,000,000
Gain (Loss) on Sale of Oil and Gas Property		(26,000,000)
Net carrying value		251,000,000
Amount of PP&E in carrying value of asset		154,000,000
Amount of deferred taxes in carrying value of asset		54,000,000
Amount of Inventory in carrying value of asset		25,000,000
Amount of Accounts Receivable in carrying value		178,000,000
Total current liabilities of discontinued operations		130,000,000
Impairment of asset held for sale		$ 42,000,000
Investment Owned Percent Of Net Assets		40.00%
Amount of Employee Benefit Obligations in carrying value		$ 38,000,000
Greater Northern Iron Ore Properties Trust [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions		148,000,000
Gain (Loss) on Sale of Oil and Gas Property		4,000,000
Amount of PP&E in carrying value of asset		144,000,000
Other Nonoperating Income		$ 88,000,000

Investments, Loans and LT Recei

Investments, Loans and LT Receivables Components (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Components of investments, loans and long-term receivables
Equity investments	$ 20,364	$ 19,850
Loans and advances-related parties	581	696
Long-term receivables	631	519
Other investments	96	121
Total	$ 21,672	$ 21,186

Investments, Loans and LT Rec64

Investments, Loans and LT Receivables - Financial Info (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Summarized financial information for equity method investments in affiliated companies
Revenues	$ 10,149	$ 11,003	$ 19,243
Income before income taxes	660	1,866	6,746
Net income	799	1,801	$ 6,630
Current assets	3,578	2,504
Noncurrent assets	60,243	58,431
Current liabilities	2,352	1,863
Noncurrent liabilities	$ 23,764	$ 24,820

Investments, Loans and LT Rec65

Investments, Loans and LT Receivables Textuals (Details)	3 Months Ended		12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)ft3 / D	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)
Schedule of Equity Method Investments [Line Items]
Undistributed earnings of affiliates in retained earnings	$ 1,392,000,000		$ 1,392,000,000
Dividends received from affiliates			398,000,000	$ 876,000,000	$ 2,648,000,000
Book value of equity method investment	20,364,000,000	$ 19,850,000,000	20,364,000,000	19,850,000,000
Cumulative translation effect	(5,646,000,000)	(5,804,000,000)	(5,646,000,000)	(5,804,000,000)	(641,000,000)	$ 2,826,000,000
Equity Method Investment, Other than Temporary Impairment	$ 40,000,000	1,507,000,000
Income (Loss) from Equity Method Investments			$ 52,000,000	655,000,000	2,529,000,000
Australia Pacific APLNG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment	37.50%		37.50%
Project finance facility							$ 8,500,000,000
Book value of equity method investment	$ 10,089,000,000	10,185,000,000	$ 10,089,000,000	10,185,000,000
Cumulative translation effect	0		0
Historical cost basis	8,348,000,000		8,348,000,000
Difference between estimated value and book value of equity method investment	1,741,000,000		1,741,000,000
Annual amortization of basis difference			92,000,000	21,000,000	$ 24,000,000
Amount drawn from project finance facility	$ 8,500,000,000		8,500,000,000
Equity Method Investment, Other than Temporary Impairment			$ 1,502,000,000	1,502,000,000
Number of APLNG Long-term Sales and Purchase Agreements			2
Percent Decrease In Guarantee	60.00%		60.00%
Australia Pacific APLNG [Member] | Export-Import Bank of US [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility							2,900,000,000
Australia Pacific APLNG [Member] | Export-Import Bank of China [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility							2,700,000,000
Australia Pacific APLNG [Member] | Australian and International Commercial Bank Syndicate [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility							$ 2,900,000,000
Australia Pacific APLNG [Member] | Origin Energy [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	37.50%		37.50%
Australia Pacific APLNG [Member] | Sinopec [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	25.00%		25.00%		15.00%
Deferred Tax Effect [Member]
Schedule of Equity Method Investments [Line Items]
Income (Loss) from Equity Method Investments			$ 174,000,000
FCCL [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment	50.00%		50.00%
Dividends received from affiliates					$ 1,300,000,000
Book value of equity method investment	$ 8,784,000,000		$ 8,784,000,000
Cumulative translation effect	$ 1,706,000,000		$ 1,706,000,000
Initial acquisition obligation to joint venture						7,500,000,000
Payoff of remaining balance of obligation						$ 2,810,000,000
FCCL [Member] | Cenovus Energy Inc. [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	50.00%		50.00%
QG 3 [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment	30.00%		30.00%
Project finance facility	$ 4,000,000,000		$ 4,000,000,000
Book value of equity method investment	869,000,000		869,000,000
Loans to related parties - project financing	$ 696,000,000		$ 696,000,000
Percentage of interest in terminal and pipeline use agreements	12.40%		12.40%
QG 3 [Member] | Export credit agencies [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility	$ 1,300,000,000		$ 1,300,000,000
QG 3 [Member] | Commerical Banks [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility	1,500,000,000		1,500,000,000
QG 3 [Member] | Conoco Philips [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility	$ 1,200,000,000		$ 1,200,000,000
QG 3 [Member] | Qatar Petroleum [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	68.50%		68.50%
QG 3 [Member] | Mitsui & Co, Ltd. [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	1.50%		1.50%
Freeport LNG [Member]
Schedule of Equity Method Investments [Line Items]
Loans to related parties - project financing		454,000,000		$ 454,000,000
Previous long-term Agreement to Use Regasification Capacity Cubic Feet Per Day | ft3 / D				900,000,000
Termination Payment		522,000,000		$ 522,000,000
After Tax Charge					$ 540,000,000
Termination Cash Outflow		$ 63,000,000		$ 63,000,000
Long-term agreement to use regasification capacity cubic feet per day | ft3 / D				400,000,000
Freeport GP [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment		50.00%		50.00%

Suspended Wells Net Changes in

Suspended Wells Net Changes in Well Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net changes in suspended Exploratory well costs
Beginning balance	$ 1,260	$ 1,299	$ 994
Additions pending the determination of proved reserves	225	331	478
Reclassifications to proved properties	(27)	(28)	(9)
Sales of suspended well investment	(247)	0	(57)
Charged to dry hole expense	(148)	(342)	(107)
Ending balance	$ 1,063	$ 1,260	$ 1,299

Suspended Wells - Aging of susp

Suspended Wells - Aging of suspended well balances (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Aging of suspended well cost
Exploratory well costs capitalized for a period of one year or less	$ 132	$ 235	$ 466
Exploratory well costs capitalized for a period greater than one year	931	1,025	833
Ending balance	$ 1,063	$ 1,260	$ 1,299	$ 994
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year	26	28	30

Suspended Wells-Exploratory Cap

Suspended Wells-Exploratory Capitalized Well Costs (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
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		$ 931	$ 1,025	$ 833
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		648
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		58
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		225
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	[1]	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	[1]	157
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	[1]	15
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	[1]	5
Shenandoah-Lower 48 [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	[2]	161
Shenandoah-Lower 48 [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	[2]	118
Shenandoah-Lower 48 [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	[2]	0
Shenandoah-Lower 48 [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	[2]	43
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	[1]	131
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	[1]	120
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	[1]	11
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	[1]	0
Surmont 3 and beyond-Canada [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	[2]	107
Surmont 3 and beyond-Canada [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	[2]	55
Surmont 3 and beyond-Canada [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	[2]	29
Surmont 3 and beyond-Canada [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	[2]	23
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	[2]	93
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	[2]	70
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	[2]	0
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	[2]	23
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	[2]	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	[2]	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	[2]	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	[2]	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	[2]	31
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	[2]	31
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	[2]	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	[2]	0
Limbayong-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	[2]	23
Limbayong-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	[2]	23
Limbayong-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	[2]	0
Limbayong-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	[2]	0
Alpine Satellite-Alaska
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	[1]	22
Alpine Satellite-Alaska | 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	[1]	0
Alpine Satellite-Alaska | 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	[1]	0
Alpine Satellite-Alaska | 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	[1]	22
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	[1]	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	[1]	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	[1]	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	[1]	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	[1]	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	[1]	19
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	[1]	0
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	[1]	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	[1]	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	[1]	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	[1]	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	[1]	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	[1]	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	[1]	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	[1]	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	[1]	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	[1],[2]	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	[1],[2]	25
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	[1],[2]	3
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	[1],[2]	$ 15
[1]	Appraisal drilling complete; costs being incurred to assess development.
[2]	Additional appraisal wells planned.

Suspended Wells-Exploration Exp

Suspended Wells-Exploration Expense - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		$ 1,915	$ 4,192	$ 2,045
Gulf of Mexico Drillship cancellation fee [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			335
Gulf of Mexico Drillship cancellation fee Maersk [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		$ 146
Gulf of mexico drill ship capitalized rig costs [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			$ 48
Angola [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	$ 43

Impairments (Details)

Impairments (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Impairment charges by segment, before-tax
Asset Impairment Charges	$ 139,000,000	$ 2,245,000,000	$ 856,000,000
Exploration expenses	1,915,000,000	4,192,000,000	2,045,000,000
Alaska [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges	1,000,000	10,000,000	59,000,000
Chukchi [Member]
Impairment charges by segment, before-tax
Exploration expenses		575,000,000
Lower 48 [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges	149,000,000	(2,000,000)	208,000,000
Exploration expenses			239,000,000
Gulf of Mexico [Member]
Impairment charges by segment, before-tax
Exploration expenses	79,000,000	399,000,000
Gibson and Tiber [Member]
Impairment charges by segment, before-tax
Exploration expenses	203,000,000
Melmar [Member]
Impairment charges by segment, before-tax
Exploration expenses	95,000,000
Canada [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges	88,000,000	4,000,000	38,000,000
Exploration expenses	31,000,000		145,000,000
Duvernay Thornbury Saleski Crow Lake [Member]
Impairment charges by segment, before-tax
Exploration expenses		102,000,000
Europe and North Africa
Impairment charges by segment, before-tax
Asset Impairment Charges	(160,000,000)	724,000,000	541,000,000
Asia Pacific and Middle East [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges	44,000,000	1,508,000,000	7,000,000
Palangkaraya [Member]
Impairment charges by segment, before-tax
Exploration expenses		105,000,000
Block 36 [Member]
Impairment charges by segment, before-tax
Exploration expenses		377,000,000
Block 37 [Member]
Impairment charges by segment, before-tax
Exploration expenses		116,000,000
Corporate [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges	$ 17,000,000	$ 1,000,000	$ 3,000,000

Asset Retirement Obligations 71

Asset Retirement Obligations and Accrued Environmental Costs (Details) - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Asset retirement obligations and accrued environmental costs
Asset retirement obligations		$ 8,405	$ 9,911	$ 10,939
Accrued environmental costs		247	258
Total asset retirement obligations and accrued environmental costs		8,652	10,169
Asset retirement obligations and accrued environmental costs due within one year	[1]	(227)	(589)
Long-term asset retirement obligations and accrued environmental costs		$ 8,425	$ 9,580
[1]	*Classified as a current liability on the balance sheet under "Other accruals."

Asset Retirement Obligations 72

Asset Retirement Obligations and Accrued Environmental Costs - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Changes in overall asset retirement obligation changed
Balance at	$ 9,911	$ 10,939
Accretion of discount	420	480
New obligations	180	135
Changes in estimates of existing obligations	(1,197)	267
Spending on existing obligations	(314)	(437)
Property dispositions	(150)	(726)
Foreign currency translation	(464)	(747)
Other ARO Adjustments	19
Balance at	$ 8,405	$ 9,911

Asset Retirement Obligations 73

Asset Retirement Obligations and Accrued Environmental Costs - Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Environmental Liabilities [Line Items]
Accrued environmental costs	$ 247	$ 258
Additional Asset Retirement Obligations and Accrued Environmental Costs (Textual) [Abstract]
Maximum number of years accrued environmental liabilities will be paid over	30 years
Expected expenditures for acquired environmental obligations, weighted-average discount factor rate	5.00%
Accrued environmental costs, undiscounted due within one year	$ 9
Accrued environmental costs, undiscounted due within second year	12
Accrued environmental costs, undiscounted due within three year	8
Accrued environmental costs, undiscounted due within fourth year	5
Accrued environmental costs, undiscounted due within fifth year	4
Accrued environmental costs, undiscounted due after fifth year	110
Cleanup Remediation Activities [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	183	184
Corporate and Other Environmental Liabilities [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	51	57
Federal Comprehensive Environmental Response Compensation and Liability Act or Similar State Laws [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	13	$ 17
Acquired Environmental Obligations [Member]
Environmental Liabilities [Line Items]
Discounted accrued environmental costs	$ 92

Debt (Details)

Debt (Details) - USD ($) $ in Millions	Dec. 31, 2016	Sep. 30, 2016	Dec. 31, 2015
Long-term debt
Debt at face value	$ 26,175		$ 23,778
Capitalized leases	852		818
Net unamortized premiums and discounts	248		284
Total debt	27,275		24,880
Short-term debt	(1,089)		(1,427)
Long-term debt	26,186		23,453
9.125% Debentures due 2021 [Member]
Long-term debt
Debt at face value	$ 150		$ 150
Debt (Additional Textual) [Abstract]
Stated percentage of debt	9.125%		9.125%
8.20% Debentures due 2025 [Member]
Long-term debt
Debt at face value	$ 150		$ 150
Debt (Additional Textual) [Abstract]
Stated percentage of debt	8.20%		8.20%
8.125% Notes due 2030 [Member]
Long-term debt
Debt at face value	$ 600		$ 600
Debt (Additional Textual) [Abstract]
Stated percentage of debt	8.125%		8.125%
7.9% Debentures due 2047 [Member]
Long-term debt
Debt at face value	$ 100		$ 100
Debt (Additional Textual) [Abstract]
Stated percentage of debt	7.90%		7.90%
7.8% Debentures due 2027 [Member]
Long-term debt
Debt at face value	$ 300		$ 300
Debt (Additional Textual) [Abstract]
Stated percentage of debt	7.80%		7.80%
7.65% Debentures due 2023 [Member]
Long-term debt
Debt at face value	$ 88		$ 88
Debt (Additional Textual) [Abstract]
Stated percentage of debt	7.65%		7.65%
7.40% Notes due 2031 [Member]
Long-term debt
Debt at face value	$ 500		$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt	7.40%		7.40%
7.375% Debentures due 2029 [Member]
Long-term debt
Debt at face value	$ 92		$ 92
Debt (Additional Textual) [Abstract]
Stated percentage of debt	7.375%		7.375%
7.25% Notes due 2031 [Member]
Long-term debt
Debt at face value	$ 500		$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt	7.25%		7.25%
7.20% Notes due 2031 [Member]
Long-term debt
Debt at face value	$ 575		$ 575
Debt (Additional Textual) [Abstract]
Stated percentage of debt	7.20%		7.20%
7% Debentures due 2029 [Member]
Long-term debt
Debt at face value	$ 200		$ 200
Debt (Additional Textual) [Abstract]
Stated percentage of debt	7.00%		7.00%
6.95% Notes due 2029 [Member]
Long-term debt
Debt at face value	$ 1,549		$ 1,549
Debt (Additional Textual) [Abstract]
Stated percentage of debt	6.95%		6.95%
6.875% Debentures due 2026 [Member]
Long-term debt
Debt at face value	$ 67		$ 67
Debt (Additional Textual) [Abstract]
Stated percentage of debt	6.875%		6.875%
6.65% Debentures due 2018 [Member]
Long-term debt
Debt at face value	$ 297		$ 297
Debt (Additional Textual) [Abstract]
Stated percentage of debt	6.65%		6.65%
6.50% Notes due 2039 [Member]
Long-term debt
Debt at face value	$ 2,750		$ 2,750
Debt (Additional Textual) [Abstract]
Stated percentage of debt	6.50%		6.50%
6.00% Notes due 2020 [Member]
Long-term debt
Debt at face value	$ 1,000		$ 1,000
Debt (Additional Textual) [Abstract]
Stated percentage of debt	6.00%		6.00%
5.951% Notes due 2037 [Member]
Long-term debt
Debt at face value	$ 645		$ 645
Debt (Additional Textual) [Abstract]
Stated percentage of debt	5.951%		5.951%
5.95% Notes due 2036 [Member]
Long-term debt
Debt at face value	$ 500		$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt	5.95%		5.95%
5.95% Notes due 2046 [Member]
Long-term debt
Debt at face value	$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt	5.95%		5.95%
5.90% Notes due 2032 [Member]
Long-term debt
Debt at face value	$ 505		$ 505
Debt (Additional Textual) [Abstract]
Stated percentage of debt	5.90%		5.90%
5.90% Notes due 2038 [Member]
Long-term debt
Debt at face value	$ 600		$ 600
Debt (Additional Textual) [Abstract]
Stated percentage of debt	5.90%		5.90%
5.75% Notes due 2019 [Member]
Long-term debt
Debt at face value	$ 2,250		$ 2,250
Debt (Additional Textual) [Abstract]
Stated percentage of debt	5.75%		5.75%
5.625% Notes due 2016 [Member]
Long-term debt
Debt at face value	$ 0		$ 1,250
Debt (Additional Textual) [Abstract]
Stated percentage of debt	5.625%		5.625%
5.20% Notes due 2018 [Member]
Long-term debt
Debt at face value	$ 500		$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt	5.20%		5.20%
4.95% Notes due 2026 [Member]
Long-term debt
Debt at face value	$ 1,250		$ 0
Debt (Additional Textual) [Abstract]
Stated percentage of debt	4.95%		4.95%
4.3% Notes due 2044 [Member]
Long-term debt
Debt at face value	$ 750		$ 750
Debt (Additional Textual) [Abstract]
Stated percentage of debt	4.30%		4.30%
Other Debt [Member]
Long-term debt
Debt at face value	$ 24		$ 24
4.2% Notes due 2021 [Member]
Long-term debt
Debt at face value	$ 1,250		$ 0
Debt (Additional Textual) [Abstract]
Stated percentage of debt	4.20%		4.20%
4.15% Notes due 2034 [Member]
Long-term debt
Debt at face value	$ 500		$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt	4.15%		4.15%
3.35% Notes due 2024 [Member]
Long-term debt
Debt at face value	$ 1,000		$ 1,000
Debt (Additional Textual) [Abstract]
Stated percentage of debt	3.35%		3.35%
3.35% Notes due 2025 [Member]
Long-term debt
Debt at face value	$ 500		$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt	3.35%		3.35%
2.875% Notes due 2021 [Member]
Long-term debt
Debt at face value	$ 750		$ 750
Debt (Additional Textual) [Abstract]
Stated percentage of debt	2.875%		2.875%
2.4% Notes due 2022 [Member]
Long-term debt
Debt at face value	$ 1,000		$ 1,000
Debt (Additional Textual) [Abstract]
Stated percentage of debt	2.40%		2.40%
2.2% Notes due 2020 [Member]
Long-term debt
Debt at face value	$ 500		$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt	2.20%		2.20%
1.5% Notes due 2018 [Member]
Long-term debt
Debt at face value	$ 750		$ 750
Debt (Additional Textual) [Abstract]
Stated percentage of debt	1.50%		1.50%
1.05% Notes due 2017 [Member]
Long-term debt
Debt at face value	$ 1,000		$ 1,000
Debt (Additional Textual) [Abstract]
Stated percentage of debt	1.05%		1.05%
Floating rate term loan due 2019 at 1.94% - 2.31% during 2016 [Member]
Long-term debt
Debt at face value	$ 1,450	$ 1,600
Floating term loan due 2018 at .69% - 1.24% during 2016 [Member]
Long-term debt
Debt at face value	250		$ 250
Floating Rate Notes Due 2022 at 1.26% - 1.81% during 2016[Member]
Long-term debt
Debt at face value	500		500
Variable rate debt bonds [Member]
Long-term debt
Debt at face value	283
Commercial paper at 0.16% - 0.80% at year-end 2015 [Member]
Long-term debt
Debt at face value	0		803
Marine Terminal Revenue Refunding Bonds due 2031 at 0.01% - 0.95% at year-end 2016 and 0.01% - 0.14% at year-end 2015
Long-term debt
Debt at face value	265		265
Industrial Development Bonds due 2015 through 2038 at 0.01% - 0.91% at year-end 2016 and 0.01% - 0.13% at year-end 2015
Long-term debt
Debt at face value	$ 18		$ 18

Debt Capital Lease (Details 2)

Debt Capital Lease (Details 2) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Capital lease obligations
2,017	$ 121
2,018	102
2,019	102
2,020	103
2,021	88
Remaining years	590
Capital lease payments	1,106
Less portion representing imputed interest	(254)
Capital Lease Obligations, Total	$ 852	$ 818

Debt (Details Textual)

Debt (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Sep. 30, 2016
Debt (Textual) [Abstract]
Maturities of long-term borrowings in 2016	$ 1,089
Maturities of long-term borrowings in 2017	1,894
Maturities of long-term borrowings in 2018	3,784
Maturities of long-term borrowings in 2019	1,593
Maturities of long-term borrowings in 2020	2,235
Classification of short-term debt as long-term debt	$ 0
Debt to capital ratio	0.65
Capital Leased Assets [Line Items]
Capital lease obligations	$ 852	$ 818
Ownership Pre Unitization		33.00%
Ownership Post Unitization		29.00%
Short-term Debt [Line Items]
Maturity period of commercial paper (in days)	P90D
Letters of credit issued	$ 304
Credit facilities remaining after commercial paper outstanding and issuance of letters of credit	6,750
Debt Instrument [Line Items]
Debt Instrument, Face Amount	26,175	$ 23,778
Repayment of Debt	2,251	103	$ 2,014
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	540	707	$ 906
Capital Leases Other Accumulated Depreciation	268	122
Floating rate notes due 2019
Debt Instrument [Line Items]
Debt Instrument, Face Amount	1,450			$ 1,600
Repayment of Debt	$ 150
Minimum interest [Member]
Debt Instrument [Line Items]
Stated percentage of debt	1.50%
Maximum interest [Member]
Debt Instrument [Line Items]
Stated percentage of debt	2.00%
Base Rate Interest [Member]
Debt Instrument [Line Items]
Stated percentage of debt	0.50%
Libor Rate Interest [Member]
Debt Instrument [Line Items]
Stated percentage of debt	1.50%
Base minimum interest [Member]
Debt Instrument [Line Items]
Stated percentage of debt	0.50%
Base maximum interest [Member]
Debt Instrument [Line Items]
Stated percentage of debt	1.00%
5.625% Notes due 2016 [Member]
Debt Instrument [Line Items]
Stated percentage of debt	5.625%
Repayment of Debt	$ 1,250
Marine Terminal Revenue Refunding Bonds due 2035 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	283
4.2% Notes due 2021 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,250	$ 0
Stated percentage of debt	4.20%	4.20%
4.95% Notes due 2026 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 1,250	$ 0
Stated percentage of debt	4.95%	4.95%
5.95% Notes due 2046 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 500
Stated percentage of debt	5.95%	5.95%
ConocoPhillips [Member]
Short-term Debt [Line Items]
Commercial paper program	$ 6,250
Debt Instrument [Line Items]
Repayment of Debt	150	$ 0	$ 1,909
ConocoPhillips Qatar Funding Ltd. [Member]
Short-term Debt [Line Items]
Commercial paper program	500
Commercial paper outstanding	0	803
Under Revolving Credit Facilities [Member]
Short-term Debt [Line Items]
Total amount under revolving credit facilities	6,750	$ 7,000
Letters of credit capacity	500
Minimum limit of debt for cross default provision	200
Letters of credit issued	$ 0

Guarantees (Details)

Guarantees (Details) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)
Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Ownership percentage in equity investment	37.50%
Train 1 and Train 2 [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 10
Terms of Guarantees Outstanding	1 year
Construction completion guarantee [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 1,300
Maximum potential amount of future payments - based on pro-rata share	1,300
Carrying value of the guarantee to third-party lenders	46
Continued development [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 160
Terms of Guarantees Outstanding	up to 29 years or the life of the venture
Other Guarantees [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 540
Terms of Guarantees Outstanding	up to six years
Indemnification [Member]
Guarantees (Textual) [Abstract]
Environmental accruals for known contamination in carrying amount recorded for indemnifications	$ 40
Carrying value of the guarantee to third-party lenders	100
Indemnification [Member] | Refinery Supplier [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 1,400
Terms of Guarantees Outstanding	eight years
Carrying value of the guarantee to third-party lenders	$ 98
Carrying value of indemnification asset	98
Guarantee existing sales agreement of natural gas delivery | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	1,000
Maximum potential amount of future payments - reckless breach	$ 1,700
Terms of Guarantees Outstanding	1 to 25 years
Finance Reserve Guarantee [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 60
Terms of Guarantees Outstanding	13 years
Carrying value of the guarantee to third-party lenders	$ 9

Contingencies and Commitments (

Contingencies and Commitments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Contingencies and Commitments (Textual) [Abstract]
Letters of Credit Outstanding, Amount	$ 304
Arbitration settlement amount	380
Counterclaim settlement amount	(42)
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	24
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Second Year	20
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Third Year	7
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Fourth Year	7
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Fifth Year	7
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due after Fifth Year	75
Total payments under Long-Term Throughput Agreements and Take-or-Pay Agreements	$ 42	$ 27	$ 127

Derivative and Financial Inst79

Derivative and Financial Instruments - Commodity Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	$ 268	$ 768
Other assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	44	60
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	300	754
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	$ 34	$ 46

Derivative and Financial Inst80

Derivative and Financial Instruments - Commodity GainLoss (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Sales and other operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (198)	$ 231	$ 523
Other Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	(1)	2	1
Purchased commodities [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ 161	$ (201)	$ (458)

Derivative and Financial Inst81

Derivative and Financial Instruments - Commodity Notional (Details 2) pure in Billions	Dec. 31, 2016	Dec. 31, 2015
Natural gas and power, Fixed price [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	(31)	(14)
Natural gas and power, Basis [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	2	(17)

Derivative and Financial Inst82

Derivative and Financial Instruments - FX Balance Sheet (Details 3) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	$ 1	$ 47
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative liabilities	$ 168	$ 8

Derivative and Financial Inst83

Derivative and Financial Instruments - FX GainLoss (Details 4) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Foreign currency transaction (gains) losses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Foreign currency transaction (gains) losses	$ 247	$ (33)	$ 3

Derivative and Financial Inst84

Derivative and Financial Instruments - FX Notional (Details 5) - Not Designated as Hedging Instrument [Member] - USD ($) $ in Millions		Dec. 31, 2016	Dec. 31, 2015
Sell U.S. dollar, buy other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	[1]	$ 13	$ 347
Buy U.S. dollar, sell other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	[2]	25	20
Buy British pound, sell other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	[3]	1,069	567
Sell British pound, buy Norwegian krone [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives		$ 51	$ 0
[1]	*Primarily Canadian dollar, Norwegian krone and British pound.
[2]	**Primarily Canadian dollar and British pound.
[3]	***Primarily Canadian dollar and Euro.

Derivative and Financial Inst85

Derivative and Financial Instruments - Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents, at Carrying Value, Total	$ 3,610	$ 2,368	$ 5,062	$ 6,246
Short-term Investments	50
Cash and Cash Equivalents [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash	623	528
Money Market Funds At Carrying Value		0
Time Deposits	2,987	1,840
Commercial Paper		$ 0
Cash and Cash Equivalents [Member] | Remaining maturities from 1 to 90 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Time Deposits	39
Cash and Cash Equivalents [Member] | Remaining maturities from 91 to 180 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Time Deposits	$ 11

Derivative and Financial Inst86

Derivative and Financial Instruments - Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Schedule of Credit Risk [Line items]
Collateral was posted for derivative instruments in a liability position	$ 0	$ 2
Aggregate fair value of all derivative instruments in a liability position	$ 42	$ 158
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Terms of financial instruments and trade receivables	30 days	30 days
In event of lowered credit rating [Member]
Schedule of Credit Risk [Line items]
Additional collateral, either in the form of cash or letters of credit	$ 0
In event of downgrade below investment grade [Member]
Schedule of Credit Risk [Line items]
Additional collateral, either in the form of cash or letters of credit	$ 42

Fair Value Measurement - FV Hie

Fair Value Measurement - FV Hierarchy (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative asset, gross	$ 312	$ 828
Commodity derivative liability, gross	334	800
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Deferred compensation investments	0	0
Commodity derivative asset, gross	312	828
Total assets	312	828
Commodity derivative liability, gross	334	800
Total liabilities	334	800
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Deferred compensation investments	0	0
Commodity derivative asset, gross	194	516
Total assets	194	516
Commodity derivative liability, gross	207	515
Total liabilities	207	515
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	96	242
Total assets	96	242
Commodity derivative liability, gross	105	273
Total liabilities	105	273
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	22	70
Total assets	22	70
Commodity derivative liability, gross	22	12
Total liabilities	$ 22	$ 12

Fair Value Measurement - FV of

Fair Value Measurement - FV of Commodity Derivatives (Details 1) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Offsetting Derivative Assets [Abstract]
Assets - gross amounts recognized	$ 312	$ 828
Assets - gross amounts offset	221	600
Assets - net amounts presented	91	228
Assets - cash collateral	0	0
Assets - amounts without right of setoff	5	8
Assets - net amounts	86	220
Offsetting Derivative Liabilities [Abstract]
Liabilities - gross amounts recognized	334	800
Liabilities - gross amounts offset	221	600
Liabilities - net amounts presented	113	200
Liabilities - cash collateral	12	1
Liabilities - amounts without right of setoff	12	11
Liabilities - net amounts	$ 89	$ 188

Fair Value Measurement - Nonrec

Fair Value Measurement - Nonrecurring (Details) - USD ($) $ in Millions	3 Months Ended
	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for sale)		$ 217
Fair Value - Net PP&E (held for use)	$ 13		$ 23	$ 217	$ 440		$ 42
Fair Value - Net PP&E (unproved property)						$ 104
Fair Value - Equity Method Investments	90				10,210
Before-Tax Loss - Equity method investments	40				1,507
Before-Tax Loss - Net PP&E (held for sale)		99
Before-Tax Loss - Net PP&E (unproved propery)						240
Before-Tax Loss - Net PP&E (held for use)	29		53	129	595	7	70	$ 9
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 sale)		$ 217
Fair Value - 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)	13		$ 23	$ 217	440		$ 42
Fair Value - Net PP&E (unproved property)						$ 104
Fair Value - Equity Method Investments	$ 86				$ 10,210

Fair Value Measurement - Fair V

Fair Value Measurement - Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Financial Assets
Commodity derivatives, assets	$ 86	$ 220
Financial Liabilities
Commodity derivatives, liability	89	188
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Financial Assets
Deferred compensation investments	0	0
Commodity derivatives, assets	91	228
Loans to related parties - project financing	701	808
Financial Liabilities
Total debt, excluding capital leases, carrying amount	26,423	24,062
Commodity derivatives, liability	101	199
Deferred Compensation Liquidation [Member]
Financial Assets
Deferred compensation investments	267
Portion at Fair Value, Fair Value Disclosure [Member]
Financial Assets
Deferred compensation investments	0	0
Commodity derivatives, assets	91	228
Loans to related parties - project financing	701	808
Financial Liabilities
Total debt, excluding capital leases, fair value	29,307	24,785
Commodity derivatives, liability	$ 101	$ 199

Fair Value Measurement - Textua

Fair Value Measurement - Textuals (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2016
Financial Instruments and Derivative Contracts (Textual) [Abstract]
Obligations to return cash collateral	$ 0	$ 0
Rights to reclaim cash collateral	1,000,000	$ 12,000,000
APLNG equity method investment	10,185,000,000
APLNG Before-Tax Loss	$ 1,502,000,000

Equity - changes in shares of c

Equity - changes in shares of common stock (Details) - shares	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Changes in shares of common stock
Repurchase of common stock	2,579,098
Common Stock [Member]
Changes in shares of common stock
Beginning Balance, Common Stock	1,778,226,388	1,773,583,368	1,768,169,906
Distributed under benefit plans	3,852,719	4,643,020	5,413,462
Ending Balance, Common Stock	1,782,079,107	1,778,226,388	1,773,583,368
Treasury Stock [Member]
Changes in shares of common stock
Beginning Balance, Common Stock	542,230,673	542,230,673	542,230,673
Repurchase of common stock	2,579,098		0
Distributed under benefit plans			0
Ending Balance, Common Stock	544,809,771	542,230,673	542,230,673

Equity - Textuals (Details)

Equity - Textuals (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Equity (Textual) [Abstract]
Preferred Stock, Authorized	500,000,000	500,000,000
Preferred Stock, Par value	$ 0.01	$ 0.01
Preferred Stock, Issued	0	0
Preferred Stock, Outstanding	0	0
Noncontrolling interests	$ 252	$ 320
Repurchase of common stock	2,579,098
Repurchase of company common stock	$ 126
Stock repurchase program authorized amount	$ 3,000

Non Mineral Leases (Details)

Non Mineral Leases (Details) $ in Millions	Dec. 31, 2016USD ($)
Future minimum rental payments due under noncancelable leases
2,017	$ 277
2,018	238
2,019	172
2,020	390
2,021	114
Remaining Years	435
Total	1,626
Less income from subleases	(15)
Net Minimum Operating Lease Payments	$ 1,611

Non-Mineral Leases - Operating

Non-Mineral Leases - Operating lease rental (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Operating lease rental expense
Total rentals	$ 537,000,000	$ 432,000,000	$ 474,000,000
Less sublease rentals	(8,000,000)	(9,000,000)	(10,000,000)
Operating Leases, Rent Expense, Total	$ 529,000,000	$ 423,000,000	$ 464,000,000

Employee Benefit Plans - Change

Employee Benefit Plans - Change in Benefit Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
United States Pension Plans of US Entity, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	$ 3,772	[1],[2]	$ 4,387
Service cost	108		138		$ 124
Interest cost	133		161		165
Actuarial (gain) loss	247		(212)
Benefits paid	(872)		(729)
Defined Benefit Plan, Curtailments	14		27
Settlements					0
Recognition of termination benefits	14
Benefit obligation at December 31	3,416	[1]	3,772	[1],[2]	4,387
Accumulated benefit at year end	3,246		3,573
Foreign Pension Plans, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	3,321	[1],[2]	3,984
Service cost	76		124		109
Interest cost	120		135		166
Plan participant contributions	3		5
Actuarial (gain) loss	466		(442)
Benefits paid	(148)		(162)
Defined Benefit Plan, Curtailments	10		(43)
Settlements	(46)
Recognition of termination benefits	1		68
Foreign currency exchange rate change	(358)		(348)
Benefit obligation at December 31	3,445	[1]	3,321	[1],[2]	3,984
Accumulated benefit at year end	3,067		2,953
Other Postretirement Benefit Plans, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	352		716
Service cost	2		4		3
Interest cost	13		22		29
Plan participant contributions	24		21
Plan amendments	(27)		(303)
Actuarial (gain) loss	(14)		(49)
Benefits paid	(68)		(63)
Defined Benefit Plan, Curtailments	3		8
Foreign currency exchange rate change	1		(4)
Benefit obligation at December 31	$ 286		$ 352		$ 716
[1]	*Accumulated benefit obligation portion of above at December 31: $3,246, $3,067, $3,573, $2,953
[2]	*Accumulated benefit obligation portion of above at December 31: $3,246, $3,067, $3,573, $2,953

Employee Benefit Plans - Chan97

Employee Benefit Plans - Change in Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
United States Pension Plans of US Entity, Defined Benefit [Member]
Change in Fair Value of Plan Assets
Fair value of plan assets at January 1	$ 2,606	$ 3,266
Actual return on plan assets	133	(4)
Company contributions	214	73
Benefits paid	(872)	(729)
Fair value of plan assets at December 31	2,081	2,606
Funded Status	(1,335)	(1,166)
Foreign Pension Plans, Defined Benefit [Member]
Change in Fair Value of Plan Assets
Fair value of plan assets at January 1	3,063	3,278
Actual return on plan assets	397	96
Company contributions	125	120
Plan participant contributions	3	5
Benefits paid	(148)	(162)
Foreign currency exchange rate change	(372)	(274)
Fair value of plan assets at December 31	3,068	3,063
Funded Status	(377)	(258)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Change in Fair Value of Plan Assets
Company contributions	44	42
Plan participant contributions	24	21
Benefits paid	(68)	(63)
Funded Status	$ (286)	$ (352)

Employee Benefit Plans - Amount

Employee Benefit Plans - Amounts recognized in Balance Sheet And Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent liabilities	$ (2,552)	$ (2,286)
United States Pension Plans of US Entity, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Current liabilities	(101)	(99)
Noncurrent liabilities	(1,234)	(1,067)
Total recognized	$ (1,335)	$ (1,166)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.95%	4.50%
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	3.90%	4.00%
Expected return on plan assets	7.00%	7.00%
Rate of compensation increase	4.00%	4.75%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 748	$ 773
Unrecognized prior service cost (credit)	4	9
Foreign Pension Plans, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent assets	164	175
Current liabilities	(7)	(34)
Noncurrent liabilities	(534)	(399)
Total recognized	$ (377)	$ (258)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.00%	3.95%
Rate of compensation increase	3.85%	4.05%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	3.95%	3.55%
Expected return on plan assets	5.45%	5.40%
Rate of compensation increase	4.05%	4.35%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 479	$ 273
Unrecognized prior service cost (credit)	(20)	(30)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Current liabilities	(44)	(45)
Noncurrent liabilities	(242)	(307)
Total recognized	$ (286)	$ (352)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.60%	3.90%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	3.75%	4.05%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ (27)	$ (18)
Unrecognized prior service cost (credit)	$ (285)	$ (292)

Employee Benefit Plans - Source

Employee Benefit Plans - Sources of Change in Other Comprehensive Income (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Sources of change in other comprehensive income
Net actuarial gain (loss) arising during the period		$ (481)		$ 592		$ (840)
Amortization of (gain) loss included in income		309		403		131
Prior service (cost) credit arising during the period		23		301		(3)
Reclassification adjustment for amortization of prior service cost included in net income (loss)		(35)		(19)		$ (6)
United States Pension Plans of US Entity, Defined Benefit [Member]
Sources of change in other comprehensive income
Net actuarial gain (loss) arising during the period		(263)		61
Amortization of (gain) loss included in income		288	[1]	312	[2]
Net change during the period		25		373
Reclassification adjustment for amortization of prior service cost included in net income (loss)		5		7
Net change during the period		5		7
Amounts included in accumulated other comprehensive income that are expected to be amortized into net periodic postretirement cost
Unrecognized net actuarial loss (gain)		75
Unrecognized prior service cost (credit)		4
Foreign Pension Plans, Defined Benefit [Member]
Sources of change in other comprehensive income
Net actuarial gain (loss) arising during the period		(232)		490
Amortization of (gain) loss included in income	[1]	26		89
Net change during the period		(206)		579
Prior service (cost) credit arising during the period		(4)		(2)
Reclassification adjustment for amortization of prior service cost included in net income (loss)		(6)		(11)
Net change during the period		(10)		(13)
Amounts included in accumulated other comprehensive income that are expected to be amortized into net periodic postretirement cost
Unrecognized net actuarial loss (gain)		48
Unrecognized prior service cost (credit)		(5)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Sources of change in other comprehensive income
Net actuarial gain (loss) arising during the period		14		41
Amortization of (gain) loss included in income		(5)	[1]	2	[2]
Net change during the period		9		43
Prior service (cost) credit arising during the period		27		303
Reclassification adjustment for amortization of prior service cost included in net income (loss)		(34)		(15)
Net change during the period		(7)		288
Amounts included in accumulated other comprehensive income that are expected to be amortized into net periodic postretirement cost
Unrecognized net actuarial loss (gain)		(3)
Unrecognized prior service cost (credit)		$ (36)
Discontinued Contribution Post 65 [Member]
Sources of change in other comprehensive income
Prior service (cost) credit arising during the period				149
Cost Sharing Assumptions [Member]
Sources of change in other comprehensive income
Prior service (cost) credit arising during the period				91
Phillips 66 Exclusion [Member]
Sources of change in other comprehensive income
Prior service (cost) credit arising during the period				49
Post 65 not eligible [Member]
Sources of change in other comprehensive income
Prior service (cost) credit arising during the period				$ 14
[1]	*Includes settlement losses recognized in 2016 and 2015.
[2]	*Includes settlement losses recognized in 2016 and 2015.

Employee Benefit Plans - Compon

Employee Benefit Plans - Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net periodic benefit cost of all defined benefit plans
Settlements	$ 202	$ 204
Curtailments (gain) loss	15	33
Special pension termination benefits	$ 15	124
Percent Amortized of Unamortized Balance for Net Actuarial Gain and Losses	10.00%
United States Pension Plans of US Entity, Defined Benefit [Member]
Net periodic benefit cost of all defined benefit plans
Service cost	$ 108	138	$ 124
Interest cost	133	161	165
Expected return on plan assets	(149)	(201)	(213)
Amortization of prior service cost (credit)	5	6	6
Recognized net actuarial loss (gain)	86	115	77
Settlements	202	197
Curtailments (gain) loss	14	35
Net periodic benefit cost	399	451	159
Special pension termination benefits	$ 14	46
Pre 65 Retiree [Member]
Net periodic benefit cost of all defined benefit plans
Measurement of the accumulated postretirement benefit obligation assumes a health care cost trend rate	6.50%
Measurement of the accumulated postretirement benefit obligation assumes a health care cost trend rate, after increase or decline	5.00%
Year of measurement of the accumulated postretirement benefit obligation assumes a health care cost trend rate, after decline	2,023
Post 65 Retiree [Member]
Net periodic benefit cost of all defined benefit plans
Measurement of the accumulated postretirement benefit obligation assumes a health care cost trend rate	4.00%
Measurement of the accumulated postretirement benefit obligation assumes a health care cost trend rate, after increase or decline	5.00%
Year of measurement of the accumulated postretirement benefit obligation assumes a health care cost trend rate, after decline	2,018
Foreign Pension Plans, Defined Benefit [Member]
Net periodic benefit cost of all defined benefit plans
Service cost	$ 76	124	109
Interest cost	120	135	166
Expected return on plan assets	(147)	(164)	(181)
Amortization of prior service cost (credit)	(6)	(7)	(8)
Recognized net actuarial loss (gain)	26	82	57
Settlements		7
Curtailments (gain) loss	0	(4)
Net periodic benefit cost	69	173	143
Europe [Member]
Net periodic benefit cost of all defined benefit plans
Special pension termination benefits	1	$ 78
Special pension termination benefits recoverable from partner		62.00%
Other Postretirement Benefit Plans, Defined Benefit [Member]
Net periodic benefit cost of all defined benefit plans
Service cost	2	$ 4	3
Interest cost	13	22	29
Amortization of prior service cost (credit)	(34)	(17)	(4)
Recognized net actuarial loss (gain)	(2)	2	(3)
Curtailments (gain) loss	1	2
Net periodic benefit cost	$ (20)	$ 13	$ 25

Employee Benefit Plans - Fair v

Employee Benefit Plans - Fair values of pension plan assets (Details) - USD ($) $ in Millions		Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Fair values of our pension plan assets
Fair value of participating interest in annuity contract		$ 121		$ 125
Net payables receivables related to security transactions		1		32
United States Pension Plans of US Entity, Defined Benefit [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		2,081		2,606		$ 3,266
United States Pension Plans of US Entity, Defined Benefit [Member] | U.S. (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		646		782
United States Pension Plans of US Entity, Defined Benefit [Member] | International (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		342		485
United States Pension Plans of US Entity, Defined Benefit [Member] | Common/Collective Trusts(Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		62
United States Pension Plans of US Entity, Defined Benefit [Member] | Common/Collective Trusts Measured at NAV (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	[1]	410		569
United States Pension Plans of US Entity, Defined Benefit [Member] | Government (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		38		141
United States Pension Plans of US Entity, Defined Benefit [Member] | Corporate (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		57		348
United States Pension Plans of US Entity, Defined Benefit [Member] | Agency and Mortgage Backed Securities(Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets				80
United States Pension Plans of US Entity, Defined Benefit [Member] | Common/Collective Trusts Measured at Net Asset Value (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	[1]	312
United States Pension Plans of US Entity, Defined Benefit [Member] | Cash and Cash Equivalents [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
United States Pension Plans of US Entity, Defined Benefit [Member] | Cash and Cash Equivalents Measured at Net Asset Value [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	[1]	36		60
United States Pension Plans of US Entity, Defined Benefit [Member] | Private Equity Funds [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
United States Pension Plans of US Entity, Defined Benefit [Member] | Derivatives [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0		(7)
United States Pension Plans of US Entity, Defined Benefit [Member] | Real Estate [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
United States Pension Plans of US Entity, Defined Benefit [Member] | Real Estate Measured at Net Asset Value [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	[1]	69		63
United States Pension Plans of US Entity, Defined Benefit [Member] | Subtotal in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		1,145		1,829
United States Pension Plans of US Entity, Defined Benefit [Member] | Grand Total in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		1,972	[2]	2,521	[3]
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | U.S. (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		632		777
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | International (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		342		485
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Common/Collective Trusts(Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		62
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Government (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0		85
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Derivatives [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Subtotal in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		1,036		1,347
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Grand Total in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		1,036	[2]	1,347	[3]
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | U.S. (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0		3
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Common/Collective Trusts(Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Government (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		38		56
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Corporate (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		54		331
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Agency and Mortgage Backed Securities(Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets				80
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Derivatives [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0		(7)
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Subtotal in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		92		463
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Grand Total in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		92	[2]	463	[3]
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | U.S. (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		14		2
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Corporate (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		3		17
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Real Estate [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Subtotal in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		17		19
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Grand Total in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		17	[2]	19	[3]
Foreign Pension Plans, Defined Benefit [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		3,068		3,063		$ 3,278
Foreign Pension Plans, Defined Benefit [Member] | U.S. (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		628		609
Foreign Pension Plans, Defined Benefit [Member] | International (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		428		450
Foreign Pension Plans, Defined Benefit [Member] | Common/Collective Trusts(Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		156		214
Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		407		340
Foreign Pension Plans, Defined Benefit [Member] | Government (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		470		493
Foreign Pension Plans, Defined Benefit [Member] | Corporate (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
Foreign Pension Plans, Defined Benefit [Member] | Corporate Measured at Net Asset Value (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	[1]	155		172
Foreign Pension Plans, Defined Benefit [Member] | Agency and Mortgage Backed Securities Measured at Net Asset Value (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	[1]	27		36
Foreign Pension Plans, Defined Benefit [Member] | Common/Collective Trusts (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		385		406
Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		137		136
Foreign Pension Plans, Defined Benefit [Member] | Cash and Cash Equivalents [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		48		46
Foreign Pension Plans, Defined Benefit [Member] | Cash and Cash Equivalents Measured at Net Asset Value [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	[1]	11		10
Foreign Pension Plans, Defined Benefit [Member] | Private Equity Funds [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
Foreign Pension Plans, Defined Benefit [Member] | Derivatives [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		18		(26)
Foreign Pension Plans, Defined Benefit [Member] | Real Estate [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		111		104
Foreign Pension Plans, Defined Benefit [Member] | Real Estate Measured at Net Asset Value [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	[1]	76		65
Foreign Pension Plans, Defined Benefit [Member] | Subtotal in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		2,788		2,772
Foreign Pension Plans, Defined Benefit [Member] | Grand Total in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		3,057	[2]	3,055	[3]
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | U.S. (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		628		609
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | International (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		428		450
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Mutual Funds (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		268		234
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Government (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		470		493
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Mutual Funds (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		137		136
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Cash and Cash Equivalents [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		48		46
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Derivatives [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		18		(26)
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Subtotal in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		1,997		1,942
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Grand Total in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		1,997	[2]	1,942	[3]
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Common/Collective Trusts(Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		156		214
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Mutual Funds (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		139		106
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Corporate (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Common/Collective Trusts (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		385		406
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Cash and Cash Equivalents [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Subtotal in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		680		726
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Grand Total in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		680	[2]	726	[3]
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Private Equity Funds [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		0
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Real Estate [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		111		104
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Subtotal in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		111		104
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Grand Total in Fair Value Hierarchy [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets		$ 111	[2]	$ 104	[3]
[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 $121 million and net payables related to security transactions of $1 million.
[3]	Excludes the participating interest in the annuity contract with a net asset value of $125 million and net payables related to security transactions of $32 million.

Employee Benefit Plans - Benefi

Employee Benefit Plans - Benefit payments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Share-based compensation expense recognized in income and the associated tax benefit
Compensation cost	$ 272	$ 362	$ 358
Tax benefit	$ 92	$ 123	$ 125
Stock Option Plan Contractual Term	10 years
United States Pension Plans of US Entity, Defined Benefit [Member]
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:
2,017	$ 352
2,018	290
2,019	287
2,020	277
2,021	292
2022-2026	1,374
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:
2,017	116
2,018	131
2,019	124
2,020	129
2,021	137
2022-2026	729
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:
2,017	42
2,018	39
2,019	36
2,020	34
2,021	30
2022-2026	$ 109

Employee Benefit Plans (Severan

Employee Benefit Plans (Severances) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Supplemental Unemployment Benefits [Line Items]
Foreign currency translation adjustments	$ 153	$ (5,199)	$ (3,539)
Employee Severance
Supplemental Unemployment Benefits [Line Items]
Severance Accrual	80	$ 156
Payments For Postemployment Benefits	(206)
Severance accrual current period change	129
Foreign currency translation adjustments	1
Short term supplemental unemployment beneffits	$ 52

Employee Benefit Plans - Stock

Employee Benefit Plans - Stock option activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Assumptions used
Risk-free interest rate	1.55%	1.79%	1.86%
Dividend yield	4.00%	4.00%	4.00%
Volatility factor	26.80%	23.32%	25.31%
Expected life (years)	6 years 4 months 13 days	5 years 9 months 15 days	6 years 1 month 13 days
Summary of Stock Options Activity
Stock option, exercisable	15,932,144
Weighted-Average Exercise Price at the beginning of year	$ 55.88
Weighted-Average Exercise Price, granted	33.13
Weighted-Average Exercise Price, exercised	48.8
Weighted-Average Exercise Price, forfeited	34.51
Weighted-Average Exercise Price, expired or canceled	45.46
Weighted-Average Exercise Price at the end of year	52.14	$ 55.88
Weighted-Average Exercise Price, vested	52.85
Weighted-Average Exercise Price, Exercisable	$ 53.56
Aggregate Intrinsic Value, outstanding	$ 128	$ 42
Aggregate Intrinsic Value, vested	93
Aggregate Intrinsic Value, exercisable	$ 55
Stock option Outstanding at the beginning of year	20,184,810
Stock option, granted	4,434,400
Stock option, exercised	(62,536)
Stock option, forfeited	(272,646)
Stock option, expired or canceled	(571,916)
Stock option Outstanding at the end of year	23,712,112	20,184,810
Stock option, vested	20,192,822

Employee Benefit Plans - Sto105

Employee Benefit Plans - Stock unit activity (Details) - Stock Unit Program [Member] - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Summary of stock unit activity
Stock Units, Outstanding beginning of year	9,178,165
Stock Units, Granted	4,613,469
Stock Units, Forfeited	(169,018)
Stock Units, Issued/Settled	(5,115,112)
Stock Units, Outstanding ending of year	8,507,504	9,178,165
Stock Units Not Vested, ending of year	5,990,350
Weighted-Average Grant-Date Fair Value, beginning of year	$ 59.8
Weighted-Average Grant-Date Fair Value, Granted	32.15
Weighted-Average Grant-Date Fair Value, Forfeited	30.46
Weighted-Average Grant-Date Fair Value, ending of year	48.65	$ 59.8
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 48.29
Total Fair Value, Issued	$ 191	$ 316	$ 256

Employee Benefit Plans - Perfor

Employee Benefit Plans - Performance Share Program activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock Settled Performance Share Program [Member]
Summary of Performance Share Program activity
Stock Units, Outstanding beginning of year	4,270,222
Stock Units, Granted	48,065
Stock Units, Issued/Settled	(428,763)
Stock Units, Outstanding ending of year	3,889,524	4,270,222
Stock Units Not Vested, ending of year	606,085
Weighted-Average Grant-Date Fair Value, beginning of year	$ 51.95
Weighted-Average Grant-Date Fair Value, Granted	33.13
Weighted-Average Grant-Date Fair Value, ending of year	51.93	$ 51.95
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 53.34
Total Fair Value, Issued	$ 17	$ 25	$ 18
Cash Settled Performance Share Program [Member]
Summary of Performance Share Program activity
Stock Units, Outstanding beginning of year	1,459,236
Stock Units, Granted	684,386
Stock Units, Issued/Settled	(868,860)
Stock Units, Outstanding ending of year	1,274,762	1,459,236
Stock Units Not Vested, ending of year	584,789
Weighted-Average Grant-Date Fair Value, beginning of year	$ 46.54
Weighted-Average Grant-Date Fair Value, Granted	33.13
Weighted-Average Grant-Date Fair Value, ending of year	50.39	$ 46.54
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 50.39
Total Fair Value, Issued	$ 31	$ 6	$ 0

Employee Benefit Plans - Restri

Employee Benefit Plans - Restricted shares and units (Details) - Restricted Stock Units (RSUs) [Member] $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)$ / sharesshares
Summary of aggregate activity of restricted shares and units
Stock Units, Outstanding beginning of year | shares	1,272,136
Stock Units, Granted | shares	99,300
Stock Units, Forfeited | shares	(15,964)
Stock Units, Issued/Settled | shares	(37,508)
Stock Units, Outstanding ending of year | shares	1,317,964
Weighted-Average Grant-Date Fair Value, beginning of year | $ / shares	$ 33.25
Weighted-Average Grant-Date Fair Value, Granted | $ / shares	40.36
Weighted-Average Grant-Date Fair Value, Forfeited | $ / shares	20.69
Weighted-Average Grant-Date Fair Value, ending of year | $ / shares
Weighted-Average Grant-Date Fair Value Not Vested, ending of year | $ / shares	$ 33.16
Total Fair Value, Issued | $	$ 2

Employee Benefits Plans (Detail

Employee Benefits Plans (Details Textual) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)investmentsshares	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Plan Assets (Textual) [Abstract]
Fair value of participating interest in annuity contract	$ 121	$ 125
Decrease In Fair Value Of Debt Securities	17
Decrease in Present Value of Contract Obligation	$ 13
Defined Contribution Plans (Textual) [Abstract]
Employees maximum percent to deposit in saving plan	75.00%
Number of investment funds in which employee can contribute | investments	34
Employer matching contribution up to a certain percentage of pay			0.00%
Company contributions in savings plan and predecessor plans except leveraged employee stock ownership plan charged to expense	$ 58	109	$ 116
CPSP stock savings feature shares
Dividends used to service debt			0
Interest incurred on the CPSP debt			0
Share Based Compensation Plans (Textual) [Abstract]
Omnibus Stock and Performance Incentive Plan life	10 years
Authorized common stock for compensation plan, maximum | shares	79
Common stock available under incentive stock options, maximum | shares	40
Pension And Postretirement Plans (Textual) [Abstract]
Pension settlement losses	$ 202	204
Stock Savings Feature [Member]
Defined Contribution Plans (Textual) [Abstract]
Company contributions in savings plan and predecessor plans except leveraged employee stock ownership plan charged to expense			0
CPSP stock savings feature shares
Cash contribution to the CPSP			0
ConocoPhilips Pension Plan [Member]
Defined Contribution Plans (Textual) [Abstract]
Employer matching contribution up to a certain percentage of pay	6.00%
Employer matching discretionary contribution	6.00%
CPSP stock savings feature shares
Defined contribution plan employee contribution percent	1.00%
Equity Securities [Member]
Plan Assets (Textual) [Abstract]
Target allocations for plan assets	57.00%
Debt Securities [Member]
Plan Assets (Textual) [Abstract]
Target allocations for plan assets	37.00%
Real Estate [Member]
Plan Assets (Textual) [Abstract]
Target allocations for plan assets	6.00%
Fair Value, Inputs, Level 3 [Member]
Plan Assets (Textual) [Abstract]
Fair value of participating interest in debt security	$ 288	305
Accumulated benefit obligation covered by the contract	167	180
United States Pension Plans of US Entity, Defined Benefit [Member]
Pension And Postretirement Plans (Textual) [Abstract]
Pension settlement losses	202	197
Foreign Pension Plans, Defined Benefit [Member]
Pension And Postretirement Plans (Textual) [Abstract]
Pension settlement losses		7
International qualified and nonqualified pension and postretirement benefit plans [Member]
Plan Assets (Textual) [Abstract]
Expected contribution to qualified and nonqualified pension and postretirement benefit	110
Defined Contribution Plans (Textual) [Abstract]
Company contributions in savings plan and predecessor plans except leveraged employee stock ownership plan charged to expense	44	55	$ 66
Domestic qualified and nonqualified pension and postretirement benefit plans [Member]
Plan Assets (Textual) [Abstract]
Expected contribution to qualified and nonqualified pension and postretirement benefit	320
Tax qualified pension plan [Member]
Pension And Postretirement Plans (Textual) [Abstract]
Tax-qualified pension plans with projected benefit obligations in excess of plan assets	5,498	5,720
Tax-qualified pension plans with accumulated benefit obligation in excess of plan assets	5,145	5,314
Tax-qualified pension plans with fair value of plan assets in excess of plan assets	4,208	4,759
Unfunded non qualified key employee pension plan [Member]
Pension And Postretirement Plans (Textual) [Abstract]
Tax-qualified pension plans with projected benefit obligations in excess of plan assets	586	639
Tax-qualified pension plans with accumulated benefit obligation in excess of plan assets	$ 496	$ 564

Employee Benefits Plans (Det109

Employee Benefits Plans (Details Textual 1) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Stock Option [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Vest ratably options term, in year	10 years
Portion of options or units that are vesting	33.00%
Vesting period of stock options or stock units	6 months
Weighted-average remaining contractual term of outstanding options	5 years 8 months 2 days
Weighted-average remaining contractual term exercisable	4 years 4 months 5 days
Weighted-Average Grant-Date Fair Value, granted	$ 5.39	$ 9.54	$ 10.17
Aggregate Intrinsic Value, exercised	$ 0	$ 10	$ 89
Cash received from exercise of stock options	3
Tax benefit from exercise of options	4
Unrecognized compensation cost from stock options	$ 8
Weighted average period of recognition of unvested options, in months	10 months 20 days
Longest weighted-average period of recognition of unvested options, in months	2 years 1 month 17 days
Stock Options Vested [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-average remaining contractual term of outstanding options	5 years 3 months 7 days
Stock Unit Program [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Vest ratably options term, in year	3 years
Weighted-Average Grant-Date Fair Value, granted		$ 65.4	$ 62.72
Unrecognized compensation cost from stock options	$ 105
Weighted average period of recognition of unvested options, in months	1 year 7 months 11 days
Longest weighted-average period of recognition of unvested options, in months	2 years 9 months 1 day
Total Fair Value, Issued	$ 191	$ 316	$ 256
Performance Share Program [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Vest ratably options term, in year	3 years
Phillips 66 [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Unrecognized compensation cost from stock options	$ 1
Stock Settled Performance Share Program [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 69.25	$ 65.46
Years of service required for award	5 years
Retirement eligible age	55
Unrecognized compensation cost from stock options	$ 3
Weighted average period of recognition of unvested options, in months	1 year 9 months 4 days
Longest weighted-average period of recognition of unvested options, in months	3 years 11 months 27 days
Total Fair Value, Issued	$ 17	$ 25	$ 18
Cash Settled Performance Share Program [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 46.54	$ 69.23
Years of service required for award	5 years
PSU termination date	Dec. 31, 2016	Dec. 31, 2015
Unrecognized compensation cost from stock options	$ 7
Weighted average period of recognition of unvested options, in months	1 year 9 months 6 days
Longest weighted-average period of recognition of unvested options, in months	3 years 1 month 17 days
Total Fair Value, Issued	$ 31	$ 6	$ 0
Other [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 58.66	$ 71.23
Total Fair Value, Issued		$ 3	$ 3

Income Taxes (Details)

Income Taxes (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Liabilities
Properties, plants and equipment, and intangibles	$ 15,099,000,000	$ 16,378,000,000
Investment in joint ventures	933,000,000	866,000,000
Inventory	36,000,000	25,000,000
Deferred state income tax (liability)	203,000,000	128,000,000
Partnership income deferral	0	44,000,000
Other	486,000,000	453,000,000
Total deferred tax liabilities	16,757,000,000	17,894,000,000
Deferred Tax Assets
Benefit plan accruals	1,280,000,000	1,160,000,000
Asset retirement obligations and accrued environmental costs	3,514,000,000	4,426,000,000
Other financial accruals and deferrals	317,000,000	616,000,000
Loss and credit carryforwards	3,522,000,000	1,579,000,000
Other	250,000,000	134,000,000
Total deferred tax assets	8,883,000,000	7,915,000,000
Less valuation allowance	(675,000,000)	(734,000,000)
Net deferred tax assets	8,208,000,000	7,181,000,000
Total deferred tax liabilities	8,549,000,000	10,713,000,000
Reconciliation of the beginning and ending unrecognized tax benefits
Unrecognized Tax Benefits, Balance at January 1	459,000,000	442,000,000	$ 655,000,000
Additions based on tax positions related to the current year	32,000,000	54,000,000	46,000,000
Additions for tax positions of prior years	19,000,000	4,000,000	7,000,000
Reductions for tax positions of prior years	(118,000,000)	(37,000,000)	(228,000,000)
Settlements	(9,000,000)	(4,000,000)	(28,000,000)
Lapse of statute	(2,000,000)	0	(10,000,000)
Unrecognized Tax Benefits, Balance at December 31	381,000,000	459,000,000	442,000,000
Income (loss) before income taxes, Income Tax Reconciliation
Income (loss) before taxes - United States	(4,410,000,000)	(4,150,000,000)	2,310,000,000
Income (loss) before taxes - foreign	(1,120,000,000)	(3,089,000,000)	7,080,000,000
Income (loss) from continuing operations before income taxes	(5,530,000,000)	(7,239,000,000)	9,390,000,000
Federal statutory income tax	(1,936,000,000)	(2,534,000,000)	3,287,000,000
Non US effective tax rates	365,000,000	381,000,000	376,000,000
Foreign tax law change	(161,000,000)	(426,000,000)	0
U.S. fair value election	0	(185,000,000)
Capital loss benefit	0	0	0
Enhanded oil recovery credit	(62,000,000)
State income tax	(131,000,000)	(89,000,000)	(44,000,000)
Other	(46,000,000)	(15,000,000)	(36,000,000)
Provision for income taxes	$ (1,971,000,000)	$ (2,868,000,000)	$ 3,583,000,000
Income (loss) before income taxes, Percent of Pretax Income
Income (loss) before income taxes, United States, Percentage	79.70%	57.30%	24.60%
Income (loss) before income taxes, Foreign, Percentage	20.30%	42.70%	75.40%
Income (loss) before income taxes, Percent	100.00%	100.00%	100.00%
Domestic federal statutory rate	35.00%	35.00%	35.00%
Non US effective tax rates	(6.60%)	(5.30%)	4.00%
Foreign tax law change percent	2.90%	5.90%	0.00%
U.S. fair value election percent	0.00%	2.60%	0.00%
Capital loss benefit, Percent	0.00%	0.00%	0.00%
Enhanced oil recovery credit, Rate	1.10%
State income tax, Rate	2.40%	1.20%	(0.50%)
Other, Rate	0.80%	0.20%	(0.40%)
Total Income taxes charged to income (loss), Rate	35.60%	39.60%	38.10%
Income Taxes (Textual) [Abstract]
Deferred taxes Included in long-term assets	$ 400,000,000	$ 286,000,000
Deferred taxes Included in long-term liabilities	8,949,000,000	10,999,000,000
Income considered to be permanently reinvested in foreign subsidiaries and foreign corporate joint ventures	3,720,000,000
Unrecognized tax benefits that if recognized, would affect effective tax rate	359,000,000	354,000,000	$ 348,000,000
Accrued liabilities for interest and penalties	54,000,000	79,000,000	65,000,000
Interest and penalties (benefiting) charging earnings	(18,000,000)	11,000,000	(43,000,000)
Earnings reduction due to deferred tax remeasurement			0
Valuation Allowance [Line Items]
Worthless Security Deduction	60,000,000	491,000,000	122,000,000
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)	393,000,000	745,000,000	$ 2,846,000,000
Valuation Allowance Amount Of Decrease [Member]
Valuation Allowance [Line Items]
Increase (decrease) in valuation allowance	(59,000,000)
Canada [Member]
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)	$ 0	$ 129,000,000
Corporation Tax Rate pre legislation	0.00%	25.00%
Corporation Tax Rate post legislation	0.00%	27.00%
United Kingdom [Member]
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)	$ (161,000,000)	$ (555,000,000)
Corporation Tax Rate pre legislation	50.00%	62.00%
Corporation Tax Rate post legislation	40.00%	50.00%

Income Taxes (Carryforwards)

Income Taxes (Carryforwards) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Components of Our Loss and Credit Carryforwards [Line Items]
State net operating losses and tax credits	$ 0	$ 0
Loss and credit carryforwards	3,522	$ 1,579
Gross Deferred Tax Asset [Member] | 2036
Components of Our Loss and Credit Carryforwards [Line Items]
U.S. federal net operating loss	1,648
Gross Deferred Tax Asset [Member] | 2025-2026
Components of Our Loss and Credit Carryforwards [Line Items]
U.S. foreign tax credits	480
Gross Deferred Tax Asset [Member] | 2031
Components of Our Loss and Credit Carryforwards [Line Items]
U.S. general business credits	96
Gross Deferred Tax Asset [Member] | Post 2024
Components of Our Loss and Credit Carryforwards [Line Items]
State net operating losses and tax credits	502
Gross Deferred Tax Asset [Member] | Post 2025
Components of Our Loss and Credit Carryforwards [Line Items]
Foreign net operating losses and tax credits	$ 796

Income Taxes Carryforward VA

Income Taxes Carryforward VA - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015
Components of our loss and credit carryforwards after val allow [Line Items]
Net deferred tax assets	$ 8,208	$ 7,181
Net Deferred Tax Asset After Valuation Allowance [Member]
Components of our loss and credit carryforwards after val allow [Line Items]
Net deferred tax assets	2,872
Net Deferred Tax Asset After Valuation Allowance [Member] | 2036
Components of our loss and credit carryforwards after val allow [Line Items]
U.S. federal net operating loss after valuation allowance	1,648
Net Deferred Tax Asset After Valuation Allowance [Member] | 2025-2026
Components of our loss and credit carryforwards after val allow [Line Items]
U.S. foreign tax credits after valuation allowance	296
Net Deferred Tax Asset After Valuation Allowance [Member] | 2031
Components of our loss and credit carryforwards after val allow [Line Items]
U.S. general business credits after valuation allowance	96
Net Deferred Tax Asset After Valuation Allowance [Member] | Post 2024
Components of our loss and credit carryforwards after val allow [Line Items]
State net operating losses and tax credits after valuation allowance	49
Net Deferred Tax Asset After Valuation Allowance [Member] | Post 2025
Components of our loss and credit carryforwards after val allow [Line Items]
Foreign net operating losses and tax credits after valuation allowance	$ 783

Income Taxes (Details 1)

Income Taxes (Details 1) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Federal
Current	$ (9,000,000)	$ (718,000,000)	$ 188,000,000
Deferred	(1,634,000,000)	(1,443,000,000)	365,000,000
Foreign
Current	393,000,000	745,000,000	2,846,000,000
Deferred	(519,000,000)	(1,315,000,000)	252,000,000
State and local
Current	(135,000,000)	8,000,000	46,000,000
Deferred	(67,000,000)	(145,000,000)	(114,000,000)
Provision for income taxes	$ (1,971,000,000)	$ (2,868,000,000)	$ 3,583,000,000

Accumulated Other Comprehens114

Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Accumulated other comprehensive income
Defined Benefit Plans, Beginning Balance		$ (443)	$ (1,261)	$ (824)
Foreign Currency Translation, Beginning Balance		(5,804)	(641)	2,826
Hedging, Beginning Balance			0	0
Accumulated Other Comprehensive Income (loss), Beginning Balance		(6,247)	(1,902)	2,002
Defined Benefit Pension Plans		(104)	818	(437)
Defined Benefit Plans, Separation of Downstream Business				0
Foreign Currency Translation		158	(5,163)	(3,467)
Foreign Currency Translation, Separation of Downstream Business				0
Hedging				0
Other Comprehensive Income, Net of Tax, Separation of Downstream Business				0
Other Comprehensive Income (Loss), Net of Tax		54	(4,345)	(3,904)
Defined Benefit Plans, Ending Balance		(547)	(443)	(1,261)
Foreign Currency Translation, Ending Balance		(5,646)	(5,804)	(641)
Hedging, Ending Balance				0
Accumulated Other Comprehensive Income (loss), Ending Balance		(6,193)	(6,247)	$ (1,902)
Reclassification out of Accumulated Other Comprehensive Income [Abstract]
Defined Benefit Plans	[1],[2]	179	251
Other Comprehensive (Income) Loss Reclassification Adjustment From AOCI Pension And Other Postretirement Benefit Plans, Tax		$ 95	$ 133
[1]	Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $95 $133
[2]	See Note 18—Employee Benefit Plans, for additional information.

Cash Flow Information (Details)

Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016		Dec. 31, 2015		Dec. 31, 2014
Noncash Investing and Financing Activities
Increase in PP&E related to increase in asset retirement obligations	$ (1,017)		$ 402		$ 1,611	[1]
Cash payments
Interest	1,151		920		669
Income taxes	(318)	[2]	523	[2]	4,203
Proceeds From Income Tax Refunds	642		585
Net Sales (Purchases) of Short-Term Investments
Short-term investments purchased	(1,753)		0		(876)
Short-term investments sold	1,702		0		1,129
Net Sales (Purchases) of Short-Term Investments	(51)		0		253
ARO increase related to UK tax law changes	0		0		68
Accounting Changes And Error Corrections [Abstract]
Working capital changes associated with investing activities	$ (331)		$ (968)		$ 180
[1]	*Includes $68 million in 2014, primarily related to the impact of U.K. tax law changes on the deductibility of decommissioning costs.
[2]	**Net of $585 million and $642 million in 2016 and 2015, respectively, related to refunds received from the Internal Revenue Service.

Other Financial Information (De

Other Financial Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		$ (26)	$ (64)	$ (44)
Incurred
Debt		1,279	1,130	1,063
Other		123	84	73
Interest Costs Incurred, Total		1,402	1,214	1,136
Capitalized		(157)	(294)	(488)
Expensed		1,245	920	648
Other Income
Interest income		57	45	83
Other, net		198	80	283
Other Nonoperating Income		255	125	366
Research and Development Expenditures - expensed		116	222	263
Shipping and Handling Costs	[1]	1,139	1,181	1,360
Lower 48 [Member]
Other Income
Interest income		0	0	35
Canada [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		1	0	(4)
Europe and North Africa
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		(7)	(22)	(56)
Other Income
Interest income		2	2	2
Asia Pacific and Middle East [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		(9)	(78)	0
Other Income
Interest income		8	6	6
Other International [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		7	(9)	0
Other Income
Interest income		0	1	0
Corporate and Other [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		(18)	45	16
Other Income
Interest income		$ 47	$ 36	$ 40
[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, 2016	Dec. 31, 2015
Properties, Plants And Equipment
Proved properties	$ 119,970	$ 122,796
Unproved properties	5,150	7,410
Other	6,286	6,653
Gross properties, plants and equipment	131,406	136,859
Accumulated depreciation	(73,075)	(70,413)
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $73,075 million in 2016 and $70,413 million in 2015)	$ 58,331	66,446
Assets held for sale, formerly in proved properties		0
Assets held for sale, formerly in unproved properties		$ 0

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Significant transactions with related parties
Operating revenues and other income		$ 133	$ 118	$ 119
Purchases		101	97	190
Operating expenses and selling, general and administrative expenses		63	62	70
Net interest expense (neg)	[1]			$ (44)
Net Interest Income (neg)	[2]	$ (12)	$ 9
[1]	*We paid interest to, or received interest from, various affiliates. See Note 7—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 7—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) $ in Millions	12 Months Ended
	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)
Sales and Operating Revenues by Segment
Sales and other operating revenues	$ 23,693	$ 29,564	$ 52,524
Number of Operating Segments	6
Alaska [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	$ 3,681	4,351	8,382
Lower 48 Before Intersegment Eliminations [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	10,719	11,976	21,721
Intersegment Eliminations before Lower 48 [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	(17)	(63)	(107)
Lower 48 [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	10,702	11,913	21,614
Canada before Intersegment Eliminations [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	2,192	2,454	5,162
Intersegment Eliminations before Canada [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	(218)	(318)	(753)
Canada [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	1,974	2,136	4,409
Europe and North Africa before Intersegment Eliminations [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	3,462	6,110	10,665
Intersegment Eliminations before Europe [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	0	(4)	(49)
Europe and North Africa
Sales and Operating Revenues by Segment
Sales and other operating revenues	3,462	6,106	10,616
Asia Pacific before Intersegment Eliminations [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	3,705	4,746	7,425
Intersegment Eliminations before Asia Pacific [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	0	(1)	(1)
Asia Pacific and Middle East [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	3,705	4,745	7,424
Other International [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	0	1	0
Corporate and Other [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	$ 169	$ 312	$ 79

Segment Disclosures - Depreciat

Segment Disclosures - Depreciation, Equity Earnings, Income Tax (Details) - USD ($)	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	$ 9,201,000,000	$ 11,358,000,000	$ 9,185,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	52,000,000	655,000,000	2,529,000,000
Income Taxes
Provision (benefit) for income taxes	(1,971,000,000)	(2,868,000,000)	3,583,000,000
Alaska State [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	868,000,000	690,000,000	584,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	9,000,000	4,000,000	9,000,000
Income Taxes
Provision (benefit) for income taxes	(59,000,000)	(71,000,000)	1,081,000,000
Lower 48 [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	4,358,000,000	4,227,000,000	3,911,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	(6,000,000)	(5,000,000)	1,000,000
Income Taxes
Provision (benefit) for income taxes	(1,328,000,000)	(1,119,000,000)	(92,000,000)
Canada [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	975,000,000	788,000,000	962,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	89,000,000	78,000,000	1,385,000,000
Income Taxes
Provision (benefit) for income taxes	(383,000,000)	(223,000,000)	236,000,000
Europe and North Africa
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	1,253,000,000	2,565,000,000	2,345,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	22,000,000	23,000,000	37,000,000
Income Taxes
Provision (benefit) for income taxes	(46,000,000)	(854,000,000)	1,590,000,000
Asia Pacific and Middle East [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	1,606,000,000	2,981,000,000	1,275,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	(51,000,000)	550,000,000	1,089,000,000
Income Taxes
Provision (benefit) for income taxes	306,000,000	467,000,000	1,194,000,000
Other International [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	1,000,000	0	1,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	0	8,000,000	9,000,000
Income Taxes
Provision (benefit) for income taxes	(40,000,000)	(456,000,000)	(102,000,000)
Corporate and Other [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	140,000,000	107,000,000	107,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	(11,000,000)	(3,000,000)	(1,000,000)
Income Taxes
Provision (benefit) for income taxes	$ (421,000,000)	$ (612,000,000)	$ (324,000,000)

Segment Disclosures - Net Incom

Segment Disclosures - Net Income (Loss), Investments, Total Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	$ (3,615)	$ (4,428)	$ 6,869
Investments In and Advances To Affiliates
Investments in and advances to affiliates	20,945	20,546	24,230
Total Assets
Total assets	89,772	97,484	116,539
Alaska State [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	319	4	2,041
Investments In and Advances To Affiliates
Investments in and advances to affiliates	58	61	53
Total Assets
Total assets	12,314	12,555	12,655
Lower 48 [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(2,257)	(1,932)	(22)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	426	455	471
Total Assets
Total assets	22,673	26,932	30,185
Canada [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(935)	(1,044)	940
Investments In and Advances To Affiliates
Investments in and advances to affiliates	8,784	8,165	9,484
Total Assets
Total assets	17,548	17,221	21,764
Europe and North Africa
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	394	409	814
Investments In and Advances To Affiliates
Investments in and advances to affiliates	62	70	126
Total Assets
Total assets	11,727	13,703	16,970
Asia Pacific and Middle East [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	209	(463)	2,939
Investments In and Advances To Affiliates
Investments in and advances to affiliates	11,611	11,780	14,022
Total Assets
Total assets	20,451	22,318	25,976
Other International [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(16)	(593)	(100)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	0	0	59
Total Assets
Total assets	97	282	1,116
Corporate and Other [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(1,329)	(809)	(874)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	4	15	15
Total Assets
Total assets	4,962	4,473	7,815
Discontinued Operations [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	0	0	1,131
Total Assets
Total assets	$ 0	$ 0	$ 58

Segment Disclosures - Capital E

Segment Disclosures - Capital Expenditures and Interest (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Capital Expenditures and Investments
Consolidated capital expenditures and investments	$ 4,869	$ 10,050	$ 17,085
Interest Income and Expense
Interest income	57	45	83
Alaska State [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	883	1,352	1,564
Lower 48 [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	1,262	3,765	6,054
Interest Income and Expense
Interest income	0	0	35
Canada [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	698	1,255	2,340
Interest Income and Expense
Interest and debt expense	0	0	0
Europe and North Africa
Capital Expenditures and Investments
Consolidated capital expenditures and investments	1,020	1,573	2,540
Interest Income and Expense
Interest income	2	2	2
Asia Pacific and Middle East [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	838	1,812	3,877
Interest Income and Expense
Interest income	8	6	6
Other International [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	104	173	520
Interest Income and Expense
Interest income	0	1	0
Corporate and Other [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	64	120	190
Interest Income and Expense
Interest income	47	36	40
Interest and debt expense	$ 1,245	$ 920	$ 648

Segment Disclosures - Sales by

Segment Disclosures - Sales by Product (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product		$ 23,693	$ 29,564	$ 52,524
Crude Oil [Member]
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product		10,801	12,830	23,784
Natural Gas [Member]
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product		9,401	11,888	20,717
Natural Gas Liquids [Member]
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product		837	952	2,245
Other Products [Member]
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product	[1]	$ 2,654	$ 3,894	$ 5,778
[1]	*Includes LNG and bitumen.

Segment Disclosures - Geographi

Segment Disclosures - Geographic Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Geographic Information
Sales and other operating revenues		$ 23,693	$ 29,564	$ 52,524
Long-Lived Assets	[1]	79,276	86,992	99,674
UNITED STATES
Geographic Information
Sales and other operating revenues		14,400	16,284	30,019
Long-Lived Assets	[1]	32,949	37,445	39,641
AUSTRALIA
Geographic Information
Sales and other operating revenues	[2]	1,353	2,127	3,258
Long-Lived Assets	[1],[2]	12,259	12,788	14,969
CANADA
Geographic Information
Sales and other operating revenues		1,974	2,136	4,409
Long-Lived Assets	[1]	16,846	16,766	20,874
CHINA
Geographic Information
Sales and other operating revenues		551	782	1,701
Long-Lived Assets	[1]	1,372	1,647	1,913
INDONESIA
Geographic Information
Sales and other operating revenues		938	1,165	1,963
Long-Lived Assets	[1]	856	1,191	1,526
MALAYSIA
Geographic Information
Sales and other operating revenues		735	598	403
Long-Lived Assets	[1]	3,323	3,599	3,811
NORWAY
Geographic Information
Sales and other operating revenues		1,645	2,107	3,794
Long-Lived Assets	[1]	6,228	6,933	8,142
UNITED KINGDOM
Geographic Information
Sales and other operating revenues		1,816	4,005	6,594
Long-Lived Assets	[1]	3,209	4,154	5,327
Segment Geographical Groups of Countries Other [Member]
Geographic Information
Sales and other operating revenues		281	360	383
Long-Lived Assets	[1]	$ 2,234	$ 2,469	$ 3,471
[1]	Defined as net PP&E plus investments in and advances to affiliated companies.
[2]	Includes amounts related to the joint petroleum development area with shared ownership held by Australia and Timor-Leste.

Segment Disclosures - Textuals

Segment Disclosures - Textuals (Details Textual)	12 Months Ended
	Dec. 31, 2016
Segment Disclosures and Related Information (Textual) [Abstract]
Number of operating segments	6

Supplementary Information - 126

Supplementary Information - Condensed Consolidating Financial Information Income Statement (Details) - USD ($)		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Revenues and Other Income
Sales and other operating revenues		$ 23,693,000,000	$ 29,564,000,000	$ 52,524,000,000
Equity in earnings of affiliates		52,000,000	655,000,000	2,529,000,000
Gain on dispositions		360,000,000	591,000,000	98,000,000
Other income		255,000,000	125,000,000	366,000,000
Intercompany Revenues			0	0
Total Revenues and Other Income		24,360,000,000	30,935,000,000	55,517,000,000
Costs and Expenses
Purchased commodities		9,994,000,000	12,426,000,000	22,099,000,000
Production and operating expenses		5,667,000,000	7,016,000,000	8,909,000,000
Selling, general and administrative expenses		723,000,000	953,000,000	735,000,000
Exploration expenses		1,915,000,000	4,192,000,000	2,045,000,000
Depreciation, depletion and amortization		9,062,000,000	9,113,000,000	8,329,000,000
Impairments		139,000,000	2,245,000,000	856,000,000
Taxes other than income taxes		739,000,000	901,000,000	2,088,000,000
Accretion on discounted liabilities		425,000,000	483,000,000	484,000,000
Interest and debt expense		1,245,000,000	920,000,000	648,000,000
Foreign currency transaction (gains) losses		(19,000,000)	(75,000,000)	(66,000,000)
Total Costs and Expenses		29,890,000,000	38,174,000,000	46,127,000,000
Income (loss) before income taxes		(5,530,000,000)	(7,239,000,000)	9,390,000,000
Provision (benefit) for income taxes		(1,971,000,000)	(2,868,000,000)	3,583,000,000
Income (Loss) From Continuing Operations		(3,559,000,000)	(4,371,000,000)	5,807,000,000
Income (loss) from discontinued operations	[1]			1,131,000,000
Net income (loss)		(3,559,000,000)	(4,371,000,000)	6,938,000,000
Less: net income attributable to noncontrolling interests		(56,000,000)	(57,000,000)	(69,000,000)
Net income (loss) attributable to ConocoPhillips		(3,615,000,000)	(4,428,000,000)	6,869,000,000
Comprehensive Income Attributable to ConocoPhillips		(3,561,000,000)	(8,773,000,000)	2,965,000,000
ConocoPhillips [Member]
Revenues and Other Income
Sales and other operating revenues				0
Equity in earnings of affiliates		(3,351,000,000)	(4,081,000,000)	6,108,000,000
Gain on dispositions				0
Other income		1,000,000	0	(6,000,000)
Intercompany Revenues		88,000,000	74,000,000	79,000,000
Total Revenues and Other Income		(3,262,000,000)	(4,007,000,000)	6,181,000,000
Costs and Expenses
Purchased commodities				0
Production and operating expenses			0	0
Selling, general and administrative expenses		8,000,000	9,000,000	9,000,000
Exploration expenses			0	0
Depreciation, depletion and amortization			0	0
Impairments			0	0
Taxes other than income taxes			0	0
Accretion on discounted liabilities			0	0
Interest and debt expense		506,000,000	485,000,000	571,000,000
Foreign currency transaction (gains) losses		(19,000,000)	114,000,000	62,000,000
Total Costs and Expenses		495,000,000	608,000,000	642,000,000
Income (loss) before income taxes		(3,757,000,000)	(4,615,000,000)	5,539,000,000
Provision (benefit) for income taxes		(142,000,000)	(187,000,000)	(199,000,000)
Income (Loss) From Continuing Operations		(3,615,000,000)		5,738,000,000
Income (loss) from discontinued operations		0		1,131,000,000
Net income (loss)		(3,615,000,000)	(4,428,000,000)	6,869,000,000
Less: net income attributable to noncontrolling interests				0
Net income (loss) attributable to ConocoPhillips		(3,615,000,000)	(4,428,000,000)	6,869,000,000
Comprehensive Income Attributable to ConocoPhillips		(3,561,000,000)	(8,773,000,000)	2,965,000,000
ConocoPhillips Company [Member]
Revenues and Other Income
Sales and other operating revenues		10,352,000,000	11,473,000,000	20,083,000,000
Equity in earnings of affiliates		(1,051,000,000)	(1,950,000,000)	8,090,000,000
Gain on dispositions		120,000,000	332,000,000	9,000,000
Other income		(11,000,000)	12,000,000	67,000,000
Intercompany Revenues		277,000,000	341,000,000	465,000,000
Total Revenues and Other Income		9,687,000,000	10,208,000,000	28,714,000,000
Costs and Expenses
Purchased commodities		9,144,000,000	9,905,000,000	17,591,000,000
Production and operating expenses		779,000,000	1,469,000,000	2,600,000,000
Selling, general and administrative expenses		581,000,000	744,000,000	575,000,000
Exploration expenses		1,231,000,000	2,093,000,000	1,036,000,000
Depreciation, depletion and amortization		1,178,000,000	1,201,000,000	1,059,000,000
Impairments		67,000,000	15,000,000	127,000,000
Taxes other than income taxes		162,000,000	173,000,000	285,000,000
Accretion on discounted liabilities		46,000,000	58,000,000	58,000,000
Interest and debt expense		622,000,000	423,000,000	299,000,000
Foreign currency transaction (gains) losses		2,000,000	1,000,000	10,000,000
Total Costs and Expenses		13,812,000,000	16,082,000,000	23,640,000,000
Income (loss) before income taxes		(4,125,000,000)	(5,874,000,000)	5,074,000,000
Provision (benefit) for income taxes		(774,000,000)	(1,793,000,000)	(1,034,000,000)
Income (Loss) From Continuing Operations		(3,351,000,000)		6,108,000,000
Income (loss) from discontinued operations		0		1,131,000,000
Net income (loss)		(3,351,000,000)	(4,081,000,000)	7,239,000,000
Less: net income attributable to noncontrolling interests				0
Net income (loss) attributable to ConocoPhillips		(3,351,000,000)	(4,081,000,000)	7,239,000,000
Comprehensive Income Attributable to ConocoPhillips		(3,297,000,000)	(8,426,000,000)	3,335,000,000
ConocoPhillips Canada Funding Company I [Member]
Revenues and Other Income
Intercompany Revenues		220,000,000	246,000,000	283,000,000
Total Revenues and Other Income		220,000,000	246,000,000	283,000,000
Costs and Expenses
Selling, general and administrative expenses		0	1,000,000	1,000,000
Interest and debt expense		207,000,000	226,000,000	231,000,000
Foreign currency transaction (gains) losses		174,000,000	(708,000,000)	(372,000,000)
Total Costs and Expenses		381,000,000	(481,000,000)	(140,000,000)
Income (loss) before income taxes		(161,000,000)	727,000,000	423,000,000
Provision (benefit) for income taxes		(9,000,000)	21,000,000	19,000,000
Income (Loss) From Continuing Operations		(152,000,000)		404,000,000
Net income (loss)		(152,000,000)	706,000,000	404,000,000
Net income (loss) attributable to ConocoPhillips		(152,000,000)	706,000,000	404,000,000
Comprehensive Income Attributable to ConocoPhillips		(27,000,000)	71,000,000	58,000,000
All Other Subsidiaries [Member]
Revenues and Other Income
Sales and other operating revenues		13,341,000,000	18,091,000,000	32,441,000,000
Equity in earnings of affiliates		(91,000,000)	1,364,000,000	2,932,000,000
Gain on dispositions		240,000,000	259,000,000	89,000,000
Other income		265,000,000	113,000,000	305,000,000
Intercompany Revenues		3,036,000,000	3,365,000,000	5,883,000,000
Total Revenues and Other Income		16,791,000,000	23,192,000,000	41,650,000,000
Costs and Expenses
Purchased commodities		3,562,000,000	5,838,000,000	10,415,000,000
Production and operating expenses		5,131,000,000	5,585,000,000	6,368,000,000
Selling, general and administrative expenses		140,000,000	209,000,000	166,000,000
Exploration expenses		684,000,000	2,099,000,000	1,009,000,000
Depreciation, depletion and amortization		7,884,000,000	7,912,000,000	7,270,000,000
Impairments		72,000,000	2,230,000,000	729,000,000
Taxes other than income taxes		577,000,000	728,000,000	1,803,000,000
Accretion on discounted liabilities		379,000,000	425,000,000	426,000,000
Interest and debt expense		570,000,000	447,000,000	275,000,000
Foreign currency transaction (gains) losses		(176,000,000)	518,000,000	234,000,000
Total Costs and Expenses		18,823,000,000	25,991,000,000	28,695,000,000
Income (loss) before income taxes		(2,032,000,000)	(2,799,000,000)	12,955,000,000
Provision (benefit) for income taxes		(1,046,000,000)	(909,000,000)	4,797,000,000
Income (Loss) From Continuing Operations		(986,000,000)		8,158,000,000
Income (loss) from discontinued operations		0		113,000,000
Net income (loss)		(986,000,000)	(1,890,000,000)	8,271,000,000
Less: net income attributable to noncontrolling interests		(56,000,000)	(57,000,000)	(69,000,000)
Net income (loss) attributable to ConocoPhillips		(1,042,000,000)	(1,947,000,000)	8,202,000,000
Comprehensive Income Attributable to ConocoPhillips		(952,000,000)	(6,705,000,000)	4,589,000,000
Consolidating Adjustments [Member]
Revenues and Other Income
Equity in earnings of affiliates		4,545,000,000	5,322,000,000	(14,601,000,000)
Intercompany Revenues		(3,621,000,000)	(4,026,000,000)	(6,710,000,000)
Total Revenues and Other Income		924,000,000	1,296,000,000	(21,311,000,000)
Costs and Expenses
Purchased commodities		(2,712,000,000)	(3,317,000,000)	(5,907,000,000)
Production and operating expenses		(243,000,000)	(38,000,000)	(59,000,000)
Selling, general and administrative expenses		(6,000,000)	(10,000,000)	(16,000,000)
Interest and debt expense		(660,000,000)	(661,000,000)	(728,000,000)
Total Costs and Expenses		(3,621,000,000)	(4,026,000,000)	(6,710,000,000)
Income (loss) before income taxes		4,545,000,000	5,322,000,000	(14,601,000,000)
Income (Loss) From Continuing Operations		4,545,000,000		(14,601,000,000)
Income (loss) from discontinued operations		0		(1,244,000,000)
Net income (loss)		4,545,000,000	5,322,000,000	(15,845,000,000)
Net income (loss) attributable to ConocoPhillips		4,545,000,000	5,322,000,000	(15,845,000,000)
Comprehensive Income Attributable to ConocoPhillips		$ 4,276,000,000	$ 15,060,000,000	$ (7,982,000,000)
[1]	Net of provision for income taxes on discontinued operations of: $0, $0, $16

Supplementary Information - 127

Supplementary Information - Condensed Consolidating Financial Information Balance Sheet (Details 1) - USD ($) $ in Millions	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Assets
Cash and cash equivalents	$ 3,610	$ 2,368	$ 5,062	$ 6,246
Short-term investments	50
Accounts and notes receivable	3,414	4,514
Inventories	1,018	1,124
Prepaid expenses and other current assets	517	783
Total Current Assets	8,609	8,789
Investments, loans and long-term receivables	21,672	21,186
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $65,321 million in 2013 and $58,916 million in 2012)	58,331	66,446
Other assets	1,160	1,063
Total Assets	89,772	97,484	116,539
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	3,653	4,933
Short-term debt	1,089	1,427
Accrued income and other taxes	484	499
Employee benefit obligations	689	887
Other accruals	994	1,510
Total Current Liabilities	6,909	9,256
Long-term debt	26,186	23,453
Long-term asset retirement obligations and accrued environmental costs	8,425	9,580
Deferred income taxes	8,949	10,999
Employee benefit obligations	2,552	2,286
Other liabilities and deferred credits	1,525	1,828
Total Liabilities	54,546	57,402
Retained earnings	31,548	36,414
Other common stockholders' equity	3,426	3,348
Noncontrolling interests	252	320
Total Liabilities and Equity	89,772	97,484
ConocoPhillips [Member]
Assets
Cash and cash equivalents	0		0	0
Short-term investments	0
Accounts and notes receivable	22	21
Inventories	0	0
Prepaid expenses and other current assets	2	2
Total Current Assets	24	23
Investments, loans and long-term receivables	37,901	43,532
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $65,321 million in 2013 and $58,916 million in 2012)	0	0
Other assets	40	7
Total Assets	37,965	43,562
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	0	0
Short-term debt	(10)	(9)
Accrued income and other taxes	0	0
Employee benefit obligations	0	0
Other accruals	171	170
Total Current Liabilities	161	161
Long-term debt	8,975	7,518
Long-term asset retirement obligations and accrued environmental costs	0
Deferred income taxes	0
Employee benefit obligations	0
Other liabilities and deferred credits	417	2,681
Total Liabilities	9,553	10,360
Retained earnings	25,025	29,892
Other common stockholders' equity	3,387	3,310
Noncontrolling interests	0	0
Total Liabilities and Equity	37,965	43,562
ConocoPhillips Company [Member]
Assets
Cash and cash equivalents	358	4	770	2,434
Short-term investments	0
Accounts and notes receivable	1,968	2,905
Inventories	84	142
Prepaid expenses and other current assets	116	206
Total Current Assets	2,526	3,257
Investments, loans and long-term receivables	64,434	64,015
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $65,321 million in 2013 and $58,916 million in 2012)	6,301	8,110
Other assets	2,194	950
Total Assets	75,455	76,332
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	4,683	5,684
Short-term debt	999	1
Accrued income and other taxes	85	62
Employee benefit obligations	489	629
Other accruals	271	465
Total Current Liabilities	6,527	6,841
Long-term debt	12,635	10,660
Long-term asset retirement obligations and accrued environmental costs	925	1,107
Deferred income taxes	0	0
Employee benefit obligations	1,901	1,760
Other liabilities and deferred credits	10,391	7,291
Total Liabilities	32,379	27,659
Retained earnings	14,015	17,366
Other common stockholders' equity	29,061	31,307
Noncontrolling interests	0	0
Total Liabilities and Equity	75,455	76,332
ConocoPhillips Canada Funding Company I [Member]
Assets
Cash and cash equivalents	13	15	7	229
Accounts and notes receivable	23	21
Inventories	0
Prepaid expenses and other current assets	8	252
Total Current Assets	44	288
Investments, loans and long-term receivables	2,296	3,264
Other assets	220	233
Total Assets	2,560	3,785
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	1	13
Short-term debt	6	1,255
Other accruals	40	52
Total Current Liabilities	47	1,320
Long-term debt	1,710	1,716
Deferred income taxes		0
Other liabilities and deferred credits	748	667
Total Liabilities	2,505	3,703
Retained earnings	(541)	(389)
Other common stockholders' equity	596	471
Total Liabilities and Equity	2,560	3,785
All Other Subsidiaries [Member]
Assets
Cash and cash equivalents	3,239	2,349	$ 4,285	$ 3,583
Short-term investments	50	0
Accounts and notes receivable	6,103	7,228
Inventories	934	982
Prepaid expenses and other current assets	415	589
Total Current Assets	10,741	11,148
Investments, loans and long-term receivables	31,643	27,839
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $65,321 million in 2013 and $58,916 million in 2012)	52,030	58,336
Other assets	1,240	1,158
Total Assets	95,654	98,481
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	3,671	4,897
Short-term debt	94	180
Accrued income and other taxes	399	437
Employee benefit obligations	200	258
Other accruals	536	1,087
Total Current Liabilities	4,900	6,859
Long-term debt	2,866	3,559
Long-term asset retirement obligations and accrued environmental costs	7,500	8,473
Deferred income taxes	10,972	11,814
Employee benefit obligations	651	526
Other liabilities and deferred credits	17,832	15,181
Total Liabilities	44,721	46,412
Retained earnings	12,883	15,177
Other common stockholders' equity	37,798	36,572
Noncontrolling interests	252	320
Total Liabilities and Equity	95,654	98,481
Consolidating Adjustments [Member]
Assets
Accounts and notes receivable	(4,702)	(5,661)
Prepaid expenses and other current assets	(24)	(266)
Total Current Assets	(4,726)	(5,927)
Investments, loans and long-term receivables	(114,602)	(117,464)
Other assets	(2,534)	(1,285)
Total Assets	(121,862)	(124,676)
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable	(4,702)	(5,661)
Accrued income and other taxes	0	0
Other accruals	(24)	(264)
Total Current Liabilities	(4,726)	(5,925)
Deferred income taxes	(2,023)	(815)
Other liabilities and deferred credits	(27,863)	(23,992)
Total Liabilities	(34,612)	(30,732)
Retained earnings	(19,834)	(25,632)
Other common stockholders' equity	(67,416)	(68,312)
Total Liabilities and Equity	$ (121,862)	$ (124,676)

Supplementary Information - 128

Supplementary Information - Condensed Consolidating Financial Information Balance Sheet (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Condensed Financial Statements, Captions [Line Items]
Repayment of Debt	$ 2,251	$ 103	$ 2,014
Conocophillips [Member]
Condensed Financial Statements, Captions [Line Items]
Intercompany return of capital			(17,000)
Intercompany other liabilities	2,300	3,500	34,500
Intercompany Investment	(2,300)	(3,500)	(17,500)
Conocophillips Company [Member]
Condensed Financial Statements, Captions [Line Items]
Intercompany return of capital	2,300	3,500	17,000
Intercompany distribution of earnings			17,500
Intercompany other liabilities	(2,300)	$ (3,500)	(34,500)
Subsidiaries Company Two [Member]
Condensed Financial Statements, Captions [Line Items]
Repayment of Debt	$ 1,250		$ 0

Supplementary Information - 129

Supplementary Information - Condensed Consolidating Financial Information Cash Flow (Details 2) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities	$ 4,403	$ 7,572	$ 16,412
Net cash provided by (used in) discontinued operations	0	0	157
Net Cash Provided by (Used in) Operating Activities	4,403	7,572	16,569
Cash Flows From Investing Activities
Capital expenditures and investments	(4,869)	(10,050)	(17,085)
Working capital changes associated with investing activities	(331)	(968)	180
Proceeds from asset dispositions	1,286	1,952	1,603
Net sales (purchases) of short-term investments	(51)	0	253
Collection of advances/loans-related parties	108	105	603
Other	(2)	306	(446)
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	(3,859)	(8,655)	(14,892)
Net cash provided by (used in) discontinued operations	0	0	(73)
Net Cash Provided by (Used in) Investing Activities	(3,859)	(8,655)	(14,965)
Cash Flows From Financing Activities
Issuance of debt	4,594	2,498	2,994
Repayment of debt	(2,251)	(103)	(2,014)
Change in restricted cash	0	0	0
Issuance of company common stock	(63)	(82)	35
Repurchase of company common stock	(126)
Dividends paid	(1,253)	(3,664)	(3,525)
Other	(137)	(78)	(64)
Net cash provided by (used in) continuing financing activities	764	(1,429)	(2,574)
Net cash provided by (used in) discontinued operations	0	0	0
Net Cash Provided by (Used in) Financing Activities	764	(1,429)	(2,574)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	(66)	(182)	(214)
Net Change in Cash and Cash Equivalents	1,242	(2,694)	(1,184)
Cash and cash equivalents at beginning of period	2,368	5,062	6,246
Cash and Cash Equivalents at End of Period	3,610	2,368	5,062
ConocoPhillips [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities	(306)	(225)	17,259
Net cash provided by (used in) discontinued operations		0
Net Cash Provided by (Used in) Operating Activities	(306)	(225)	17,259
Cash Flows From Investing Activities
Capital expenditures and investments		0
Working capital changes associated with investing activities		0
Proceeds from asset dispositions	2,300	3,500	16,912
Net sales (purchases) of short-term investments		0
Long-term advances/loans-related parties		0
Collection of advances/loans-related parties		0
Intercompany Cash Management	(2,214)	102	(29,113)
Other		0
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	86	3,602	(12,201)
Net cash provided by (used in) discontinued operations		0	0
Net Cash Provided by (Used in) Investing Activities	86	3,602	(12,201)
Cash Flows From Financing Activities
Issuance of debt	1,600	0
Repayment of debt	(150)	0	(1,909)
Change in restricted cash			0
Issuance of company common stock	148	283	377
Repurchase of company common stock	(126)
Dividends paid	(1,253)	(3,664)	(3,525)
Other	1	4	(1)
Net cash provided by (used in) continuing financing activities		(3,377)	(5,058)
Net cash provided by (used in) discontinued operations		0
Net Cash Provided by (Used in) Financing Activities	220	(3,377)	(5,058)
Net Change in Cash and Cash Equivalents	0		0
Cash and cash equivalents at beginning of period		0	0
Cash and Cash Equivalents at End of Period	0		0
ConocoPhillips Company [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities	(322)	245	2,948
Net cash provided by (used in) discontinued operations	0	0	202
Net Cash Provided by (Used in) Operating Activities	(322)	245	3,150
Cash Flows From Investing Activities
Capital expenditures and investments	(989)	(3,064)	(6,507)
Working capital changes associated with investing activities	(126)	(4)	17
Proceeds from asset dispositions	266	826	1,588
Net sales (purchases) of short-term investments	0	0
Long-term advances/loans-related parties	(812)	(278)	(736)
Collection of advances/loans-related parties	391	0	593
Intercompany Cash Management	1,433	46	31,993
Other	1	304	(415)
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	164	(2,170)	26,533
Net cash provided by (used in) discontinued operations	0	0	133
Net Cash Provided by (Used in) Investing Activities	164	(2,170)	26,666
Cash Flows From Financing Activities
Issuance of debt	2,994	4,743	2,994
Repayment of debt	(164)	(100)	(16)
Issuance of company common stock		0
Dividends paid	0	0	(17,588)
Other	(2,315)	(3,484)	(16,870)
Net cash provided by (used in) continuing financing activities		1,159	(31,480)
Net cash provided by (used in) discontinued operations	515	0	0
Net Cash Provided by (Used in) Financing Activities	515	1,159	(31,480)
Effect of Exchange Rate Changes on Cash and Cash Equivalents	(3)		0
Net Change in Cash and Cash Equivalents	354	(766)	(1,664)
Cash and cash equivalents at beginning of period	4	770	2,434
Cash and Cash Equivalents at End of Period	358	4	770
ConocoPhillips Australia Funding Company [Member]
Cash Flows From Financing Activities
Dividends paid			0
Net cash provided by (used in) continuing financing activities			0
Net cash provided by (used in) discontinued operations			0
Net Cash Provided by (Used in) Financing Activities			0
ConocoPhillips Canada Funding Company I [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities	(2)	9	27
Net Cash Provided by (Used in) Operating Activities	(2)	9	27
Cash Flows From Investing Activities
Long-term advances/loans-related parties	0	0	(241)
Collection of advances/loans-related parties	1,250	0	0
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	1,250	0	(241)
Net Cash Provided by (Used in) Investing Activities	1,250	0	(241)
Cash Flows From Financing Activities
Issuance of debt			0
Repayment of debt	(1,250)		0
Net cash provided by (used in) continuing financing activities			0
Net Cash Provided by (Used in) Financing Activities			0
Effect of Exchange Rate Changes on Cash and Cash Equivalents	0	(1)	(8)
Net Change in Cash and Cash Equivalents	(2)	8	(222)
Cash and cash equivalents at beginning of period	15	7	229
Cash and Cash Equivalents at End of Period	13	15	7
All Other Subsidiaries [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities	5,903	7,519	16,941
Net cash provided by (used in) discontinued operations	0	0	408
Net Cash Provided by (Used in) Operating Activities	5,903	7,519	17,349
Cash Flows From Investing Activities
Capital expenditures and investments	(4,281)	(8,386)	(14,840)
Working capital changes associated with investing activities	(205)	(964)	163
Proceeds from asset dispositions	1,114	1,225	253
Net sales (purchases) of short-term investments	(51)	0	253
Long-term advances/loans-related parties	0	(2,245)	(7)
Collection of advances/loans-related parties	272	205	112
Intercompany Cash Management	781	(148)	(2,880)
Other	(3)	1	(31)
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	(2,373)	(10,312)	(16,977)
Net cash provided by (used in) discontinued operations	0	0	(73)
Net Cash Provided by (Used in) Investing Activities	(2,373)	(10,312)	(17,050)
Cash Flows From Financing Activities
Issuance of debt	812	278	984
Repayment of debt	(2,492)	(103)	(191)
Issuance of company common stock		(2)
Dividends paid	(1,081)	(339)	(3,768)
Other	184	1,204	3,919
Net cash provided by (used in) continuing financing activities		1,038	944
Net cash provided by (used in) discontinued operations	(2,577)	0	(335)
Net Cash Provided by (Used in) Financing Activities	(2,577)	1,038	609
Effect of Exchange Rate Changes on Cash and Cash Equivalents	(63)	(181)	(206)
Net Change in Cash and Cash Equivalents	890	(1,936)	702
Cash and cash equivalents at beginning of period	2,349	4,285	3,583
Cash and Cash Equivalents at End of Period	3,239	2,349	4,285
Consolidating Adjustments [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities	(870)	24	(20,763)
Net cash provided by (used in) discontinued operations	0	0	(453)
Net Cash Provided by (Used in) Operating Activities	(870)	24	(21,216)
Cash Flows From Investing Activities
Capital expenditures and investments	401	1,400	4,262
Proceeds from asset dispositions	(2,394)	(3,599)	(17,150)
Long-term advances/loans-related parties	812	2,523	984
Collection of advances/loans-related parties	(1,805)	(100)	(102)
Other	0	1
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	(2,986)	225	(12,006)
Net cash provided by (used in) discontinued operations	0	0	(133)
Net Cash Provided by (Used in) Investing Activities	(2,986)	225	(12,139)
Cash Flows From Financing Activities
Issuance of debt	(812)	(2,523)	(984)
Repayment of debt	1,805	100	102
Issuance of company common stock	(211)	(363)	(342)
Dividends paid	1,081	339	21,356
Other	1,993	2,198	12,888
Net cash provided by (used in) continuing financing activities		(249)	33,020
Net cash provided by (used in) discontinued operations	3,856	0	335
Net Cash Provided by (Used in) Financing Activities	$ 3,856	$ (249)	$ 33,355

Schedule ll (Details)

Schedule ll (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Allowance for Doubtful Accounts [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at January 1		$ 7	$ 5	$ 8
Charged to Expense		3	4	0
Other	[1]	(1)	(2)	(2)
Deductions	[2]	(4)	0	(1)
Balance at December 31		5	7	5
Valuation Allowance of Deferred Tax Assets [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at January 1		734	970	969
Charged to Expense		(31)	6	127
Other	[1]	(12)	(21)	(26)
Deductions		(16)	(221)	(100)
Balance at December 31		675	734	970
Business Restructuring Reserves [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at January 1		156	61	19
Charged to Expense		129	303	71
Other	[1]	1	(8)	(6)
Deductions	[3]	(206)	(200)	(23)
Balance at December 31		$ 80	$ 156	$ 61
[1]	Represents acquisitions/dispositions/revisions and the effect of translating foreign financial statements.
[2]	Amounts charged off less recoveries of amounts previously charged off.
[3]	Benefit payments.