ConocoPhillips (COP) 10-K 23 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2015	Jan. 31, 2016
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, 2015
Amendment Flag	false
Document Fiscal Year Focus	2,015
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	$ 75.7
Entity Common Stock, Shares Outstanding		1,236,202,726
Trading Symbol	COP

Consolidated Income Statement

Consolidated Income Statement - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues and Other Income
Sales and other operating revenues		$ 29,564	$ 52,524	$ 54,413
Equity in earnings of affiliates		655	2,529	2,219
Gain on dispositions		591	98	1,242
Other income		125	366	374
Total Revenues and Other Income		30,935	55,517	58,248
Costs and Expenses
Purchased commodities		12,426	22,099	22,643
Production and operating expenses		7,016	8,909	7,238
Selling, general and administrative expenses		953	735	854
Exploration expenses		4,192	2,045	1,232
Depreciation, depletion and amortization		9,113	8,329	7,434
Impairments		2,245	856	529
Taxes other than income taxes		901	2,088	2,884
Accretion on discounted liabilities		483	484	434
Interest and debt expense		920	648	612
Foreign currency transaction (gains) losses		(75)	(66)	(58)
Total Costs and Expenses		38,174	46,127	43,802
Income (loss) from continuing operations before income taxes		(7,239)	9,390	14,446
Provision (benefit) for income taxes		(2,868)	3,583	6,409
Income (Loss) From Continuing Operations		(4,371)	5,807	8,037
Income (loss) from discontinued operations	[1]	0	1,131	1,178
Net income (loss)		(4,371)	6,938	9,215
Less: net income attributable to noncontrolling interests		(57)	(69)	(59)
Net Income (Loss) Attributable to ConocoPhillips		(4,428)	6,869	9,156
Amounts Attributable to ConocoPhillips Common Shareholders:
Income (loss) from continuing operations		(4,428)	5,738	7,978
Income from discontinued operations	[1]	0	1,131	1,178
Net income (loss) attributable to ConocoPhillips		$ (4,428)	$ 6,869	$ 9,156
Basic
Continuing operations		$ (3.58)	$ 4.63	$ 6.47
Discontinued operations		0	0.91	0.96
Net Income (Loss) Attributable to ConocoPhillips Per Share of Common Stock		(3.58)	5.54	7.43
Diluted
Continuing operations		(3.58)	4.6	6.43
Discontinued operations		0	0.91	0.95
Net Income (Loss) Attributable to ConocoPhillips Per Share of Common Stock		(3.58)	5.51	7.38
Dividends Paid Per Share of Common Stock (dollars)		$ 2.94	$ 2.84	$ 2.7
Average Common Shares Outstanding (in thousands)
Basic		1,241,919	1,237,325	1,230,963
Diluted		1,241,919	1,245,863	1,239,803
[1]	Net of provision for income taxes on discontinued operations of: $0, $16, $283

Consolidated Income Statement (

Consolidated Income Statement (Parenthetical) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Consolidated Income Statement [Abstract]
Net of provision for income taxes on discontinued operations of	$ 0	$ 16	$ 283

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Consolidated Statement of Comprehensive Income
Net income (loss)		$ (4,371)	$ 6,938	$ 9,215
Defined benefit plans
Prior service (cost) credit arising during the period		301	(3)	1
Amortization of prior service cost (credit) included in income		(19)	(6)	(5)
Net change		282	(9)	(4)
Net actuarial gain (loss) arising during the period		592	(840)	688
Reclassification adjustment for amortization of prior service credit included in net income (loss)		403	131	294
Net change		995	(709)	982
Nonsponsored plans	[1]	1	0	10
Income taxes on defined benefit plans		(460)	281	(387)
Defined benefit plans, net of tax		818	(437)	601
Foreign currency translation adjustments		(5,199)	(3,539)	(2,705)
Reclassification adjustment for gain included in net income (loss)		0	0	(4)
Income taxes on foreign currency translation adjustments		36	72	23
Foreign currency translation adjustments, net of tax		(5,163)	(3,467)	(2,686)
Hedging activities				0
Hedging activities, net of tax				0
Other comprehensive income (loss), net of tax		(4,345)	(3,904)	(2,085)
Comprehensive income (loss)		(8,716)	3,034	7,130
Less: comprehensive income attributable to noncontrolling interests		(57)	(69)	(59)
Comprehensive Income (Loss) Attributable to ConocoPhillips		$ (8,773)	$ 2,965	$ 7,071
[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, 2015	Dec. 31, 2014
Assets
Cash and cash equivalents		$ 2,368	$ 5,062
Accounts and notes receivable (net of allowance of $7 million in 2015 and $5 million in 2014)		4,314	6,675
Accounts and notes receivable-related parties		200	132
Inventories		1,124	1,331
Prepaid expenses and other current assets		783	1,868
Total Current Assets		8,789	15,068
Investments and long-term receiavables		20,490	24,335
Loans and advances-related parties		696	804
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $70,413 million in 2015 and $70,786 million in 2014)		66,446	75,444
Other assets		1,063	888
Total Assets		97,484	116,539
Liabilities
Accounts payable		4,895	7,982
Accounts payable-related parties		38	44
Short-term debt		1,427	182
Accrued income and other taxes		499	1,051
Employee benefit obligations		887	878
Other accruals		1,510	1,400
Total Current Liabilities		9,256	11,537
Long-term debt		23,453	22,383
Long-term asset retirement obligations and accrued environmental costs		9,580	10,647
Deferred income taxes		10,999	15,070
Employee benefit obligations		2,286	2,964
Other liabilities and deferred credits	[1]	1,828	1,665
Total Liabilities		57,402	64,266
Equity
Common stock (2,500,000,000 shares authorized at $.01 par value)		18	18
Capital in excess of par		46,357	46,071
Treasury stock (at cost: 2015-542,230,673; 2014-542,230,673)		(36,780)	(36,780)
Accumulated other comprehensive income (loss)		(6,247)	(1,902)
Retained earnings		36,414	44,504
Total Common Stockholders' Equity		39,762	51,911
Noncontrolling interests		320	362
Total Equity		40,082	52,273
Total Liabilities and Equity		$ 97,484	$ 116,539
[1]	Includes intercompany loans

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Consolidated Balance Sheet [Abstract]
Allowance for accounts and notes receivable	$ 7	$ 5
Accumulated depreciation, depletion and amortization	$ 70,413	$ 70,786
Common stock, shares authorized	2,500,000,000	2,500,000,000
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares issued	1,778,226,388	1,773,583,368
Treasury stock, shares	542,230,673	542,230,673

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Cash Flows From Operating Activities
Net income (loss)		$ (4,371)	$ 6,938		$ 9,215
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization		9,113	8,329		7,434
Impairments		2,245	856		529
Dry hole costs and leasehold impairments		3,065	1,166	[1]	443	[1]
Accretion on discounted liabilities		483	484		434
Deferred taxes		(2,772)	709	[1]	1,311	[1]
Undistributed equity earnings		101	77	[1]	(822)	[1]
Gain on dispositions		(591)	(98)		(1,242)
Income from discontinued operations	[2]	0	(1,131)		(1,178)
Other		321	(233)	[1]	(371)	[1]
Working capital adjustments
Decrease (increase) in accounts and notes receivable		1,810	1,227	[1]	744	[1]
Decrease (increase) in inventories		166	(193)	[1]	(278)	[1]
Decrease (increase) in prepaid expenses and other current assets		239	(190)	[1]	(83)	[1]
Increase (decrease) in accounts payable		(1,647)	(963)	[1]	238	[1]
Increase (decrease) in taxes and other accruals		(590)	(566)	[1]	(518)	[1]
Net cash provided by continuing operating activities		7,572	16,412	[1]	15,856	[1]
Net cash provided by discontinued operations		0	157	[1]	285	[1]
Net Cash Provided by Operating Activities		7,572	16,569	[1]	16,141	[1]
Cash Flows From Investing Activities
Capital expenditures and investments		(10,050)	(17,085)	[1]	(15,537)	[1]
Working capital changes associated with investing activities		(968)	180	[1]	(55)	[1]
Proceeds from asset dispositions		1,952	1,603	[1]	10,220	[1]
Net sales (purchases) of short-term investments		0	253	[1]	(263)	[1]
Collection of advances/loans-related parties		105	603	[1]	145	[1]
Other		306	(446)	[1]	(212)	[1]
Net cash used in continuing investing activities		(8,655)	(14,892)	[1]	(5,702)	[1]
Net cash provided by (used in) discontinued operations		0	(73)	[1]	(603)	[1]
Net Cash Provided by (Used in) Investing Activities		(8,655)	(14,965)	[1]	(6,305)	[1]
Cash Flows From Financing Activities
Issuance of debt		2,498	2,994	[1]	0	[1]
Repayment of debt		(103)	(2,014)	[1]	(946)	[1]
Change in restricted cash		0	0	[1]	748	[1]
Issuance of company common stock		(82)	35	[1]	20	[1]
Dividends paid on company common stock		(3,664)	(3,525)	[1]	(3,334)	[1]
Other		(78)	(64)	[1]	(3,621)	[1]
Net cash used in continuing financing activities		(1,429)	(2,574)	[1]	(7,133)	[1]
Net cash used in discontinued operations		0	0	[1]	0	[1]
Net Cash Used in Financing Activities		(1,429)	(2,574)	[1]	(7,133)	[1]
Effect of Exchange Rate Changes on Cash and Cash Equivalents		(182)	(214)	[1]	(75)	[1]
Net Change in Cash and Cash Equivalents		(2,694)	(1,184)	[1]	2,628	[1]
Cash and cash equivalents at beginning of period		5,062	6,246	[1]	3,618	[1]
Cash and Cash Equivalents at End of Period		$ 2,368	$ 5,062		$ 6,246	[1]
[1]	*Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to Consolidated Financial Statements.
[2]	Net of provision for income taxes on discontinued operations of: $0, $16, $283

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, 2012	$ 48,427		$ 18	$ 45,324	$ (36,780)	$ 4,087	$ 35,338	$ 440
Net income (loss)	9,215						9,156	59
Other comprehensive income (loss)	(2,085)					(2,085)
Dividends paid on company common stock	(3,334)	[1]					(3,334)
Distributions to noncontrolling interests and other	(97)							(97)
Distributed under benefit plans	366			366
Ending 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 on company common stock	(3,525)	[1]					(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 on company common stock	(3,664)						(3,664)
Distributions to noncontrolling interests and other	(100)							(100)
Distributed under benefit plans	286			286
Recognition of unearned compensation	0
Other	3						2	1
Ending Balance at Dec. 31, 2015	$ 40,082		$ 18	$ 46,357	$ (36,780)	$ (6,247)	$ 36,414	$ 320
[1]	*Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to Consolidated Financial Statements.

Accounting Policies

Accounting Policies	12 Months Ended
	Dec. 31, 2015
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. Effective November 1, 2015, the Other International and historically presented Europe segments were restructured to align with changes to our intern al organization structure. The Libya business was moved from the Other International segment to the historically presented Europe segment, which is now renamed Europe and North Africa. Certain financial information has been revised for all prior periods presented to reflect the change in the composition of our operating segments. For additional information, see Note 24 —Segment Disclosures and Related Information. Unless indicated otherwise, the information in the Notes to the Consolidated Financial S tatements 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 preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosures of contingent assets and liabilities. Actual results could differ from these estimates. Revenue Recognition— Revenues associated with sales of crude oil, bitumen, natural gas, liquefied natural gas (LNG), natural gas liquids and other items are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry. Revenues associated with producing proper ties in which we have an interest with other producers are recognized based on the actual volumes we sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be nonrecover able 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 line) . Shipping and Handling Costs— We in clude 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 customers are recorded as a component of revenue. Cash Equivalents— Cash equivalents are highly liquid, short-term investments that are readily convertible to known amounts of cash and have original maturities of 90 days or less from their date of purchase. They are carried at cost plus accrued interest, which approximates fair value. Short-Term Investments —Investments in bank time deposits and marketable securities (commercial paper and government obligations) with original maturities of greater than 90 days but less than one year are classified as short-term investments. Inventories— We have several valuation methods for our various types of 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 match current inventory costs with curr ent 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 miscella neous 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— We categorize a ssets and liabilities measured at fair value 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 inpu ts are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting significan t modifications to observable related market data or our assumptions about pricing by market participants. Derivative Instruments— Deriva tive 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 netted against derivative assets and derivative liabilities, respectively. Recognition and classification of the gain or loss that results from recording and adjusting a derivative to fair value depends on the purpose for issuing or holding t he derivative. Gains 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 it s 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 devel opment 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. Explo ratory 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 econo mically recoverable reserves 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 capit alized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For complex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on t he balance sheet for several years while we perform additional appraisal drilling and seismic work on the potential oil and gas field or while we seek government or co-venturer approval of development plans or seek environmental permitting. Once all requi red approvals and permits 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 pre-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 deprec iation 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 indep endent 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 det ermined 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 avail able, 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 res erves exist, an appropriate risk-adjusted amount of these reserves may be included in the impairment calculation. Impairment of Investments in Nonconsolidated Entities — Investments in nonconsolidated entities are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred and annually following updates to corporate planning assumptions. When such a condition is judgmentally determined to be other than temporary, the carrying value of the investment is writte n down to fair value. The fair value of the impaired investment is based on quoted market prices, if available, or upon the present value of expected future cash flows using discount rates believed to be consistent with those used by principal market part icipants, plus market analysis of comparable assets owned by the investee, if appropriate. Maintenance and Repairs— C osts of ma intenance and repairs, which are not significant improvements, are expensed when incurred. Property Dispositions— When complete uni ts 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 depreciable 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) 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 their receipt is probable and estimable. G uarantees— 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 essential ly 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 gu arantee. Share -Based Compensation— We recognize share -based compensation expense over the shorter of the service period (i.e., the stated period of time required to earn the award) or the period beginning at the start 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 liabilities, except for deferred taxes on income and temporary differences related to the cumula tive translation adjustment considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures. Allowable tax credits are applied currently as reductions of the provision for income taxes. Interest related to unr ecognized 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, including unallocated shar es held by the stock savings feature of the ConocoPhillips Savings Plan. 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 equivalen ts 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 unexercised stock options, but on ly 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 and shares held by grantor trusts are excluded from the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the participating securities is immateri al.

Change in Accounting Principles

Change in Accounting Principles	12 Months Ended
	Dec. 31, 2015
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
Changes in Accounting Principles [Text Block]	Note 2 —Changes in Accounting Principles We adopted the provisions of Financial Accounting Standards Board (FASB) Accounting Standards Update (ASU) No. 2014-08, “Reporting Discontinued Operations and Disclosures of Disposals of Components of an Entity,” on a prospective basis, beginning January 1, 2015. The ASU amends the criteria for reporting discontinued operations to include only disposals representing a strategic shift in operations that have or will have a major effect on an entity’s opera tions and financial results. The ASU also requires entities to provide additional disclosures about discontinued operations as well as certain other significant disposal transactions that do not meet the revised discontinued operations reporting criteria. The adoption of this ASU did not have a material impact on our consolidated financial statements and disclosures. See Note 3 — Discontinued Operations, and Note 6 — Assets Held for Sale or Sold, for additional information on our dispositions. Effective December 31, 2015 , we early adopted, on a prospective basis, F ASB ASU No. 2015-17, “Balance Sheet Classification of Deferred Taxes.” Th e ASU requires all deferred tax assets and liabilities, along with any related valuation allowances, to be of fset and presented as a single noncurrent amount in a classified balance sheet for each tax-paying component within a tax jurisdiction. See Note 19 —Income Taxes, for additional information.

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2015
Discontinued Operations [Abstract]
Discontinued Operations Disclosure [Text Block]	Note 3 —Discontinued Operations In 2012 , we agreed to sell our interest in the North Caspian Sea Production Sharing Agreement ( Kashagan ) and our Nigeria and Algeria businesses (collectively, the “Disposition Group”). The Disposition Group was previously part of the Other International operating segment. We completed the sales of Kashagan and our Algeria business in the fourth quarter of 2013. We sold our Nigeria business in the third quarter of 2014. On November 26 , 2012, we notified government authorities in Kazakhstan and co- venturers of our intent to sell the company’s 8.4 percent interest in Kashagan to ONGC Videsh Limited (OVL). On July 2, 2013, we received notification from the government of Kaz akhstan indicating it was exercising its right to pre-empt the proposed sale to OVL and designating KazMunayGas (KMG) as the entity to acquire the interest. On October 31, 2013, we completed the transaction with KMG for total proceeds of $ 5,392 million and recognized a pre-tax gain of $ 22 million, which is included in the “Income from discontinued operations” line on our consolidated income statement. At the time of disposition, the carrying value of the net assets related to our in terest in Kashagan was $ 5,370 million, which included $ 212 million of other current assets, $ 239 million of long-term receivables, $ 5,149 million of PP&E, $ 144 million of other current liabilities, and $ 86 million of asset retirement obligations (ARO). On December 18, 2012, we entered into an agreement with Pertamina to sell our wholly owned subsidiary, ConocoPhillips Algeria Ltd . On November 27, 2013 , we completed the transaction with Pertamina , resulting in proceeds of $ 1,652 million. We recognized a pre-tax gain of $ 938 million, which is included in the “Income from discontinued operations” line on our consolidated income statement. At the time of disposition, t h e net carrying value of our Algerian assets was $ 714 million , which included $ 48 million of other current assets, $ 883 million of PP&E, $ 41 million of other current liabilities, $ 37 million of ARO, and $ 139 million of deferred taxes. On December 20, 2012, we entered into agreements with affiliates of Oando PLC to sell our Nigeria business and on 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 flow s. 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 discontinu ed operations” line on our consolidated income statement. At the time of disposition, the net carrying value of the upstream assets was $ 307 million, which included $ 233 million of other current assets, $ 1,211 million of PP&E, $ 298 million of other current liabilities, $ 14 million of ARO, and $ 825 million of deferred taxes. Sales and other operating revenues and income from discontinued operations related to the Disposition Group during 2014 and 2013 were as follows: Millions of Dollars 2014 2013 Sales and other operating revenues from discontinued operations $ 480 1,185 Income from discontinued operations before-tax $ 1,147 1,461 Income tax expense 16 283 Income from discontinued operations $ 1,131 1,178

Variable Interest Entities (VIE

Variable Interest Entities (VIEs)	12 Months Ended
	Dec. 31, 2015
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 VIE 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 no t the primary beneficiary of APLNG because we share with Origin Energy and China Petrochemical Corporation (Sinopec) the power to direct the key activities of APLNG that most significantly impact its economic performance, which involve activities relate d to the production and commercialization of coalbed methane, as well as LNG processing and export marketing. As a result, we do not consolidate APLNG, and it is accounted for as an equity method investment. As of December 31, 2015 , we have not provided any financial support to APLNG other than amounts previously contractually required. Unless 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.

Inventories

Inventories	12 Months Ended
	Dec. 31, 2015
Inventories [Abstract]
Inventories	Note 5 —Inventories Inventories at December 31 were: Millions of Dollars 2015 2014 Crude oil and natural gas $ 406 538 Materials and supplies 718 793 $ 1,124 1,331 As a result of further declining commodity prices in the fourth quarter of 2015 , we recorded a lower of cost or market adjustment of $ 44 million to our commodity inventories, which is included in the “Purchased commodities” line on our consolidated income statement. Inventories valued on the LIFO basis totaled $ 317 million and $ 440 million at December 31, 2015 and 2014 , respectively. The estimated excess of current replacement cost over LIFO cost of inventories was approximately $ 6 million at both December 31, 2015 and December 31, 2014 . In 2015 , liquidation of LIFO inventory values increased the net loss from continuing operations by $ 25 million.

Assets Held for Sale or Sold

Assets Held for Sale or Sold	12 Months Ended
	Dec. 31, 2015
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 Held for Sale On February 4 , 2016, we entered into a definitive agreement to sell our interest in the Alaska Beluga River Unit natural gas field in the Cook Inlet. The transaction is expected to close in the second quarter of 2016. Assets Sold All gains or losses are reported before-tax and are included net in the “ Gain on dispositions” li ne on our consolidated income statement. 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 dispos ition, 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 Northern 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 millio n 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 milli on 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 carry ing value of our interest, which was included in the Lower 48 segment, was $ 8 million, which primarily included $ 24 million 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. At the time of the disposition, the carrying value of our equity method investment in Polar Lights Company, which was included in our Other International segment, was approximately $ 40 million. 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. 2013 In March 2013, we sold the majority of our producing zones in the Cedar Creek Anticline for $ 994 m illion and recognized a loss on disposition of $ 43 million . At the time of the disposition, the carrying value of our interest, which was included in the Lower 48 segment, was $ 1,037 million, which included primarily $ 1,066 million of PP&E and $ 28 million of ARO. In June 2013, we sold a portion of our working interests in the Browse and Canning basins for $ 402 million. Because we retain a working interest in the unproved properties, proceeds were treated as a reduction of the carrying value of PP&E with no g ain or loss on disposition recognized. Prior to the partial disposition, the carrying value of the PP&E associated with our interests, included in our Asia Pacific and Middle East segment, was $ 486 million. In August 2013, we sold our interest in the Clyden undeveloped oil sands leasehold for $ 724 million and recognized a gain on disposition of $ 614 million. At the time of the disposition, the carrying value of our interest in Clyden , which was included in the Canada segment, was $ 110 million and was primarily classified as PP&E. In August 2013, we also sold our 39 percent interest in Phoenix Park Gas Processors Limited for $ 593 million and recognized a gain on disposition of $ 417 million. At the time of the disposition, the carrying value of our equity investment in Phoenix Park, which was included in our Other International segment, was $ 176 million. For information on the Kashagan and Algeria sales, which are 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, 2015
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 2015 2014 Equity investments $ 19,850 23,426 Loans and advances—related parties 696 804 Long-term receivables 519 444 Other investments 121 465 $ 21,186 25,139 Equity Investments Affiliated companies in which we had a significant equity investment at December 31, 2015 , 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 2015 2014 2013 Revenues $ 11,003 19,243 18,035 Income before income taxes 1,866 6,746 6,384 Net income 1,801 6,630 6,125 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2015 2014 Current assets $ 2,504 4,512 Noncurrent assets 58,431 58,570 Current liabilities 1,863 3,346 Noncurrent liabilities 24,820 20,210 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, 2015 , retained earnings included $ 1,323 million related to the undistributed earnings of affiliated companies. Dividends received from affiliates were $ 876 million , $ 2,648 million and $ 1,425 million in 2015 , 2014 and 2013 , 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 agreements for an $ 8.5 billion project finance facility during the third quarter of 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 Aust ralian and international commercial banks for approximately $ 2.9 billion. At December 31, 2015 , $ 8.4 billion had 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 which will be released upon meeting certain completion milestones. See Note 12 — Guarantees, for additional information. APLNG is considered a VIE, as it has entered into certain contra ctual arrangements that provide it with additional forms of subordinated financial support . See Note 4 — Variable Interest Entities (VIEs) for additional information. During 2015, the outlook for crude oil and natural gas prices sharply deteriorated, and as a result of these significantly reduced price outlooks, the estimated fair value of our investment in APLNG declined to an amount below book value during the fourth quarter of 2015. Based on a review of the facts and circumstances surrounding this decline in fair value, we concluded that the impairment was other than temporary under the guidance of FASB Accounting Standards Codification (ASC) Topic 323, “Investments – Equity Method and Joint Ventures,” and the recognition of an impairment of our in vestment to fair value was necessary. In reaching this conclusion, we primarily considered the severity of the current decline of commodity prices as well as the market outlook. Fair value has been estimated based on an internal discounted cash flow mode l using estimates of future production, prices from futures exchanges and pricing service companies , costs , foreign currency rates and a discount factor that is believed to be consistent with those used by principal market participants. Accordingly, we recorded a noncash $ 1,502 million, before- and after-tax impairment, in our fourth-quarter 2015 results. The impairment , which is included in the “Impairments” line on our consolidated income statement, had the effect of reducing our book valu e to $ 10,185 million, based on the present value of discounted expected future cash flows as of December 31, 2015. At December 31, 2015 , the book value of our equity method investment in APLNG was $ 10,185 million, net of a $ 1,522 million reduction due to cumulative foreign currency translation effects. Effective October 1, 2015, in conjunction with APLNG Train 1 achieving first LNG during the fourth quarter , we changed the functional currency of our inves tment in APLNG from Australian d ollar t o U.S. d ollar. Accordingly, we expect the currency translation adjustment associated with our investment balance to r emain unchanged going forward. The historical cost basis of our 37.5 percent share of net asset s on the books of APLNG under U.S. generally accepted accounting principles was $ 7,470 million, resulting in a basis difference of $ 2,715 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 alloc ated in a similar manner. Each 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 amortize the basis difference allocated to that license using the unit-of-production method. Included in net income (loss) attributable to ConocoPhillips for 2015 , 2014 and 2013 was after-tax expense of $ 21 million, $ 24 million and $ 16 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, 2015 , the book value of our investment in FCCL was $ 8,165 million , net of a $ 1,955 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 locate d in the eastern flank of the Athabasca oil sands 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 and is included in the “Other” line in the financing activities section of our consolidated statement of cash flows. Interest accrued at a fixed annual rate of 5.3 percent on the unpaid principal balance. Fifty percent of the quarterly interest payment is reflected as a capital contribution and is included in the “Capital expenditures and investments” line on our consolidated statement of cash flows . 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 consolidated 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 $ 804 million as describ ed below under “Loans and Long-T erm Receivables.” At December 31, 2015 , the book value of our equity method investment in QG3 , excluding the project financing , was $ 808 million. We have terminal and pipeline use agreements with Golden Pass LNG Terminal and affiliated Golden Pass Pipeline near Sabine Pas s, 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. However, currently the LNG from QG3 is being sold to markets outsi de 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 act ivity 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 b alance 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 fo r 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 in 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 fund 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 f rom Freeport LNG to repay the outstanding loan is included in the cash flows from investing activities section. These transactions, plus miscellaneous items, including the disposal of our 50 percent interest in Freeport GP, resulted in a one-tim e 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 has been reduced from 0.9 billion cubic feet per day to 0.4 billion cubic feet per day, until July 1, 2016, at which time it will be reduced to zero. At December 31 , 2015 , significant loans to affiliated companies include $ 804 million in project financing to QG3. We own a 30 percent interest in QG3, for which we use the equity method of accounting. The other participants in the project are affiliates of Qatar Petroleum and Mitsui. QG3 secured project financing of $ 4.0 bil lion in December 2005, consisting of $ 1.3 billion of loans from export credit agencies (ECA), $ 1.5 billion from commercial banks, and $ 1.2 billion from ConocoPhillips. The ConocoPhillips loan facilities have substantially the s ame 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 project participants. Semi-annual repayments began in January 2011 and will extend thro ugh 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, 2015
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 2015, 2014 and 2013: Millions of Dollars 2015 2014 2013 Beginning balance at January 1 $ 1,299 994 1,038 Additions pending the determination of proved reserves 331 478 466 Reclassifications to proved properties (28) (9) (29) Sales of suspended well investment - (57) (481) Charged to dry hole expense (342) (107) - Ending balance at December 31 $ 1,260 1,299 994 * *Includes $57 million of assets that were held for sale in Nigeria. The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2015 2014 2013 Exploratory well costs capitalized for a period of one year or less $ 235 466 437 Exploratory well costs capitalized for a period greater than one year 1,025 833 557 Ending balance $ 1,260 1,299 994 * Number of projects with exploratory well costs capitalized for a period greater than one year 28 30 29 *Includes $57 million of assets that were held for sale in Nigeria. 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, 2015: Millions of Dollars Suspended Since Total 2012–2014 2009–2011 2002–2008 Greater Poseidon—Australia (2) 177 165 12 - Caldita/Barossa—Australia (1) 77 - - 77 FAN—Senegal (1) 117 117 - - Fiord West—Alaska (2) 16 - - 16 Greater Clair—UK (2) 127 113 14 - Kamunsu East—Malaysia (2) 19 19 - - Limbayong—Malaysia (1) 23 23 - - NC 98—Libya (2) 15 11 - 4 NPRA—Alaska (1) 93 70 17 6 Shenandoah—Lower 48 (1) 94 51 43 - SNE—Senegal (1) 23 23 - - Sunrise—Australia (2) 13 - - 13 Surmont 3 and beyond—Canada (1) 89 58 14 17 Tiber—Lower 48 (1) 100 60 40 - Other of $10 million or less each (1)(2) 42 24 2 16 Total $ 1,025 734 142 149 (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 relation 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 the fourth quarter of 2015, we impaired our leasehold cost associated with Blo ck 36 in Angola due to the lack of commerciality of future prospects . We drilled one of our two- well commitment under the Angola Block 36 Production Sharing Contract ( PSC ) and recorded a before -tax charge of $ 93 million for potential future oblig ations . These charges are included in the “Exploration expenses” line on our consolidated inco me statement.

Impairments

Impairments	12 Months Ended
	Dec. 31, 2015
Impairment Of Long Lived Assets [Abstract]
Impairments	Note 9 —Impairments During 2015, 2014 and 2013, we recognized the following before-tax impairment charges: Millions of Dollars 2015 2014 2013 Alaska $ 10 59 3 Lower 48 (2) 208 2 Canada 4 38 216 Europe and North Africa 724 541 301 Asia Pacific and Middle East 1,508 7 3 Corporate 1 3 4 $ 2,245 856 529 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 the second and fourth quarters of 2015, we decided not to pursue further evaluation of our Block 37 and Block 36 leases in Angola, respectively, due to lack of commerciality of wells. Accordin gly, we recorded impairments of $ 116 million in the second quarter of 2015 and $ 377 million in the fourth quarter of 2015 for the associated carrying values of capitalized undeveloped leasehold costs. In the third quarter of 2015, we de cided not to conduct further activity on certain Gulf of Mexico leases , given our strategic plans to reduce deepwater exploration spending, and to relinquish our Palangkaraya PSC in Indonesia. Accordingly, we recorded impairments of $ 240 mil lion and $ 105 million, respectively, for the associated carrying value s of capitalized undeveloped leasehold cost. In the fourth quarter of 2015, we recorded impairments of $ 575 million , $ 159 million and $ 102 million fo r the associated carrying value of capitalized undeveloped leasehold cost in the Chukchi Sea in Alaska; the Gila prospect in deepwater Gulf of Mexico; and the Duvernay, Thornbury , Saleski and Crow Lake areas in Canada , respectively . These impairments were driven by the lack of commerciality of wells, regulatory uncertainty and the expiration of our leases. 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 A mauligak discovery. Accordingly, 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 . 2013 We recorded property impairments of $216 million in our Canada segment, mainly as a result of lower natural gas price assumptions, reduced volume forecasts and higher costs. In Europe, we recorded impairments of $301 million, primarily due to ARO revi sions for properties in the United Kingdom which are nearing the end of their useful lives or have ceased production.

Asset Retirement Obligations an

Asset Retirement Obligations and Accrued Environmental Costs	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Asset retirement obligations $ 9,911 10,939 Accrued environmental costs 258 344 Total asset retirement obligations and accrued environmental costs 10,169 11,283 Asset retirement obligations and accrued environmental costs due within one year* (589) (636) Long-term asset retirement obligations and accrued environmental costs $ 9,580 10,647 *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 2015 and 2014, our overall asset retirement obligation changed as follows: Millions of Dollars 2015 2014 Balance at January 1 $ 10,939 10,076 Accretion of discount 480 479 New obligations 135 368 Changes in estimates of existing obligations 267 1,175 Spending on existing obligations (437) (365) Property dispositions (726) (20) Foreign currency translation (747) (774) Balance at December 31 $ 9,911 10,939 Accrued Environmental Costs Total accrued environmental costs at December 31, 2015 and 2014 , were $ 258 million and $ 344 million, respectively. We had accrued environmental costs of $ 184 million and $ 250 million at December 31, 2015 and 2014 , respectively, related to remediation activities in the United States and Canada. We had also accrued in Corporate and Other $ 57 million and $ 79 million o f environmental c osts associated with sites no longer in operation at December 31, 2015 and 2014 , respectively. In addition, $ 17 million and $ 15 million were included at both December 31, 2015 and 2014 , 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 $ 105 million at December 31, 2015 . The expected future undiscounted payments related to the portion of the accrued environmental costs that have been discounted are: $ 12 million in 2016 , $ 13 million in 2017 , $ 9 million in 2018 , $ 6 million in 2019 , $ 4 million in 2020 , and $ 117 million for all future years after 2020 .

Debt

Debt	12 Months Ended
	Dec. 31, 2015
Debt [Abstract]
Debt	Note 11 —Debt Long-term debt at December 31 was: Millions of Dollars 2015 2014 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 2,250 2,250 6.50% Notes due 2039 500 500 6.00% Notes due 2020 1,000 1,000 5.951% Notes due 2037 645 645 5.95% Notes due 2036 500 500 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 1,250 5.20% Notes due 2018 500 500 4.30% Notes due 2044 750 750 4.15% Notes due 2034 500 500 3.35% Notes due 2024 1,000 1,000 3.35% Notes due 2025 500 - 2.875% Notes due 2021 750 750 2.4% Notes due 2022 1,000 1,000 2.2% Notes due 2020 500 - 1.5% Notes due 2018 750 - 1.05% Notes due 2017 1,000 1,000 Floating rate notes due 2018 at 0.61% – 0.69% during 2015 250 - Floating rate notes due 2022 at 1.18% – 1.26% during 2015 500 - Commercial paper at 0.16% – 0.80% during 2015 and 0.14% – 0.21% during 2014 803 860 Industrial Development Bonds due 2015 through 2038 at 0.01% – 0.13% during 2015 and 0.02% – 0.13% during 2014 18 18 Marine Terminal Revenue Refunding Bonds due 2031 at 0.01% – 0.14% during 2015 and 0.02% – 0.15% during 2014 265 265 Other 24 24 Debt at face value 23,778 21,335 Capitalized leases 818 858 Net unamortized premiums, discounts and debt issuance costs 284 372 Total debt 24,880 22,565 Short-term debt (1,427) (182) Long-term debt $ 23,453 22,383 Maturities of long-term borrowings, inclusive of net unamortized premiums and discounts, in 2016 through 2020 are: $ 1,427 million, $ 1,081 million, $ 1,859 million, $ 3,014 million and $ 1,576 million, respectively. At December 31, 2015 , we classified $ 695 million of short-term debt as long-term debt, based on our ability and intent to refinance the obligation on a long-term basis under our revolving credit facility . In May 2015 , we issued notes consisting of: The $ 750 million of 1.50 % Notes due 2018. The $ 250 million of Floating Rate Notes due 2018 bearing interest at three-month LIBOR, plus 0.33% . The $ 500 million of 2.20 % Notes due 2020. The $ 500 million of Floating Rate Notes due 2022 bearing interest at three-month LIBOR, plus 0.90% . The $ 500 million of 3.35 % Notes due 2025. The net proceeds were used for general corporate purposes. At December 31 2015 , we had a revolving credit facility totaling $ 7.0 billion expiring in June 2019. Our revolving credit facility may be used for direct bank borrowings, 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 adverse change provisions or any covenants requiring maintenance of specified financial ra tios or credit ratings. The facility agreement contains a cross-default provision relating to the failure to pay principal or interest on other debt obligations of $ 200 million or more by ConocoPhillips, or any of its consolidated subsidiaries. Credit facility borrowings may bear interest at a margin above rates offered by certain designated banks in the London interbank market or at a margin above the overnight federal funds rate or prime rates offered by certain designated banks in the United States. The agreement calls for commitment fees on available, but unused, amounts. The agreement also contains early termination rights if our current directors or their approved successors cease to be a majority of the Board of Directors. We have two c ommercial paper programs supported by our $ 7.0 billion revolving credit facility: the ConocoPhillips $ 6.1 billion program, primarily a funding source for short-term working capital needs, and the ConocoPhillips Qatar Funding Lt d. $ 900 m illion program, which is used to fund commitments relating to QG 3 . Commercial paper maturities are generally limited to 90 days. At both December 31, 2015 and 2014 , we had no direct outstanding borrowings under the revolving credit facility , with no letters of credit as of December 31, 2015 and 2014 . In addition, under the ConocoPhillips Qatar Funding Ltd. commercial paper program, there was $ 803 million of co mmercial paper outstanding at December 31, 2015 , compared with $ 860 million at December 31, 2014 . Since we had $ 803 million of commercial paper outstanding and had issued no letters of credit, we had access to $ 6.2 billion in borrowing capacity under our revolving credit facility at December 31, 2015 . 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- ve nturer . 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 agr eed at a later date. The lease has no ongoing purchase options 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 restri ctions concerning dividends, debt or further leasing activities. 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 l ease payments using our pre-tax incremental borrowing rate of 3.58 percent for debt with similar terms. Unitization of the Gumusut development with Brunei was recorded during the fourth quarter of 2014 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 $ 707 million and $ 802 million a s of December 31, 2015 and December 31, 2014 respectively. T he capital lease asset is being depreciated over a period consistent with the estimated proved reserves of Gumusut using the unit-of-production method with the associated depreciation included in the “Depreciation, depletion and amortizatio n” line on our consolidated income statement. As of December 31, 2015 and December 31, 2014 , accumulated depreciation of the capital lease asset amounted to approximately $ 122 million and $ 20 million , respectively . At December 31, 2015, future minimum payments due under capital leases were: Millions of Dollars 2016 $ 91 2017 76 2018 76 2019 76 2020 76 Remaining years 648 Total 1,043 Less: portion representing imputed interest (225) Capital lease obligations $ 818

Guarantees

Guarantees	12 Months Ended
	Dec. 31, 2015
Guarantees [Abstract]
Guarantees	Note 12 —Guarantees At December 31, 2015 , 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 perform ing 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, 2015 , 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 2015 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 $ 110 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 maximum potential amount of future payments under the guarantee is estimated to be $ 3.2 billion, wh ich could be payable if the full debt financing capacity is utilized and completion of the project is not achieved. Our guarantee of the project financing will be released upon meeting certain completion tests with milestones, which we estimate should occ u r beginning in 2016. Our maximum exposure at December 31, 2015 , is $ 3.2 billion based upon our pro-rata share of the facility used at that date. At December 31, 2015 , the carrying value of this guarantee is approximatel y $ 114 million. In conjunction with our original purchase of an ownership interest in APLNG from Origin Energy in October 2008, we agreed to be responsible for our share of a contingent liability arising under guarantees of an existing obligation of APLNG to deliver natural gas under several sales agreements with remaining terms of 1 to 26 years . Our maximum potential amount of future payments, or cost of volume delivery, under these guarantees is estimated to be $ 1 billion ($ 1.8 billion in the event of intent ional or reckless breach) and would become payable if APLNG fails to meet its obligations under these agreements and the obligations cannot otherwise be mitigated. Future payments are considered 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 guaranteed 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 30 years or the life of the venture . Our maximum potential amount of future payments related to these guarantees is approximately $ 160 million an d would become payable if APLNG does not perform. Other Guarantees We have other guarantees with maximum future potential payment amounts totaling approximately $ 590 million, which consist primarily of guarantees of the residual value of a leased office building, the residual value of leased corporate aircraft, a guarantee for our portion of a joint venture’s project finance reserve accounts, a guarantee to fund the short-term cash liquidity deficit of a joint ventur e, an d a guarantee of minimum charter revenue for an LNG vessel. These guarantees have remaining terms of up to eight years or the life of the venture and would become payable if, upon sale, certain asset values are lower than guaranteed amounts, business conditions decline at guaran teed entities, or as a result of nonperformance of contractual terms by guaranteed parties. Indemnifications Over the years, we have entered into agreements to sell ownership interests in certain corporations, joint ventures and assets that gave rise to qualifying indemnifications. These a greements include indemnifications for taxes, environmenta l liabilities, employee claims and litigation. The terms of these indemnifications vary greatly. The majority of these indemnifications are related to environ mental issues, the term is generally indefinite and the maximum amount of future payments is generally unlimited. The carrying amount recorded for these indemnifications at December 31, 2015 , was approximately $ 90 million. We amortiz e the indemnification liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of indemnity. In cases where the indemnification term is indefinite, we will reverse the liability when we have inform ation the liability is essentially relieved or amortize the liability over an appropriate time period as the fair value of our indemnification exposure declines. Although it is reasonably possible future payments may exceed amounts recorded, due to the na ture of the indemnifications, it is not possible to make a reasonable estimate of the maximum potential amount of future payments. Included in the recorded carrying amount at December 31, 2015 , were approximately $ 40 million of environme ntal 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 30, 2012, the separation of our Downstream businesses was completed, creating two independent energy companies: ConocoPhillips and Phillips 66. In connection with the separation, we entered into an Indemnification and Release A greement, which provides for cross-indemnities between Phillips 66 and us and established procedures for handling claims subject to indemnification and related matters. We evaluated the impact of the indemnifications given and the Phillips 66 indemnificat ions received as of the separation date and concluded those fair values were immaterial. On March 1, 2015 , a supplier to one of the refineries that was included in Phillips 66 as part of the separation of our Downstream businesses 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 approximately $ 1.6 billion. At December 31, 2015 , the carrying value of this guarantee is approximately $ 98 million and the remaining term is nine years . Beca use 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 valu e of the guarantee; however, if we are required to perform under the guarantee, we would expect to recover from Phillips 66 any amounts in excess of that value, provided Phillips 66 is a going concern.

Contingencies and Commitments

Contingencies and Commitments	12 Months Ended
	Dec. 31, 2015
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 made 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, 2015 , we had performance obligations secured by letters of credit of $ 340 million (issued as direct bank letters of credit) related to various purchase commitments for 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. A separate arbitration phase is currently proceeding to determine the damages owed to ConocoPhillips for Venezuela’s actions. On October 10, 2014, we filed a separate arbitration under the rules of the International Chamber of Commerce against PDVSA for co ntractual compensation related to the Petrozuata and Hamaca heavy crude oil projects. 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 Burlington 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 supplem ental counterclaim s 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 Blocks 7 and 21 was an unlawful expro priation in violation of the Ecuador-U.S. Bilateral Investment Treaty. An additional arbitration phase is now proceeding to determine the damages owed to ConocoPhillips for Ecuador’s actions and to address Ecuador’s counterclaims . ConocoPhillips served a Notice of Arbitration on the Timor-Leste Minister of Finance in October 2012 for outstanding disputes related to a series of tax assessments. The arbitration hearing was conducted in Singapore in June 2014 under the United Nations Commission on Internati onal Trade Laws (UNCITRAL) arbitration rules, pursuant to the terms of the Tax Stability Agreement with the Timor-Leste government. Post-hearing briefs from both parties were filed in August 2014. In January 2016, the Government of Timor-Leste and ConocoP hillips reached a settlement of several significant tax disputes. However, we await the Tribunal’s decision with respect to certain unresolved matters . Long-Term Throughput Agreements and Take-or-Pay Agreements We have certain throughput agreem ents 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 c ompany’s business. The aggregate amounts of estimated payments un der these various agreements are: 2016 —$ 27 million; 2017 —$ 27 million; 2018 —$ 22 million; 2019 —$ 7 million; 2020 —$ 7 million; and 2021 and after—$ 80 million. Total payments under the agreements were $ 27 million in 2015 and $ 127 million in each of 2014 and 2013 .

Derivative and Financial Instru

Derivative and Financial Instruments	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Assets Prepaid expenses and other current assets $ 768 4,500 Other assets 60 157 Liabilities Other accruals 754 4,426 Other liabilities and deferred credits 46 144 The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars 2015 2014 2013 Sales and other operating revenues $ 231 523 (160) Other income 2 1 4 Purchased commodities (201) (458) 139 The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts: Open Position Long/(Short) 2015 2014 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (14) (11) Basis (17) 18 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 2015 2014 Assets Prepaid expenses and other current assets $ 47 1 Liabilities Other accruals 8 1 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 2015 2014 2013 Foreign currency transaction (gains) losses $ (33) 3 4 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency 2015 2014 Foreign Currency Exchange Derivatives Sell U.S. dollar, buy other currencies* USD 347 7 Buy U.S. dollar, sell other currencies** USD 20 44 Buy British pound, sell other currencies*** GBP 567 20 *Primarily Canadian dollar, Norwegian krone and British pound. **Primarily Canadian dollar and Norwegian krone. ***Primarily Canadian dollar and euro. Financial Instruments We have certain financial instruments with maturities based on our cash forecasts for the various currency pools we manage. The maturities of these investments may from time to time extend beyond 90 days. The types of financial instruments include: Time deposits: Interest bearing deposits placed with approved financial institutions. Money market funds: Short-term securities representing high-quality liquid debt and monetary instruments. Commercial paper: Unsecured promissory not es issued by a corporation, commercial bank, or government agency purchased at a discount, maturing at par. These financial instruments appear in the “Cash and cash equivalents” line of our consolidated balance sheet if the maturities at the time we made the investments were 90 days or less . At December 31, we held the following financial instruments: Millions of Dollars Carrying Amount Cash and Cash Equivalents 2015 2014 Cash $ 528 946 Money market funds - 50 Time deposits Remaining maturities from 1 to 90 days 1,840 3,726 Commercial paper Remaining maturities from 1 to 90 days - 340 $ 2,368 5,062 Credit Risk Financial instruments potentially exposed to concentrations of credit risk consist primarily of cash equivalents, over-the-counter ( OTC ) derivative contracts and trade receivables. Our cash equivalents 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 trans action. 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. We also use futures, swaps and option contracts th at have a negligible credit risk because these trades are cleared with an exchange clearinghouse and subject to mandatory margin requirements until settled; however, we are exposed to the credit risk of those exchange brokers for receivables arising from d aily 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 international customer base, which limits our exposure to con centrations 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 generally require collateral to limit the exposure t o 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 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 fixed threshold amounts and other contracts with vari able threshold amounts that are contingent on our credit rating. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically revert to zero if we fall below investment grade. Ca sh 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 aggregate fair value of all derivative instruments with su ch credit risk-related contingent features that were in a liability position on December 31, 2015 and December 31, 2014 , was $ 158 million and $ 150 million, respectively. For these instruments , $ 2 million of collateral was posted as of December 31, 2015 , and no collateral was posted as of December 31, 2014 . If our credit rating had been lowered one level from its “A” rating (per Standard and Poor’s) on December 31, 2015 , we would be required to post no additional collateral to our counterparties. If we had been downgraded below investment grade, we would be required to post $ 156 million of additional collateral, either with cash or letters of credit.

Fair Value Measurement

Fair Value Measurement	12 Months Ended
	Dec. 31, 2015
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 valuation inputs under the following hierarchy: Level 1: Quoted prices (unadjusted) in an active market for identical assets or liabilities. Level 2: Inputs other than quoted prices that are directly or indirectly obs ervable. Level 3: Unobservable inputs that are significant to the fair value of assets or liabilities. The classification of an asset or liability is based on the lowest level of input significant to its fair value. Those that are initially classified as Level 3 are subsequently reported as Level 2 when the fair value derived from unobservable inputs is inconsequential to the overall fair value, or if corroborated market data becomes available. Assets and liabilities that are initially reported as Level 2 are subsequently reported as Level 3 if corroborated market data is no longer available. Transfers occur at the end of the reporting period. There were no material trans fers in or out of Level 1 during 2015 and 2014 . Recurring Fair Value Measurement Financial assets and liabilities reported at fair value on a recurring basis primarily include commodity derivative s and certain investments to support nonqualified deferred compensation plans. The deferred compensa tion investments are measured at fair value using unadjusted prices available from national securities exchanges; therefore, these assets are categorized as Level 1 in the fair value hierarchy. 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 liabilit ies 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 is not readily available. The derived value use s 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 es timate 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 the right of setoff exists for commodity derivat ives accounted for at fair value on a recurring basis): Millions of Dollars December 31, 2015 December 31, 2014 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Deferred compensation investments $ 21 - - 21 297 - - 297 Commodity derivatives 516 242 70 828 4,221 361 75 4,657 Total assets $ 537 242 70 849 4,518 361 75 4,954 Liabilities Commodity derivatives $ 515 273 12 800 4,200 354 16 4,570 Total liabilities $ 515 273 12 800 4,200 354 16 4,570 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, 2015 Assets $ 828 600 228 - 8 220 Liabilities 800 600 200 1 11 188 December 31, 2014 Assets $ 4,657 4,352 305 8 28 269 Liabilities 4,570 4,352 218 4 22 192 At December 31, 2015 and December 31, 2014, 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 3 Inputs Before-Tax Loss Year ended December 31, 2015 Net PP&E (held for use) $ 440 440 681 Net PP&E (unproved property) 104 104 240 Equity method investments 10,210 10,210 1,507 Year ended December 31, 2014 Net PP&E (held for use) $ 87 87 756 Net PP&E (unproved property) 39 39 158 *Represents the fair value at the time of the impairment. Net PP&E (held for use) Net PP&E held for use is comprised of various producing properties impaired to their individual fair values less costs to sell. The fair values were determined by internal discounted cash flow models using estimates of future production, prices from futures exchanges and pricing service companies, costs , and a discount rate believed to be consistent with those used by principal market participants. Net PP&E (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 equity method investments, primarily our investment in APLNG, were determined to have fair values below their carrying amounts, and the impairments were consid ered to be other than temporary. For additional information, see Note 7 —Investments, Loans and Long-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 : The carrying amount reported on the balance sheet approximates fair value. Accounts and notes receivable (including long-term and related parties): The carrying amount reported on the balance sheet approximates fair value. The valuation technique and methods used to estimate the fair value of the current portion of fixed-rate related party loans is consistent with Loans and advances—related parties. Loans and advances—related parties: The carrying amount of floating-rate loans approximates fair value. The fair value of fixed-rate loan activity is measure d 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 accounts payable and floating-rate debt reported on the balance sheet approximates fair value. Fixed-rate debt: The estimated fair value of fixed-rate debt is measured using prices available from a pricing service that is corroborated by market data; therefore, these liabilities are categorized as Level 2 in the fair value hierarchy. The following table summarizes the net fair value of financial instruments (i.e., adjusted where the right of setoff exists for commodity derivatives): Millions of Dollars Carrying Amount Fair Value 2015 2014 2015 2014 Financial assets Deferred compensation investments $ 21 297 21 297 Commodity derivatives 228 297 228 297 Total loans and advances—related parties 808 913 808 913 Financial liabilities Total debt, excluding capital leases 24,062 21,707 24,785 25,191 Commodity derivatives 199 214 199 214 Deferred compensation investments In May 2015 , we liquidated certain deferred compensation investments for proceeds of $267 million, which is included in the “Other” line within “C ash Flows From Investing Activities” on our consolidated statement of cash flows. Commodity derivatives At December 31, 2015 , commodity derivative assets and liabilities appear net with no obligations to return cash collate ral and $ 1 million of rights to reclaim cash collateral, respectively. At December 31, 2014 , commodity derivative assets an d liabilities appear net of $ 8 million of obligations to return cash collateral and $ 4 million of rights to reclaim cash collateral , respectively.

Equity

Equity	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Issued Beginning of year 1,773,583,368 1,768,169,906 1,762,247,949 Distributed under benefit plans 4,643,020 5,413,462 5,921,957 End of year 1,778,226,388 1,773,583,368 1,768,169,906 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, 2015 or 2014 . Noncontrolling Interests At December 31, 2015 and 2014 , we had $ 320 million and $ 362 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 .

Non Mineral Leases

Non Mineral Leases	12 Months Ended
	Dec. 31, 2015
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, 2015, future minimum rental payments due under noncancelable leases were: Millions of Dollars 2016 $ 671 2017 360 2018 215 2019 156 2020 374 Remaining years 381 Total 2,157 Less: income from subleases (9) Net minimum operating lease payments $ 2,148 Operating lease rental expense for the years ended December 31 was: Millions of Dollars 2015 2014 2013 Total rentals $ 432 474 317 Less: sublease rentals (9) (10) (12) $ 423 464 305

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2015 2014 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 4,387 3,984 3,954 3,583 716 682 Service cost 138 124 124 109 4 3 Interest cost 161 135 165 166 22 29 Plan participant contributions - 5 - 6 21 21 Plan amendments - - - - (303) - Actuarial (gain) loss (212) (442) 477 598 (49) 53 Benefits paid (729) (162) (333) (122) (63) (70) Curtailment 27 (43) - - 8 - Recognition of termination benefits - 68 - - - - Foreign currency exchange rate change - (348) - (356) (4) (2) Benefit obligation at December 31* $ 3,772 3,321 4,387 3,984 352 716 *Accumulated benefit obligation portion of above at 3,573 2,953 3,957 3,111 December 31: $ Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 3,266 3,278 3,092 3,132 - - Actual return on plan assets (4) 96 234 410 - - Company contributions 73 120 273 203 42 49 Plan participant contributions - 5 - 6 21 21 Benefits paid (729) (162) (333) (122) (63) (70) Foreign currency exchange rate change - (274) - (351) - - Fair value of plan assets at December 31 $ 2,606 3,063 3,266 3,278 - - Funded Status $ (1,166) (258) (1,121) (706) (352) (716) Millions of Dollars Pension Benefits Other Benefits 2015 2014 2015 2014 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 175 - 13 - - Current liabilities (99) (34) (26) (9) (45) (49) Noncurrent liabilities (1,067) (399) (1,095) (710) (307) (667) Total recognized $ (1,166) (258) (1,121) (706) (352) (716) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 4.50 % 3.95 3.80 3.55 3.90 4.15 Rate of compensation increase 4.00 4.05 4.75 4.35 - - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 4.00 % 3.55 4.40 4.75 4.05 4.45 Expected return on plan assets 7.00 5.40 7.00 5.75 - - Rate of compensation increase 4.75 4.35 4.75 4.60 - - 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 2015 2014 2015 2014 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial (gain) loss $ 773 273 1,146 852 (18) 25 Unrecognized prior service cost (credit) 9 (30) 16 (43) (292) (4) Millions of Dollars Pension Benefits Other Benefits 2015 2014 2015 2014 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ 61 490 (456) (331) 41 (53) Amortization of (gain) loss included in income (loss)* 312 89 77 57 2 (3) Net change during the period $ 373 579 (379) (274) 43 (56) Prior service credit (cost) arising during the period $ - (2) - (3) 303 - Amortization of prior service cost (credit) included in income (loss) 7 (11) 6 (8) (15) (4) Net change during the period $ 7 (13) 6 (11) 288 (4) *Includes settlement losses recognized in 2015. During the year ended December 31, 2015 , there were amendments to the U.S. other postretirement benefit plan. The benefit obligation decreased by $ 303 million for changes in the plan made to retiree medical benefits. The $ 303 million decrease consists of $ 149 million related to the discontinuation of all company premium cost-sharing contributions to the post-65 retiree medical plan after December 31, 2025, $ 91 million related to updated cost sharing a ssumption 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 p articipants in the post-65 retiree medical plan after December 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 de crease in other comprehensive loss . Included in accumulated other comprehensive income (loss) at December 31, 2015, were the following before- tax amounts that are expected to be amortized into net periodic benefit cost during 2016: Millions of Dollars Pension Other Benefits Benefits U.S. Int’l. Unrecognized net actuarial (gain) loss $ 78 30 (2) Unrecognized prior service cost (credit) 5 (6) (34) For our tax-qualified pension plans with projected benefit obligations in excess of plan assets, the projected benefit obligation, the accumulated benefit obligation, and the fair value of plan assets were $ 5,720 million, $ 5,314 million, and $ 4,759 million, respectively, at December 31, 2015 , and $ 7,584 million, $ 6,503 million, and $ 6,446 million, respectively, at December 31, 2014 . For our unfunded nonqualified key employee supplemental pension plans, the projected benefit obligation and the accumulated benefit obligation were $ 639 million and $ 564 million, respectively, at December 31, 2015 , and were $ 703 million and $ 482 million, respectively, at December 31, 2014 . 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 2015 2014 2013 2015 2014 2013 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 138 124 124 109 138 102 4 3 3 Interest cost 161 135 165 166 143 145 22 29 26 Expected return on plan assets (201) (164) (213) (181) (186) (160) - - - Amortization of prior service cost (credit) 6 (7) 6 (8) 6 (7) (17) (4) (4) Recognized net actuarial loss (gain) 115 82 77 57 151 73 2 (3) 3 Settlements 197 7 - - 67 - - - - Curtailment (gain) loss 35 (4) - - - - 2 - - Net periodic benefit cost $ 451 173 159 143 319 153 13 25 28 We recognized pension settlement losses of $ 204 million in 2015 and $ 67 million in 2013 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 2015 restructuring program, we concluded that actions taken during the year ended December 31, 2015 , resulted in a significant reduction of future services of active employees in the U.S. qualified pension plan, a U.S. nonqualified supplemental retirement plan, certain international qualified and nonqualif ied pension plans, and the U.S. other postretirement benefit plan. As a result, we recognized an increase in the benefit obligation and a proportionate share of prior service cost from other comprehensive income (loss) as curtailment losses of $ 33 million during the year ended December 31, 2015 . Also as part of the 2015 restructuring program in the U.S. and Europe, we recognized expense for special termination benefits of $ 124 million during the year ended December 31, 2015 , consisting of $ 46 million in the U.S. and $ 78 million in Europe (including related social security tax). Approximately 62 percent of the Europe amount is recoverable from joint venture partners. In determining net pension and other postretirement benefit costs, we amortize prior service costs on a straight-line basis over the average remaining service period of employees expected to receive benefits under the plan . For net actuarial gains and losses, we amortize 10 percent of the unamortized balance each year. We have multiple nonpension postretirement benefit plans for health and life insurance. The health care plans are contributory and subject to various cost sharing features, with participant and company contributions adjusted annually; the life insurance plans are noncontributory. The measurement of the U.S. pre-65 retiree medical accumulated postretirement benefit obligation assumes a health care cost trend rate of 6.75 percent in 2016 that declines to 5 percent by 2023 . The measurement of the U.S. post-65 retiree medical accumulated postretirement benefit obligation assumes a health care cost trend rate of 3 percent in 2016 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, investment managers 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 58 percent equity securities, 36 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, 2015 and 2014 . 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. Private equity funds are valued at net asset value as determined by the issuer based on the fair value of the underlying assets. 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, 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. At December 31, 2014 , the participating interest in the annuity contract was valued at $ 116 million and consisted of $ 328 million in debt securities, less $ 212 million for the accumulated benefit obligation covered by the contract. The net change from 2014 to 2015 is due to a decrease in the fair value of the underlying investments of $ 23 million and a decrease in the present value of the contract obligation of $ 32 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 und er 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 2015 Equity Securities U.S. $ 777 3 2 782 609 - - 609 International 485 - - 485 450 - - 450 Common/collective trusts - 569 - 569 - 214 - 214 Mutual funds - - - - 234 106 - 340 Debt Securities Government 85 56 - 141 493 - - 493 Corporate - 331 17 348 - 172 - 172 Agency and mortgage-backed securities - 80 - 80 - 36 - 36 Common/collective trusts - - - - - 406 - 406 Mutual funds - - - - 136 - - 136 Cash and cash equivalents - 60 - 60 46 10 - 56 Derivatives - (7) - (7) (26) - - (26) Real estate - - 63 63 - - 169 169 Total* $ 1,347 1,092 82 2,521 1,942 944 169 3,055 *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. 2014 Equity Securities U.S. $ 1,039 2 8 1,049 628 - - 628 International 671 - - 671 445 - - 445 Common/collective trusts - 542 - 542 - 227 - 227 Mutual funds - - - - 241 97 - 338 Debt Securities Government 132 75 - 207 624 - - 624 Corporate - 426 4 430 - 166 - 166 Agency and mortgage-backed securities - 115 - 115 - 46 1 47 Common/collective trusts - - - - - 396 - 396 Mutual funds - - - - 167 - - 167 Cash and cash equivalents - 67 - 67 50 18 - 68 Private equity funds - - - - - - 1 1 Derivatives 5 (3) - 2 (4) - - (4) Real estate - - 55 55 - - 166 166 Total* $ 1,847 1,224 67 3,138 2,151 950 168 3,269 *Excludes the participating interest in the insurance annuity contract with a net asset value of $116 million and net receivables related to security transactions of $21 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 2016 , we expect to contribute approximately $ 220 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $ 190 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. 2016 $ 414 150 45 2017 347 144 43 2018 335 140 41 2019 335 143 39 2020 338 149 38 2021–2025 1,544 858 158 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 . Severance accruals of $ 306 million were recorded in 2015 . The following table summarizes our severance accrual activity for the year ended December 31, 2015 : Millions of Dollars Balance at December 31, 2014 $ 61 Accruals 306 Accrual reversals (3) Benefit payments (200) Foreign currency translation adjustments (8) Balance at December 31, 2015 $ 156 Of the remaining balance at December 31, 2015 , $ 121 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 35 investment funds. In 2015, employees who participate in the CPSP and contribute 1 percent of their eligible pay receive a 9 percent c om pany cash match, subject to certain limitations. Starting in 2016 , employees who participate in the CPSP and contribute 1 percent of their eligible pay receive a 6 percent company cash match with a potential company discretionary cash contribution of up to 6 percent. Company contributions charged to expense related to continuing and discontinued operations for the CPSP and predecessor plans were $ 103 million in 2015 , $ 116 million in 2014 , and $ 101 million in 2013 . In 1990, the Long-Term Stock Savings Plan of Phillips Petroleum Company ( subsequently the stock savings feature of the CPSP) borrowed funds that were used to purchase previously unissued shares of c ompany common stock. Since the company guaranteed the CPSP’s borrowings, the unpaid balance wa s reported as a liability of the c ompany and unearned compensation wa s shown as a reduction of common stockholders’ equity. Dividends on all shares were charged against retained ear nings. The debt was serviced by the CPSP from c ompany contributions and dividends received on certain shares of common stock held by the plan, including all unallocated shares. The shares held by the stock savings feature of the CPSP were released for al location to participant accounts based on debt service payments on CPSP borrowings. In 2012 , the final debt service payment was made and all remaining unallocated shares were released for allocation to participant accounts. The total number of allocated CPSP stock savings fe ature shares as of December 31, 2015 and 2014 , were 7,243,832 and 8,198,873 , respectively. We have several defined contribution plans for our international employees, each with its own terms and eligibility depending on location. Total compensation expense related to continuing and discontinued operations recognized for these international plans was approximately $ 55 million in 2015 , $ 66 million in 2014 and $ 60 million in 2013 . 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 determine 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. 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. Compensation Expense — Total share-based compensation expense recognized in income (loss) related to continuing and discontinued operations and the associated tax benefit for the years ended December 31 were as follows: Millions of Dollars 2015 2014 2013 Compensation cost $ 362 358 308 Tax benefit 123 125 109 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: 2015 2014 2013 Assumptions used Risk-free interest rate 1.79 % 1.86 1.09 Dividend yield 4.00 % 4.00 4.00 Volatility factor 23.32 % 25.31 28.95 Expected life (years) 5.79 6.12 5.95 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 and 2013 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, 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 businesses) through the stock option grant date and the average his torical 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, 2015: Weighted- Weighted- Average Millions of Dollars Average Grant Date Aggregate Options Exercise Price Fair Value Intrinsic Value Outstanding at December 31, 2014 17,117,871 $ 52.61 $ 284 Granted 3,873,700 69.25 $ 9.54 Exercised (548,707) 42.11 10 Forfeited (258,010) 69.20 Expired or cancelled (44) 23.37 Outstanding at December 31, 2015 20,184,810 $ 55.88 $ 42 Vested at December 31, 2015 16,650,347 $ 53.66 $ 42 Exercisable at December 31, 2015 13,192,751 $ 50.34 $ 42 The weighted-average remaining contractual term of outstanding options, vested options and exercisable options at December 31, 2015 , was 5.84 years , 5.27 years and 4.43 years, respectively . The weighted-average grant date fair value of stock option awards granted during 2014 and 2013 was $ 10.17 and $ 9.90 , respectively. The aggregate intrinsic value of options exercised during 2014 and 2013 was $ 89 million and $ 95 million, respectively. During 2015 , we received $ 23 million in cash and realized a tax benefit related to both continuing and discontinued operations of $ 16 million from the exercise of options. At December 31, 2015 , the remaining unrecognized compensation expense from unvested options was $ 16 million, which will be recognized over a weighted-average period of 1.22 ye ars , 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, 2015: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2014 11,782,856 $ 55.75 Granted 3,455,150 65.40 Forfeited (660,298) 63.11 Issued (5,399,543) $ 316 Outstanding at December 31, 2015 9,178,165 $ 59.80 Not Vested at December 31, 2015 6,289,931 $ 59.87 At December 31, 2015 , the remaining unrecognized compensation cost from the unvested units was $ 155 million, which will be recognized over a weighted-average period of 1.53 years , the longest period being 2.67 years . The weighted - average grant date fair value of stock unit awards granted during 2014 and 2013 was $ 62.72 and $ 57.99 , respectively. The total fair value of stock units issued during 2014 and 2013 was $ 256 million and $ 245 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, 2015: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2014 4,651,244 $ 51.75 Granted 59,807 69.25 Issued (440,829) $ 25 Outstanding at December 31, 2015 4,270,222 $ 51.95 Not Vested at December 31, 2015 702,623 $ 53.90 At December 31, 2015 , the remaining unrecognized compensation cost from unvested stock-settled performance share awards was $ 9 million, which includes $ 2 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 1.76 years, the longest period being 4.99 years. The w eighted-average grant date fair value of stock-settled PSUs granted during 2014 and 2013 was $ 65.46 and $ 60.00 , respectively. The total fair value of stock-settled PSUs issued during both 2014 and 2013 wa s $ 18 million. 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, ab sent employee election to defer, on the earlier of five years after the grant date of the award or the date the employee becomes eligible for retirement. For employees eligible for retirement by or shortly after the grant date, we recognize compensation e xpense over the period beginning on the date of authorization and ending on the date of grant. Otherwise, we recognize compensation expense beginning on the grant date and ending on the date the PSUs are scheduled to vest. These PSUs are settled in cash equal to the fair market value of a share of ConocoPhillips common stock per unit on the settlement dat e and thus are classified as lia bilities on the balance sheet. Until settlement occurs, recipients of the PSUs receive a quarterly cash payment of a div idend 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 recognize compensation expense over the period beginning on the date of authorization and ending on the conclusion of the performance period. These PSUs will be settled in cash equal to the fair market value of a share of ConocoPhillips common stock per unit on the settlement date and are classified as liabilities on the balance sheet. e and thus are classified as lia bilities on the balance sheet. Until settlement occurs, recipients of the PSUs receive a quarterly cash payment of a div idend equivalent that is charged to compensati

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Taxes [Abstract]
Income Taxes	Note 19 —Income Taxes Income taxes charged to income (loss) from continuing operations were: Millions of Dollars 2015 2014 2013 Income Taxes Federal Current $ (718) 188 724 Deferred (1,443) 365 811 Foreign Current 745 2,846 4,249 Deferred (1,315) 252 504 State and local Current 8 46 220 Deferred (145) (114) (99) $ (2,868) 3,583 6,409 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 2015 2014 Deferred Tax Liabilities PP&E and intangibles $ 16,378 20,054 Investment in joint ventures 866 1,013 Inventory 25 51 Deferred state income tax 128 63 Partnership income deferral 44 155 Other 453 509 Total deferred tax liabilities 17,894 21,845 Deferred Tax Assets Benefit plan accruals 1,160 1,552 Asset retirement obligations and accrued environmental costs 4,426 4,971 Deferred state income tax - - Other financial accruals and deferrals 616 552 Loss and credit carryforwards 1,579 1,568 Other 134 329 Total deferred tax assets 7,915 8,972 Less: valuation allowance (734) (970) Net deferred tax assets 7,181 8,002 Net deferred tax liabilities $ 10,713 13,843 Effective December 31, 2015 , we early adopted, on a prospective basis, FASB ASU No. 2015-17, “Balance Sheet Classification of Deferred Taxes.” This ASU requires all deferred tax assets and liabilities to be reported as noncurrent. Noncurrent assets and liabilities include deferred taxes of $ 286 million and $ 10,999 million , respectively, at December 31, 2015 . Current assets, noncurrent assets, c urrent liabilities and noncurrent liabilities included deferred taxes of $ 865 million, $ 370 million, $ 8 million and $ 15,070 million, respectively, at December 31, 2014 . The adoption of this ASU was not reflected on our consolidated statement of cash flows. We h ave loss and credit carryovers in multiple taxing jurisdictions. These attributes generally expire between 2016 and 2036 with some carryovers having indefinite carryforward periods. Valuation allowances have been established to reduce deferred tax ass ets to an amount that will, more likely than not, be realized. During 2015, valuation allowances decreased a total of $ 236 million. This decrease primarily relates to the relinquishment of certain assets. Based on our historical taxable income, expectations for the future, and available tax-planning strategies, management expects remaining net deferred tax assets will be realized as offsets to reversing deferred tax liabilities and as offsets to the tax consequences of future taxable income. At December 31, 2015 , unremitted income considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures tot aled approximately $ 3,300 million . Deferred income taxes have not been provided on this amount , as we do not plan to initiate any action that would require the payment of income taxes. Due to the natur e of our structures within the jurisdictions in which we operate, as well as the complex nature of the relevant tax laws, it is not practicable to estimate the amount of additional tax , if any, that might be payable on this income if distri buted. The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2015, 2014 and 2013: Millions of Dollars 2015 2014 2013 Balance at January 1 $ 442 655 872 Additions based on tax positions related to the current year 54 46 52 Additions for tax positions of prior years 4 7 30 Reductions for tax positions of prior years (37) (228) (251) Settlements (4) (28) (48) Lapse of statute - (10) - Balance at December 31 $ 459 442 655 Included in the balance of unrecognized tax benefits for 2015 , 2014 and 2013 were $ 354 million, $ 348 million and $ 440 million, respectively, which, if recognized, would impact our effective tax rate. At December 31, 2015 , 2014 and 2013 , accrued liabilities for interest and penalties totaled $ 79 million, $ 65 million and $ 120 million, respectively, net of accrued income taxes. Interest and penalties res ult ed in a reduction to earnings of $ 11 million in 2015 , and a benefit to earnings of $ 43 million and $ 9 million in 2014 and 2013 , respectively. 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 (2012 ), Canada (200 9 ), United States (2010) and Norway (2014 ). 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) 2015 2014 2013 2015 2014 2013 Income (loss) before income taxes from continuing operations United States $ (4,150) 2,310 5,046 57.3 % 24.6 34.9 Foreign (3,089) 7,080 9,400 42.7 75.4 65.1 $ (7,239) 9,390 14,446 100.0 % 100.0 100.0 Federal statutory income tax $ (2,534) 3,287 5,056 35.0 % 35.0 35.0 Foreign taxes in excess of federal statutory rate 381 376 1,389 (5.3) 4.0 9.6 Foreign tax law change (426) - - 5.9 U.S. fair value election (185) - - 2.6 Capital loss benefit - - (79) - - (0.5) Federal manufacturing deduction - (15) (35) - (0.2) (0.2) State income tax (89) (44) 79 1.2 (0.5) 0.5 Other (15) (21) (1) 0.2 (0.2) - $ (2,868) 3,583 6,409 39.6 % 38.1 44.4 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. The change in the effective tax rate from 2013 to 2014 , was primarily due to lower income in high tax jurisdictions. 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 “Provision (benefit) for income taxes” 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 perce nt effective July 1, 2015 . As a result, a $ 129 million net tax expense for revaluing the Canadian deferred tax liability is reflected in the “Provision (benefit) for income taxes” line on our consolidated income statement . In December 2015 , we filed refund claims for prior years electing the fair market value method of apportioning interest in the United States. As a result, a $ 185 million tax benefit was recorded in the fourth quarter of 2015 . Certain operating loss es in jurisdictions outside of the U.S. only yield a tax benefit in the U.S. as a worthless security deduction. For 2015, 2014 and 2013 th e amount of the benefit was $ 491 million, $ 122 million and $ 19 million, respectively.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Income	12 Months Ended
	Dec. 31, 2015
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, 2012 $ (1,425) 5,512 4,087 Other comprehensive income (loss) 601 (2,686) (2,085) 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) The following table summarizes reclassifications out of accumulated other comprehensive loss during the years ended December 31: Millions of Dollars 2015 2014 Defined Benefit Plans $ 251 81 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 133 44 See Note 18—Employee Benefit Plans, for additional information. There were no items within accumulated other comprehensive income (loss) related to noncontrolling interests.

Cash Flow Information

Cash Flow Information	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Noncash Investing and Financing Activities Increase in PP&E related to an increase in asset retirement obligations* $ 402 1,611 1,329 Increase (decrease) in PP&E and debt related to a capital lease asset and obligation 7 (84) 906 Cash Payments Interest $ 920 669 566 Income taxes** 523 4,203 4,910 Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ - (876) (361) Short-term investments sold - 1,129 98 $ - 253 (263) *Includes $68 million and $212 million in 2014 and 2013, respectively, primarily related to the impact of U.K. tax law changes on the deductibility of decommissioning costs. **Net of $642 million in 2015 related to a refund received from the Internal Revenue Service for 2014 overpaid taxes. In relation to certain working capital changes associated with investing activities, we reclassified $ 180 million and $ 55 million of the “Increase (decrease) in accounts payable” line within “Cash Flows From Operating Activities” to the “Working capital changes associated with investing activities” line within “Cash Flows From Investing Activities” for December 31, 2014 and December 31, 2013, respectively . Th ere was no impact to “Cash and Cash Equivalents at End of Period .”

Other Financial Information

Other Financial Information	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Interest and Debt Expense Incurred Debt $ 1,130 1,063 1,087 Other 84 73 192 1,214 1,136 1,279 Capitalized (294) (488) (667) Expensed $ 920 648 612 Other Income Interest income $ 45 83 113 Other, net 80 283 261 $ 125 366 374 Research and Development Expenditures —expensed $ 222 263 258 Shipping and Handling Costs* $ 1,181 1,360 1,137 *Amounts included in production and operating expenses. Foreign Currency Transaction (Gains) Losses —after-tax Alaska $ - - - Lower 48 - - - Canada - (4) (6) Europe and North Africa* (22) (56) (29) Asia Pacific and Middle East (78) - (29) Other International* (9) - - Corporate and Other 45 16 31 $ (64) (44) (33) *2014 and 2013 restated to conform to current period presentation. Millions of Dollars 2015 2014 Properties, Plants and Equipment Proved properties $ 122,796 130,448 Unproved properties 7,410 8,951 Other 6,653 6,831 Gross properties, plants and equipment 136,859 146,230 Less: Accumulated depreciation, depletion and amortization (70,413) (70,786) Net properties, plants and equipment $ 66,446 75,444

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Operating revenues and other income $ 118 119 102 Purchases 97 190 184 Operating expenses and selling, general and administrative expenses 62 70 35 Net interest (income) expense* (9) (44) 31 *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, 2015
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 the third quarter of 2014. Results for these operations have been reported as discontinued operations in all periods presented. For additional information, see Note 3 — Discontinued Operations . Effective November 1, 2015, the Other International and historically presented Eu rope segments were restructured to align with changes to our internal organization structure. The Libya business was moved from the Other International segment to the historically presented Europe segment, which is now renamed Europe and North Africa. Ac cordingly, results of operations for the Other International and Europe and North Africa segments have been revised in all periods presented. There was no impact on our consolidated financial statements, and the impact on our segment presentation is immaterial. Corporate and Other represents costs not directly associated with an operating segment, such as most intere st expense, corporate overhead and certain technology activities, including licensing revenues. Corporate assets include all cash and c ash equivalents. We evaluate performance and allocate resources based on net income (loss) attributable to ConocoPhillips. Segment accounting policies are the same as those in Note 1 —Accounting Policies. Intersegment sales are at prices that ap proximate market. Analysis of Results by Operating Segment Millions of Dollars 2015 2014 2013 Sales and Other Operating Revenues Alaska $ 4,351 8,382 8,553 Lower 48 11,976 21,721 19,480 Intersegment eliminations (63) (107) (104) Lower 48 11,913 21,614 19,376 Canada 2,454 5,162 5,254 Intersegment eliminations (318) (753) (607) Canada 2,136 4,409 4,647 Europe and North Africa 6,110 10,665 13,248 Intersegment eliminations (4) (49) - Europe and North Africa 6,106 10,616 13,248 Asia Pacific and Middle East 4,746 7,425 8,426 Intersegment eliminations (1) (1) - Asia Pacific and Middle East 4,745 7,424 8,426 Other International 1 - - Corporate and Other 312 79 163 Consolidated sales and other operating revenues $ 29,564 52,524 54,413 Depreciation, Depletion, Amortization and Impairments Alaska $ 690 584 533 Lower 48 4,227 3,911 3,247 Canada 788 962 1,531 Europe and North Africa 2,565 2,345 1,363 Asia Pacific and Middle East 2,981 1,275 1,188 Other International - 1 1 Corporate and Other 107 107 100 Consolidated depreciation, depletion, amortization and impairments $ 11,358 9,185 7,963 Millions of Dollars 2015 2014 2013 Equity in Earnings of Affiliates Alaska $ 4 9 7 Lower 48 (5) 1 (2) Canada 78 1,385 984 Europe and North Africa 23 37 27 Asia Pacific and Middle East 550 1,089 1,162 Other International 8 9 43 Corporate and Other (3) (1) (2) Consolidated equity in earnings of affiliates $ 655 2,529 2,219 Income Taxes Alaska $ (71) 1,081 1,275 Lower 48 (1,119) (92) 398 Canada (223) 236 (44) Europe and North Africa (854) 1,590 3,258 Asia Pacific and Middle East 467 1,194 1,512 Other International (456) (102) 134 Corporate and Other (612) (324) (124) Consolidated income taxes $ (2,868) 3,583 6,409 Net Income (Loss) Attributable to ConocoPhillips Alaska $ 4 2,041 2,274 Lower 48 (1,932) (22) 754 Canada (1,044) 940 718 Europe and North Africa 409 814 1,297 Asia Pacific and Middle East (463) 2,939 3,532 Other International (593) (100) 223 Corporate and Other (809) (874) (820) Discontinued operations - 1,131 1,178 Consolidated net income (loss) attributable to ConocoPhillips $ (4,428) 6,869 9,156 Investments In and Advances To Affiliates Alaska $ 61 53 53 Lower 48 455 471 905 Canada 8,165 9,484 10,273 Europe and North Africa 70 126 143 Asia Pacific and Middle East 11,780 14,022 12,806 Other International - 59 141 Corporate and Other 15 15 16 Consolidated investments in and advances to affiliates $ 20,546 24,230 24,337 Millions of Dollars 2015 2014 2013 Total Assets Alaska $ 12,555 12,655 11,662 Lower 48 26,932 30,185 29,552 Canada 17,221 21,764 22,394 Europe and North Africa 13,703 16,970 18,109 Asia Pacific and Middle East 22,318 25,976 25,473 Other International 282 1,116 819 Corporate and Other 4,473 7,815 8,367 Discontinued operations - 58 1,681 Consolidated total assets $ 97,484 116,539 118,057 Capital Expenditures and Investments Alaska $ 1,352 1,564 1,140 Lower 48 3,765 6,054 5,210 Canada 1,255 2,340 2,232 Europe and North Africa 1,573 2,540 3,126 Asia Pacific and Middle East 1,812 3,877 3,382 Other International 173 520 265 Corporate and Other 120 190 182 Consolidated capital expenditures and investments $ 10,050 17,085 15,537 Interest Income and Expense Interest income Corporate $ 36 40 60 Lower 48 - 35 43 Europe and North Africa 2 2 1 Asia Pacific and Middle East 6 6 8 Other International 1 - 1 Interest and debt expense Corporate $ 920 648 532 Canada - - 80 Sales and Other Operating Revenues by Product Crude oil $ 12,830 23,784 24,899 Natural gas 11,888 20,717 22,539 Natural gas liquids 952 2,245 2,111 Other* 3,894 5,778 4,864 Consolidated sales and other operating revenues by product $ 29,564 52,524 54,413 *Includes LNG and bitumen. Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2015 2014 2013 2015 2014 2013 United States $ 16,284 30,019 27,954 37,445 39,641 37,593 Australia (3) 2,127 3,258 3,571 12,788 14,969 13,450 Canada 2,136 4,409 4,647 16,766 20,874 21,380 China 782 1,701 2,120 1,647 1,913 2,143 Indonesia 1,165 1,963 2,083 1,191 1,526 1,780 Malaysia 598 403 281 3,599 3,811 3,406 Norway 2,107 3,794 4,323 6,933 8,142 8,089 United Kingdom 4,005 6,594 7,717 4,154 5,327 5,959 Other foreign countries 360 383 1,717 2,469 3,471 3,364 Worldwide consolidated $ 29,564 52,524 54,413 86,992 99,674 97,164 (1)Sales and other operating revenues are attributable to countries based on the location of the operations generating the revenues. (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, 2015
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. Add itional disclosures will be required to describe the nature, amount, timing and uncertainty of revenue and cash flows arising from customer contracts. In August 2015, the FASB issued ASU No. 2015-14, “Deferral of the Effective Date,” which defers the e ffective date of ASU No. 2014-09. The ASU is now effective for interim and annual periods beginning after December 15, 2017. Early adoption is permitted for interim and annual periods beginning after December 15, 2016. Entities may choose to adopt the s tandard using either a full retrospective approach or a modified retrospective approach. We are currently evaluating the impact of the adoption of ASU No. 2014-09 and continue to monitor proposals issued by the FASB to clarify the ASU. In February 2015, the FASB issued ASU No. 2015-02, “Amendments to the Consolidation Analysis,” which amends existing requirements applicable to reporting entities that are required to evaluate whether certain legal entities should be consolidated. The ASU is effective for interim and annual periods beginning after December 15, 2015. Early adoption is permitted. Entities may choose to adopt the standard using either a full retrospective approach or a modified retrospective approach. We do not expect the adoption of this A SU to have a material impact on our consolidated financial statements and disclosures.

Supplementary Information - Con

Supplementary Information - Condensed Consolidating Financial Information	12 Months Ended
	Dec. 31, 2015
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. ConocoPhil lips Australia Funding Company and ConocoPhillips Canada Funding Company I are indirect, 100 percent owned subsidiaries of ConocoPhillips Company. ConocoPhillips and ConocoPhillips Company have fully and unconditionally guaranteed the payment obligations of ConocoPhillips Australia Funding Company and ConocoPhillips Canada Funding Company I, wit h 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 respect to its publicly held debt securities. All guarantees are joint and several. The following condensed consolidating financial information presents the results o f operations, financial position and cash flows for: ConocoPhillips, ConocoPhillips Company and ConocoPhillips Canada Funding Company I (in each case, reflecting investments in subsidiaries utilizing the equity method of accounting). All other nonguaranto r subsidiaries of ConocoPhillips. The consolidating adjustments necessary to present ConocoPhillips’ 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 s easoned 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 securities, 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 not included in the condensed consolidating financial information. During 2013, ConocoPhillips Australia Funding Company’s guaranteed, publicly held debt was repaid. Beginning in 2014, financial information for ConocoPhillips Australia Funding Company is presented in the “All Other Subsidiaries” column of our condensed consolidating financial information. In 2014, ConocoPhillips received $34.5 billion in dividends fro m ConocoPhillips Company to settle certain accumulated intercompany balances. This consisted of a $17.5 billion distribution of 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 February 2016, ConocoPhillips received a $2.3 billion return of capital from ConocoPhillips Company to settle certain accumulated intercompany balances. The transaction will be reflected in the first quarter 2016 Condensed Consolidating Financial Information for ConocoPhillips and ConocoPhillips Company and is expected to have no impact on our consolidated financial statements. This condensed consolidating fin ancial information should be read in conjunction with the accompanying consolidated financial statements and notes. Millions of Dollars Year Ended December 31, 2015 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 11,473 - 18,091 - 29,564 Equity in earnings 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) Provision (benefit) for income taxes (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) Income Statement Year Ended December 31, 2014 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 Provision (benefit) for income taxes (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 Year Ended December 31, 2013 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Australia Funding Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 18,186 - - 36,227 - 54,413 Equity in earnings of affiliates 8,374 9,200 - - 2,611 (17,966) 2,219 Gain on dispositions - 364 - - 878 - 1,242 Other income 2 271 - - 101 - 374 Intercompany revenues 82 458 13 305 4,948 (5,806) - Total Revenues and Other Income 8,458 28,479 13 305 44,765 (23,772) 58,248 Costs and Expenses Purchased commodities - 15,779 - - 11,812 (4,948) 22,643 Production and operating expenses - 1,492 - - 5,756 (10) 7,238 Selling, general and administrative expenses 11 623 - 1 238 (19) 854 Exploration expenses - 659 - - 573 - 1,232 Depreciation, depletion and amortization - 907 - - 6,527 - 7,434 Impairments - 4 - - 525 - 529 Taxes other than income taxes - 236 - - 2,648 - 2,884 Accretion on discounted liabilities - 56 - - 378 - 434 Interest and debt expense 630 327 12 235 237 (829) 612 Foreign currency transaction (gains) losses 52 3 - (349) 236 - (58) Total Costs and Expenses 693 20,086 12 (113) 28,930 (5,806) 43,802 Income from continuing operations before income taxes 7,765 8,393 1 418 15,835 (17,966) 14,446 Provision (benefit) for income taxes (213) 19 - 31 6,572 - 6,409 Income From Continuing Operations 7,978 8,374 1 387 9,263 (17,966) 8,037 Income from discontinued operations 1,178 1,178 - - 1,178 (2,356) 1,178 Net income 9,156 9,552 1 387 10,441 (20,322) 9,215 Less: net income attributable to noncontrolling interests - - - - (59) - (59) Net Income Attributable to ConocoPhillips $ 9,156 9,552 1 387 10,382 (20,322) 9,156 Comprehensive Income Attributable to ConocoPhillips $ 7,071 7,467 1 99 7,782 (15,349) 7,071 Millions of Dollars At December 31, 2015 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated 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 Balance Sheet At December 31, 2014 Assets Cash and cash equivalents $ - 770 7 4,285 - 5,062 Accounts and notes receivable 20 2,813 22 6,671 (2,719) 6,807 Inventories - 281 - 1,050 - 1,331 Prepaid expenses and other current assets 6 754 15 1,138 (45) 1,868 Total Current Assets 26 4,618 44 13,144 (2,764) 15,068 Investments, loans and long-term receivables* 55,568 70,732 3,965 32,467 (137,593) 25,139 Net properties, plants and equipment - 9,730 - 65,714 - 75,444 Other assets 40 67 208 1,338 (765) 888 Total Assets $ 55,634 85,147 4,217 112,663 (141,122) 116,539 Liabilities and Stockholders’ Equity Accounts payable $ 1 4,149 14 6,581 (2,719) 8,026 Short-term debt (5) 6 5 176 - 182 Accrued income and other taxes - 117 - 934 - 1,051 Employee benefit obligations - 595 - 283 - 878 Other accruals 170 337 71 868 (46) 1,400 Total Current Liabilities 166 5,204 90 8,842 (2,765) 11,537 Long-term debt 7,541 8,197 2,974 3,671 - 22,383 Asset retirement obligations and accrued environmental costs - 1,328 - 9,319 - 10,647 Deferred income taxes - 265 - 14,811 (6) 15,070 Employee benefit obligations - 2,162 - 802 - 2,964 Other liabilities and deferred credits* 2,577 7,391 1,142 17,218 (26,663) 1,665 Total Liabilities 10,284 24,547 4,206 54,663 (29,434) 64,266 Retained earnings 37,983 21,448 (1,096) 17,355 (31,186) 44,504 Other common stockholders’ equity 7,367 39,152 1,107 40,283 (80,502) 7,407 Noncontrolling interests - - - 362 - 362 Total Liabilities and Stockholders’ Equity $ 55,634 85,147 4,217 112,663 (141,122) 116,539 *Includes intercompany loans. Millions of Dollars Statement of Cash Flows Year Ended December 31, 2015 ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities (225) 245 9 7,519 24 7,572 Cash Flows From Investing Activities Capital expenditures and investments - (3,064) - (8,386) 1,400 (10,050) Working capital changes associated with investing activities - (4) - (964) - (968) Proceeds from asset dispositions 3,500 826 - 1,225 (3,599) 1,952 Long-term advances/loans—related parties - (278) - (2,245) 2,523 - Collection of advances/loans—related parties - - - 205 (100) 105 Intercompany cash management 102 46 - (148) - - Other - 304 - 1 1 306 Net Cash Provided by (Used in) Investing Activities 3,602 (2,170) - (10,312) 225 (8,655) Cash Flows From Financing Activities Issuance of debt - 4,743 - 278 (2,523) 2,498 Repayment of debt - (100) - (103) 100 (103) Issuance of company common stock 283 - - (2) (363) (82) Dividends paid (3,664) - - (339) 339 (3,664) Other 4 (3,484) - 1,204 2,198 (78) Net Cash Provided by (Used in) Financing Activities (3,377) 1,159 - 1,038 (249) (1,429) Effect of Exchange Rate Changes on Cash and Cash Equivalents - - (1) (181) - (182) Net Change in Cash and Cash Equivalents - (766) 8 (1,936) - (2,694) Cash and cash equivalents at beginning of period - 770 7 4,285 - 5,062 Cash and Cash Equivalents at End of Period $ - 4 15 2,349 - 2,368 Statement of Cash Flows Year Ended December 31, 2014* Cash Flows From Operating Activities Net cash provided by 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 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 sales 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 provided by (used in) continuing financing activities (5,058) (31,480) - 944 33,020 (2,574) Net cash used in discontinued operations - - - (335) 335 - Net Cash Provided by (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 *Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to the Consolidated Financial Statements. Millions of Dollars Statement of Cash Flows Year Ended December 31, 2013* ConocoPhillips ConocoPhillips Company ConocoPhillips Australia Funding 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 $ (295) 22,928 (2) 1 14,510 (21,286) 15,856 Net cash provided by discontinued operations - 91 - - 642 (448) 285 Net Cash Provided by (Used in) Operating Activities (295) 23,019 (2) 1 15,152 (21,734) 16,141 Cash Flows From Investing Activities Capital expenditures and investments - (4,821) - - (13,566) 2,850 (15,537) Working capital changes associated with investing activities - 68 - - (123) - (55) Proceeds from asset dispositions - 2,633 - - 9,745 (2,158) 10,220 Net purchases of short-term investments - - - - (263) - (263) Long-term advances/loans—related parties - (342) - - (545) 887 - Collection of advances/loans—related parties - 174 750 169 3,010 (3,958) 145 Intercompany cash management 2,511 (15,919) - - 13,408 - - Other - 21 - - (233) - (212) Net cash provided by (used in) continuing investing activities 2,511 (18,186) 750 169 11,433 (2,379) (5,702) Net cash used in discontinued operations - (52) - - (603) 52 (603) Net Cash Provided by (Used in) Investing Activities 2,511 (18,238) 750 169 10,830 (2,327) (6,305) Cash Flows From Financing Activities Issuance of debt - 522 - - 365 (887) - Repayment of debt - (2,924) (750) - (1,230) 3,958 (946) Change in restricted cash 748 - - - - - 748 Issuance of company common stock 365 - - - - (345) 20 Dividends paid (3,334) - (4) - (21,984) 21,988 (3,334) Other 3 52 - - (2,984) (692) (3,621) Net cash used in continuing financing activities (2,218) (2,350) (754) - (25,833) 24,022 (7,133) Net cash used in discontinued operations - - - - (39) 39 - Net Cash Used in Financing Activities (2,218) (2,350) (754) - (25,872) 24,061 (7,133) Effect of Exchange Rate Changes on Cash and Cash Equivalents - (9) - - (66) - (75) Net Change in Cash and Cash Equivalents (2) 2,422 (6) 170 44 - 2,628 Cash and cash equivalents at beginning of period 2 12 6 59 3,539 - 3,618 Cash and Cash Equivalents at End of Period $ - 2,434 - 229 3,583 - 6,246 *Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to the Consolidated Financial Statements.

Schedule ll

Schedule ll	12 Months Ended
	Dec. 31, 2015
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 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 2013 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 10 - - (2) (b) 8 Deferred tax asset valuation allowance 1,345 (357) 3 (22) 969 Included in other liabilities: Restructuring accruals 17 10 (1) (7) (c) 19 (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, 2015
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. Effective November 1, 2015, the Other International and historically presented Europe segments were restructured to align with changes to our intern al organization structure. The Libya business was moved from the Other International segment to the historically presented Europe segment, which is now renamed Europe and North Africa. Certain financial information has been revised for all prior periods presented to reflect the change in the composition of our operating segments. For additional information, see Note 24 —Segment Disclosures and Related Information. Unless indicated otherwise, the information in the Notes to the Consolidated Financial S tatements 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 preparation of financial statements in conformity with accounting principles generally accepted in the United States requires management to make estimates and assumptions that affect the reported amounts of assets, liabilities, revenues and expenses, and the disclosures of contingent assets and liabilities. Actual results could differ from these estimates.
Revenue Recognition	Revenue Recognition— Revenues associated with sales of crude oil, bitumen, natural gas, liquefied natural gas (LNG), natural gas liquids and other items are recognized when title passes to the customer, which is when the risk of ownership passes to the purchaser and physical delivery of goods occurs, either immediately or within a fixed delivery schedule that is reasonable and customary in the industry. Revenues associated with producing proper ties in which we have an interest with other producers are recognized based on the actual volumes we sold during the period. Any differences between volumes sold and entitlement volumes, based on our net working interest, which are deemed to be nonrecover able 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 line) .
Shipping and Handling Costs	Shipping and Handling Costs— We in clude 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 customers are recorded as a component of revenue.
Cash Equivalents	Cash Equivalents— Cash equivalents are highly liquid, short-term investments that are readily convertible to known amounts of cash and have original maturities of 90 days or less from their date of purchase. They are carried at cost plus accrued interest, which approximates fair value.
Short-Term Investments	Short-Term Investments —Investments in bank time deposits and marketable securities (commercial paper and government obligations) with original maturities of greater than 90 days but less than one year are classified as short-term investments.
Inventories	Inventories— We have several valuation methods for our various types of 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 match current inventory costs with curr ent 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 miscella neous 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	Fair Value Measurements— We categorize a ssets and liabilities measured at fair value 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 inpu ts are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting significan t modifications to observable related market data or our assumptions about pricing by market participants.
Derivative Instruments	Derivative Instruments— Deriva tive 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 netted against derivative assets and derivative liabilities, respectively. Recognition and classification of the gain or loss that results from recording and adjusting a derivative to fair value depends on the purpose for issuing or holding t he derivative. Gains 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 it s 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 devel opment 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. Explo ratory 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 econo mically recoverable reserves 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 capit alized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For complex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on t he balance sheet for several years while we perform additional appraisal drilling and seismic work on the potential oil and gas field or while we seek government or co-venturer approval of development plans or seek environmental permitting. Once all requi red approvals and permits 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 pre-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 deprec iation 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 indep endent 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 det ermined 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 avail able, 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 res erves exist, an appropriate risk-adjusted amount of these reserves may be included in the impairment calculation.
Impairment of Investments in Nonconsolidated Entities	Impairment of Investments in Nonconsolidated Entities — Investments in nonconsolidated entities are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred and annually following updates to corporate planning assumptions. When such a condition is judgmentally determined to be other than temporary, the carrying value of the investment is writte n down to fair value. The fair value of the impaired investment is based on quoted market prices, if available, or upon the present value of expected future cash flows using discount rates believed to be consistent with those used by principal market part icipants, plus market analysis of comparable assets owned by the investee, if appropriate.
Maintenance and Repairs	Maintenance and Repairs— C osts of ma intenance and repairs, which are not significant improvements, are expensed when incurred.
Property Dispositions	Property Dispositions— When complete uni ts 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 depreciable 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) 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 their receipt is probable and estimable.
Guarantees	G uarantees— 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 essential ly 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 gu arantee.
Stock-Based Compensation	Share -Based Compensation— We recognize share -based compensation expense over the shorter of the service period (i.e., the stated period of time required to earn the award) or the period beginning at the start 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 liabilities, except for deferred taxes on income and temporary differences related to the cumula tive translation adjustment considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures. Allowable tax credits are applied currently as reductions of the provision for income taxes. Interest related to unr ecognized 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, including unallocated shar es held by the stock savings feature of the ConocoPhillips Savings Plan. 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 equivalen ts 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 unexercised stock options, but on ly 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 and shares held by grantor trusts are excluded from the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the participating securities is immateri al.

Discontinured Operations (Table

Discontinured Operations (Tables)	12 Months Ended
	Dec. 31, 2015
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 Disposition Group during 2014 and 2013 were as follows: Millions of Dollars 2014 2013 Sales and other operating revenues from discontinued operations $ 480 1,185 Income from discontinued operations before-tax $ 1,147 1,461 Income tax expense 16 283 Income from discontinued operations $ 1,131 1,178

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2015
Inventories [Abstract]
Inventories	Note 5 —Inventories Inventories at December 31 were: Millions of Dollars 2015 2014 Crude oil and natural gas $ 406 538 Materials and supplies 718 793 $ 1,124 1,331

Investments, Loans and Long-T39

Investments, Loans and Long-Term Receivables (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Equity investments $ 19,850 23,426 Loans and advances—related parties 696 804 Long-term receivables 519 444 Other investments 121 465 $ 21,186 25,139
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 2015 2014 2013 Revenues $ 11,003 19,243 18,035 Income before income taxes 1,866 6,746 6,384 Net income 1,801 6,630 6,125 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2015 2014 Current assets $ 2,504 4,512 Noncurrent assets 58,431 58,570 Current liabilities 1,863 3,346 Noncurrent liabilities 24,820 20,210

Suspended Wells (Tables)

Suspended Wells (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015, 2014 and 2013: Millions of Dollars 2015 2014 2013 Beginning balance at January 1 $ 1,299 994 1,038 Additions pending the determination of proved reserves 331 478 466 Reclassifications to proved properties (28) (9) (29) Sales of suspended well investment - (57) (481) Charged to dry hole expense (342) (107) - Ending balance at December 31 $ 1,260 1,299 994 * *Includes $57 million of assets that were held for sale in Nigeria.
Aging of suspended well cost	The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2015 2014 2013 Exploratory well costs capitalized for a period of one year or less $ 235 466 437 Exploratory well costs capitalized for a period greater than one year 1,025 833 557 Ending balance $ 1,260 1,299 994 * Number of projects with exploratory well costs capitalized for a period greater than one year 28 30 29 *Includes $57 million of assets that were held for sale in Nigeria.
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, 2015: Millions of Dollars Suspended Since Total 2012–2014 2009–2011 2002–2008 Greater Poseidon—Australia (2) 177 165 12 - Caldita/Barossa—Australia (1) 77 - - 77 FAN—Senegal (1) 117 117 - - Fiord West—Alaska (2) 16 - - 16 Greater Clair—UK (2) 127 113 14 - Kamunsu East—Malaysia (2) 19 19 - - Limbayong—Malaysia (1) 23 23 - - NC 98—Libya (2) 15 11 - 4 NPRA—Alaska (1) 93 70 17 6 Shenandoah—Lower 48 (1) 94 51 43 - SNE—Senegal (1) 23 23 - - Sunrise—Australia (2) 13 - - 13 Surmont 3 and beyond—Canada (1) 89 58 14 17 Tiber—Lower 48 (1) 100 60 40 - Other of $10 million or less each (1)(2) 42 24 2 16 Total $ 1,025 734 142 149 (1)Additional appraisal wells planned. (2)Appraisal drilling complete; costs being incurred to assess development.

Impairments (Tables)

Impairments (Tables)	12 Months Ended
	Dec. 31, 2015
Impairment Of Long Lived Assets [Abstract]
Impairment Charges By Segment Before Tax	Note 9 —Impairments During 2015, 2014 and 2013, we recognized the following before-tax impairment charges: Millions of Dollars 2015 2014 2013 Alaska $ 10 59 3 Lower 48 (2) 208 2 Canada 4 38 216 Europe and North Africa 724 541 301 Asia Pacific and Middle East 1,508 7 3 Corporate 1 3 4 $ 2,245 856 529

Asset Retirement Obligations 42

Asset Retirement Obligations and Accrued Environmental Costs (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Asset retirement obligations $ 9,911 10,939 Accrued environmental costs 258 344 Total asset retirement obligations and accrued environmental costs 10,169 11,283 Asset retirement obligations and accrued environmental costs due within one year* (589) (636) Long-term asset retirement obligations and accrued environmental costs $ 9,580 10,647 *Classified as a current liability on the balance sheet under "Other accruals."
Changes in overall asset retirement obligation changed	During 2015 and 2014, our overall asset retirement obligation changed as follows: Millions of Dollars 2015 2014 Balance at January 1 $ 10,939 10,076 Accretion of discount 480 479 New obligations 135 368 Changes in estimates of existing obligations 267 1,175 Spending on existing obligations (437) (365) Property dispositions (726) (20) Foreign currency translation (747) (774) Balance at December 31 $ 9,911 10,939

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt [Abstract]
Long-term debt	Note 11 —Debt Long-term debt at December 31 was: Millions of Dollars 2015 2014 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 2,250 2,250 6.50% Notes due 2039 500 500 6.00% Notes due 2020 1,000 1,000 5.951% Notes due 2037 645 645 5.95% Notes due 2036 500 500 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 1,250 5.20% Notes due 2018 500 500 4.30% Notes due 2044 750 750 4.15% Notes due 2034 500 500 3.35% Notes due 2024 1,000 1,000 3.35% Notes due 2025 500 - 2.875% Notes due 2021 750 750 2.4% Notes due 2022 1,000 1,000 2.2% Notes due 2020 500 - 1.5% Notes due 2018 750 - 1.05% Notes due 2017 1,000 1,000 Floating rate notes due 2018 at 0.61% – 0.69% during 2015 250 - Floating rate notes due 2022 at 1.18% – 1.26% during 2015 500 - Commercial paper at 0.16% – 0.80% during 2015 and 0.14% – 0.21% during 2014 803 860 Industrial Development Bonds due 2015 through 2038 at 0.01% – 0.13% during 2015 and 0.02% – 0.13% during 2014 18 18 Marine Terminal Revenue Refunding Bonds due 2031 at 0.01% – 0.14% during 2015 and 0.02% – 0.15% during 2014 265 265 Other 24 24 Debt at face value 23,778 21,335 Capitalized leases 818 858 Net unamortized premiums, discounts and debt issuance costs 284 372 Total debt 24,880 22,565 Short-term debt (1,427) (182) Long-term debt $ 23,453 22,383
Capital lease payment table	At December 31, 2015, future minimum payments due under capital leases were: Millions of Dollars 2016 $ 91 2017 76 2018 76 2019 76 2020 76 Remaining years 648 Total 1,043 Less: portion representing imputed interest (225) Capital lease obligations $ 818

Derivative and Financial Inst44

Derivative and Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 Assets Prepaid expenses and other current assets $ 768 4,500 Other assets 60 157 Liabilities Other accruals 754 4,426 Other liabilities and deferred credits 46 144 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 2015 2014 Assets Prepaid expenses and other current assets $ 47 1 Liabilities Other accruals 8 1
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 2015 2014 2013 Sales and other operating revenues $ 231 523 (160) Other income 2 1 4 Purchased commodities (201) (458) 139 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 2015 2014 2013 Foreign currency transaction (gains) losses $ (33) 3 4
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) 2015 2014 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (14) (11) Basis (17) 18 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency 2015 2014 Foreign Currency Exchange Derivatives Sell U.S. dollar, buy other currencies* USD 347 7 Buy U.S. dollar, sell other currencies** USD 20 44 Buy British pound, sell other currencies*** GBP 567 20 *Primarily Canadian dollar, Norwegian krone and British pound. **Primarily Canadian dollar and Norwegian krone. ***Primarily Canadian dollar and euro.
Net carrying amount of held to maturity investments	Millions of Dollars Carrying Amount Cash and Cash Equivalents 2015 2014 Cash $ 528 946 Money market funds - 50 Time deposits Remaining maturities from 1 to 90 days 1,840 3,726 Commercial paper Remaining maturities from 1 to 90 days - 340 $ 2,368 5,062

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value Measurement [Abstract]
Fair value hierarchy for gross financial assets and liabilities	Millions of Dollars December 31, 2015 December 31, 2014 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Deferred compensation investments $ 21 - - 21 297 - - 297 Commodity derivatives 516 242 70 828 4,221 361 75 4,657 Total assets $ 537 242 70 849 4,518 361 75 4,954 Liabilities Commodity derivatives $ 515 273 12 800 4,200 354 16 4,570 Total liabilities $ 515 273 12 800 4,200 354 16 4,570
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, 2015 Assets $ 828 600 228 - 8 220 Liabilities 800 600 200 1 11 188 December 31, 2014 Assets $ 4,657 4,352 305 8 28 269 Liabilities 4,570 4,352 218 4 22 192 At December 31, 2015 and December 31, 2014, 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 3 Inputs Before-Tax Loss Year ended December 31, 2015 Net PP&E (held for use) $ 440 440 681 Net PP&E (unproved property) 104 104 240 Equity method investments 10,210 10,210 1,507 Year ended December 31, 2014 Net PP&E (held for use) $ 87 87 756 Net PP&E (unproved property) 39 39 158 *Represents the fair value at the time of the impairment.
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 2015 2014 2015 2014 Financial assets Deferred compensation investments $ 21 297 21 297 Commodity derivatives 228 297 228 297 Total loans and advances—related parties 808 913 808 913 Financial liabilities Total debt, excluding capital leases 24,062 21,707 24,785 25,191 Commodity derivatives 199 214 199 214

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Issued Beginning of year 1,773,583,368 1,768,169,906 1,762,247,949 Distributed under benefit plans 4,643,020 5,413,462 5,921,957 End of year 1,778,226,388 1,773,583,368 1,768,169,906

Non Mineral Leases (Tables)

Non Mineral Leases (Tables)	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Future minimum rental payments due under noncancelable leases	At December 31, 2015, future minimum rental payments due under noncancelable leases were: Millions of Dollars 2016 $ 671 2017 360 2018 215 2019 156 2020 374 Remaining years 381 Total 2,157 Less: income from subleases (9) Net minimum operating lease payments $ 2,148
Operating leases rental expense	Operating lease rental expense for the years ended December 31 was: Millions of Dollars 2015 2014 2013 Total rentals $ 432 474 317 Less: sublease rentals (9) (10) (12) $ 423 464 305

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2015 2014 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 4,387 3,984 3,954 3,583 716 682 Service cost 138 124 124 109 4 3 Interest cost 161 135 165 166 22 29 Plan participant contributions - 5 - 6 21 21 Plan amendments - - - - (303) - Actuarial (gain) loss (212) (442) 477 598 (49) 53 Benefits paid (729) (162) (333) (122) (63) (70) Curtailment 27 (43) - - 8 - Recognition of termination benefits - 68 - - - - Foreign currency exchange rate change - (348) - (356) (4) (2) Benefit obligation at December 31* $ 3,772 3,321 4,387 3,984 352 716 *Accumulated benefit obligation portion of above at 3,573 2,953 3,957 3,111 December 31: $ Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 3,266 3,278 3,092 3,132 - - Actual return on plan assets (4) 96 234 410 - - Company contributions 73 120 273 203 42 49 Plan participant contributions - 5 - 6 21 21 Benefits paid (729) (162) (333) (122) (63) (70) Foreign currency exchange rate change - (274) - (351) - - Fair value of plan assets at December 31 $ 2,606 3,063 3,266 3,278 - - Funded Status $ (1,166) (258) (1,121) (706) (352) (716)
Weighted-Average Assumptions Used to Determine Benefit Obligations and Net Periodic Benefit Cost	Millions of Dollars Pension Benefits Other Benefits 2015 2014 2015 2014 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 175 - 13 - - Current liabilities (99) (34) (26) (9) (45) (49) Noncurrent liabilities (1,067) (399) (1,095) (710) (307) (667) Total recognized $ (1,166) (258) (1,121) (706) (352) (716) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 4.50 % 3.95 3.80 3.55 3.90 4.15 Rate of compensation increase 4.00 4.05 4.75 4.35 - - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 4.00 % 3.55 4.40 4.75 4.05 4.45 Expected return on plan assets 7.00 5.40 7.00 5.75 - - Rate of compensation increase 4.75 4.35 4.75 4.60 - -
Sources of change in other comprehensive income	Millions of Dollars Pension Benefits Other Benefits 2015 2014 2015 2014 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ 61 490 (456) (331) 41 (53) Amortization of (gain) loss included in income (loss)* 312 89 77 57 2 (3) Net change during the period $ 373 579 (379) (274) 43 (56) Prior service credit (cost) arising during the period $ - (2) - (3) 303 - Amortization of prior service cost (credit) included in income (loss) 7 (11) 6 (8) (15) (4) Net change during the period $ 7 (13) 6 (11) 288 (4) *Includes settlement losses recognized in 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 2015 2014 2015 2014 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial (gain) loss $ 773 273 1,146 852 (18) 25 Unrecognized prior service cost (credit) 9 (30) 16 (43) (292) (4) Included in accumulated other comprehensive income (loss) at December 31, 2015, were the following before- tax amounts that are expected to be amortized into net periodic benefit cost during 2016: Millions of Dollars Pension Other Benefits Benefits U.S. Int’l. Unrecognized net actuarial (gain) loss $ 78 30 (2) Unrecognized prior service cost (credit) 5 (6) (34)
Net periodic benefit cost of all defined benefit plans	The components of net periodic benefit cost of all defined benefit plans are presented in the following table: Millions of Dollars Pension Benefits Other Benefits 2015 2014 2013 2015 2014 2013 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 138 124 124 109 138 102 4 3 3 Interest cost 161 135 165 166 143 145 22 29 26 Expected return on plan assets (201) (164) (213) (181) (186) (160) - - - Amortization of prior service cost (credit) 6 (7) 6 (8) 6 (7) (17) (4) (4) Recognized net actuarial loss (gain) 115 82 77 57 151 73 2 (3) 3 Settlements 197 7 - - 67 - - - - Curtailment (gain) loss 35 (4) - - - - 2 - - Net periodic benefit cost $ 451 173 159 143 319 153 13 25 28
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 2015 Equity Securities U.S. $ 777 3 2 782 609 - - 609 International 485 - - 485 450 - - 450 Common/collective trusts - 569 - 569 - 214 - 214 Mutual funds - - - - 234 106 - 340 Debt Securities Government 85 56 - 141 493 - - 493 Corporate - 331 17 348 - 172 - 172 Agency and mortgage-backed securities - 80 - 80 - 36 - 36 Common/collective trusts - - - - - 406 - 406 Mutual funds - - - - 136 - - 136 Cash and cash equivalents - 60 - 60 46 10 - 56 Derivatives - (7) - (7) (26) - - (26) Real estate - - 63 63 - - 169 169 Total* $ 1,347 1,092 82 2,521 1,942 944 169 3,055 *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. 2014 Equity Securities U.S. $ 1,039 2 8 1,049 628 - - 628 International 671 - - 671 445 - - 445 Common/collective trusts - 542 - 542 - 227 - 227 Mutual funds - - - - 241 97 - 338 Debt Securities Government 132 75 - 207 624 - - 624 Corporate - 426 4 430 - 166 - 166 Agency and mortgage-backed securities - 115 - 115 - 46 1 47 Common/collective trusts - - - - - 396 - 396 Mutual funds - - - - 167 - - 167 Cash and cash equivalents - 67 - 67 50 18 - 68 Private equity funds - - - - - - 1 1 Derivatives 5 (3) - 2 (4) - - (4) Real estate - - 55 55 - - 166 166 Total* $ 1,847 1,224 67 3,138 2,151 950 168 3,269 *Excludes the participating interest in the insurance annuity contract with a net asset value of $116 million and net receivables related to security transactions of $21 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. 2016 $ 414 150 45 2017 347 144 43 2018 335 140 41 2019 335 143 39 2020 338 149 38 2021–2025 1,544 858 158
Share-based compensation expense recognized in income and the associated tax benefit	Compensation Expense — Total share-based compensation expense recognized in income (loss) related to continuing and discontinued operations and the associated tax benefit for the years ended December 31 were as follows: Millions of Dollars 2015 2014 2013 Compensation cost $ 362 358 308 Tax benefit 123 125 109
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: 2015 2014 2013 Assumptions used Risk-free interest rate 1.79 % 1.86 1.09 Dividend yield 4.00 % 4.00 4.00 Volatility factor 23.32 % 25.31 28.95 Expected life (years) 5.79 6.12 5.95
Summary of stock option activity	The following summarizes our stock option activity for the year ended December 31, 2015: Weighted- Weighted- Average Millions of Dollars Average Grant Date Aggregate Options Exercise Price Fair Value Intrinsic Value Outstanding at December 31, 2014 17,117,871 $ 52.61 $ 284 Granted 3,873,700 69.25 $ 9.54 Exercised (548,707) 42.11 10 Forfeited (258,010) 69.20 Expired or cancelled (44) 23.37 Outstanding at December 31, 2015 20,184,810 $ 55.88 $ 42 Vested at December 31, 2015 16,650,347 $ 53.66 $ 42 Exercisable at December 31, 2015 13,192,751 $ 50.34 $ 42 The following summarizes our stock unit activity for the year ended December 31, 2015: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2014 11,782,856 $ 55.75 Granted 3,455,150 65.40 Forfeited (660,298) 63.11 Issued (5,399,543) $ 316 Outstanding at December 31, 2015 9,178,165 $ 59.80 Not Vested at December 31, 2015 6,289,931 $ 59.87
Summary of Performance Share Program activity	The following summarizes our stock-settled Performance Share Program activity for the year ended December 31, 2015: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2014 4,651,244 $ 51.75 Granted 59,807 69.25 Issued (440,829) $ 25 Outstanding at December 31, 2015 4,270,222 $ 51.95 Not Vested at December 31, 2015 702,623 $ 53.90 The following summarizes our cash-settled Performance Share Program activity for the year ended December 31, 2015: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2014 675,587 $ 69.23 Granted 903,398 46.54 Settled (119,749) $ 6 Outstanding at December 31, 2015 1,459,236 $ 46.54 Not Vested at December 31, 2015 873,853 $ 46.54
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, 2015: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2014 1,207,035 $ 31.48 Granted 108,306 58.66 Cancelled (6,969) 22.62 Issued (36,236) $ 3 Outstanding at December 31, 2015 1,272,136 $ 33.25 Not Vested at December 31, 2015 -
Severance accrual	Millions of Dollars Balance at December 31, 2014 $ 61 Accruals 306 Accrual reversals (3) Benefit payments (200) Foreign currency translation adjustments (8) Balance at December 31, 2015 $ 156

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Income Taxes Federal Current $ (718) 188 724 Deferred (1,443) 365 811 Foreign Current 745 2,846 4,249 Deferred (1,315) 252 504 State and local Current 8 46 220 Deferred (145) (114) (99) $ (2,868) 3,583 6,409
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 2015 2014 Deferred Tax Liabilities PP&E and intangibles $ 16,378 20,054 Investment in joint ventures 866 1,013 Inventory 25 51 Deferred state income tax 128 63 Partnership income deferral 44 155 Other 453 509 Total deferred tax liabilities 17,894 21,845 Deferred Tax Assets Benefit plan accruals 1,160 1,552 Asset retirement obligations and accrued environmental costs 4,426 4,971 Deferred state income tax - - Other financial accruals and deferrals 616 552 Loss and credit carryforwards 1,579 1,568 Other 134 329 Total deferred tax assets 7,915 8,972 Less: valuation allowance (734) (970) Net deferred tax assets 7,181 8,002 Net deferred tax liabilities $ 10,713 13,843
Reconciliation of the beginning and ending unrecognized tax benefits	The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2015, 2014 and 2013: Millions of Dollars 2015 2014 2013 Balance at January 1 $ 442 655 872 Additions based on tax positions related to the current year 54 46 52 Additions for tax positions of prior years 4 7 30 Reductions for tax positions of prior years (37) (228) (251) Settlements (4) (28) (48) Lapse of statute - (10) - Balance at December 31 $ 459 442 655
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) 2015 2014 2013 2015 2014 2013 Income (loss) before income taxes from continuing operations United States $ (4,150) 2,310 5,046 57.3 % 24.6 34.9 Foreign (3,089) 7,080 9,400 42.7 75.4 65.1 $ (7,239) 9,390 14,446 100.0 % 100.0 100.0 Federal statutory income tax $ (2,534) 3,287 5,056 35.0 % 35.0 35.0 Foreign taxes in excess of federal statutory rate 381 376 1,389 (5.3) 4.0 9.6 Foreign tax law change (426) - - 5.9 U.S. fair value election (185) - - 2.6 Capital loss benefit - - (79) - - (0.5) Federal manufacturing deduction - (15) (35) - (0.2) (0.2) State income tax (89) (44) 79 1.2 (0.5) 0.5 Other (15) (21) (1) 0.2 (0.2) - $ (2,868) 3,583 6,409 39.6 % 38.1 44.4

Accumulated Other Comprehensi50

Accumulated Other Comprehensive Income (Tables)	12 Months Ended
	Dec. 31, 2015
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, 2012 $ (1,425) 5,512 4,087 Other comprehensive income (loss) 601 (2,686) (2,085) 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)
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 2015 2014 Defined Benefit Plans $ 251 81 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 133 44 See Note 18—Employee Benefit Plans, for additional information. There were no items within accumulated other comprehensive income (loss) related to noncontrolling interests.

Cash Flow Information (Tables)

Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Noncash Investing and Financing Activities Increase in PP&E related to an increase in asset retirement obligations* $ 402 1,611 1,329 Increase (decrease) in PP&E and debt related to a capital lease asset and obligation 7 (84) 906 Cash Payments Interest $ 920 669 566 Income taxes** 523 4,203 4,910 Net Sales (Purchases) of Short-Term Investments Short-term investments purchased $ - (876) (361) Short-term investments sold - 1,129 98 $ - 253 (263) *Includes $68 million and $212 million in 2014 and 2013, respectively, primarily related to the impact of U.K. tax law changes on the deductibility of decommissioning costs. **Net of $642 million in 2015 related to a refund received from the Internal Revenue Service for 2014 overpaid taxes.

Other Financial Information (Ta

Other Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Interest and Debt Expense Incurred Debt $ 1,130 1,063 1,087 Other 84 73 192 1,214 1,136 1,279 Capitalized (294) (488) (667) Expensed $ 920 648 612 Other Income Interest income $ 45 83 113 Other, net 80 283 261 $ 125 366 374 Research and Development Expenditures —expensed $ 222 263 258 Shipping and Handling Costs* $ 1,181 1,360 1,137 *Amounts included in production and operating expenses. Foreign Currency Transaction (Gains) Losses —after-tax Alaska $ - - - Lower 48 - - - Canada - (4) (6) Europe and North Africa* (22) (56) (29) Asia Pacific and Middle East (78) - (29) Other International* (9) - - Corporate and Other 45 16 31 $ (64) (44) (33) *2014 and 2013 restated to conform to current period presentation.
Property, Plant And Equipment [Table Text Block]	Millions of Dollars 2015 2014 Properties, Plants and Equipment Proved properties $ 122,796 130,448 Unproved properties 7,410 8,951 Other 6,653 6,831 Gross properties, plants and equipment 136,859 146,230 Less: Accumulated depreciation, depletion and amortization (70,413) (70,786) Net properties, plants and equipment $ 66,446 75,444

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2015
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 2015 2014 2013 Operating revenues and other income $ 118 119 102 Purchases 97 190 184 Operating expenses and selling, general and administrative expenses 62 70 35 Net interest (income) expense* (9) (44) 31 *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, 2015
Segment Disclosures and Related Information [Abstract]
Sales and Other Operating Revenues	Analysis of Results by Operating Segment Millions of Dollars 2015 2014 2013 Sales and Other Operating Revenues Alaska $ 4,351 8,382 8,553 Lower 48 11,976 21,721 19,480 Intersegment eliminations (63) (107) (104) Lower 48 11,913 21,614 19,376 Canada 2,454 5,162 5,254 Intersegment eliminations (318) (753) (607) Canada 2,136 4,409 4,647 Europe and North Africa 6,110 10,665 13,248 Intersegment eliminations (4) (49) - Europe and North Africa 6,106 10,616 13,248 Asia Pacific and Middle East 4,746 7,425 8,426 Intersegment eliminations (1) (1) - Asia Pacific and Middle East 4,745 7,424 8,426 Other International 1 - - Corporate and Other 312 79 163 Consolidated sales and other operating revenues $ 29,564 52,524 54,413
Depreciation, Depletion, Amortization and Impairments	Depreciation, Depletion, Amortization and Impairments Alaska $ 690 584 533 Lower 48 4,227 3,911 3,247 Canada 788 962 1,531 Europe and North Africa 2,565 2,345 1,363 Asia Pacific and Middle East 2,981 1,275 1,188 Other International - 1 1 Corporate and Other 107 107 100 Consolidated depreciation, depletion, amortization and impairments $ 11,358 9,185 7,963
Equity in Earnings of Affiliates	Millions of Dollars 2015 2014 2013 Equity in Earnings of Affiliates Alaska $ 4 9 7 Lower 48 (5) 1 (2) Canada 78 1,385 984 Europe and North Africa 23 37 27 Asia Pacific and Middle East 550 1,089 1,162 Other International 8 9 43 Corporate and Other (3) (1) (2) Consolidated equity in earnings of affiliates $ 655 2,529 2,219
Income Taxes	Income Taxes Alaska $ (71) 1,081 1,275 Lower 48 (1,119) (92) 398 Canada (223) 236 (44) Europe and North Africa (854) 1,590 3,258 Asia Pacific and Middle East 467 1,194 1,512 Other International (456) (102) 134 Corporate and Other (612) (324) (124) Consolidated income taxes $ (2,868) 3,583 6,409
Net Income Attributable to ConocoPhillips	Net Income (Loss) Attributable to ConocoPhillips Alaska $ 4 2,041 2,274 Lower 48 (1,932) (22) 754 Canada (1,044) 940 718 Europe and North Africa 409 814 1,297 Asia Pacific and Middle East (463) 2,939 3,532 Other International (593) (100) 223 Corporate and Other (809) (874) (820) Discontinued operations - 1,131 1,178 Consolidated net income (loss) attributable to ConocoPhillips $ (4,428) 6,869 9,156
Investments In and Advances To Affiliates	Investments In and Advances To Affiliates Alaska $ 61 53 53 Lower 48 455 471 905 Canada 8,165 9,484 10,273 Europe and North Africa 70 126 143 Asia Pacific and Middle East 11,780 14,022 12,806 Other International - 59 141 Corporate and Other 15 15 16 Consolidated investments in and advances to affiliates $ 20,546 24,230 24,337
Total Assets	Millions of Dollars 2015 2014 2013 Total Assets Alaska $ 12,555 12,655 11,662 Lower 48 26,932 30,185 29,552 Canada 17,221 21,764 22,394 Europe and North Africa 13,703 16,970 18,109 Asia Pacific and Middle East 22,318 25,976 25,473 Other International 282 1,116 819 Corporate and Other 4,473 7,815 8,367 Discontinued operations - 58 1,681 Consolidated total assets $ 97,484 116,539 118,057
Capital Expenditures and Investments	Capital Expenditures and Investments Alaska $ 1,352 1,564 1,140 Lower 48 3,765 6,054 5,210 Canada 1,255 2,340 2,232 Europe and North Africa 1,573 2,540 3,126 Asia Pacific and Middle East 1,812 3,877 3,382 Other International 173 520 265 Corporate and Other 120 190 182 Consolidated capital expenditures and investments $ 10,050 17,085 15,537
Interest Income and Expense	Interest Income and Expense Interest income Corporate $ 36 40 60 Lower 48 - 35 43 Europe and North Africa 2 2 1 Asia Pacific and Middle East 6 6 8 Other International 1 - 1 Interest and debt expense Corporate $ 920 648 532 Canada - - 80
Geographic Information	Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2015 2014 2013 2015 2014 2013 United States $ 16,284 30,019 27,954 37,445 39,641 37,593 Australia (3) 2,127 3,258 3,571 12,788 14,969 13,450 Canada 2,136 4,409 4,647 16,766 20,874 21,380 China 782 1,701 2,120 1,647 1,913 2,143 Indonesia 1,165 1,963 2,083 1,191 1,526 1,780 Malaysia 598 403 281 3,599 3,811 3,406 Norway 2,107 3,794 4,323 6,933 8,142 8,089 United Kingdom 4,005 6,594 7,717 4,154 5,327 5,959 Other foreign countries 360 383 1,717 2,469 3,471 3,364 Worldwide consolidated $ 29,564 52,524 54,413 86,992 99,674 97,164 (1)Sales and other operating revenues are attributable to countries based on the location of the operations generating the revenues. (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 $ 12,830 23,784 24,899 Natural gas 11,888 20,717 22,539 Natural gas liquids 952 2,245 2,111 Other* 3,894 5,778 4,864 Consolidated sales and other operating revenues by product $ 29,564 52,524 54,413 *Includes LNG and bitumen.

Supplementary Information - C55

Supplementary Information - Condensed Consolidating Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Supplementary Information - Condensed Consolidating Financial Information [Abstract]
Condensed Consolidated Income Statement	Millions of Dollars Year Ended December 31, 2015 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 11,473 - 18,091 - 29,564 Equity in earnings 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) Provision (benefit) for income taxes (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) Income Statement Year Ended December 31, 2014 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 Provision (benefit) for income taxes (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 Year Ended December 31, 2013 Income Statement ConocoPhillips ConocoPhillips Company ConocoPhillips Australia Funding Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Revenues and Other Income Sales and other operating revenues $ - 18,186 - - 36,227 - 54,413 Equity in earnings of affiliates 8,374 9,200 - - 2,611 (17,966) 2,219 Gain on dispositions - 364 - - 878 - 1,242 Other income 2 271 - - 101 - 374 Intercompany revenues 82 458 13 305 4,948 (5,806) - Total Revenues and Other Income 8,458 28,479 13 305 44,765 (23,772) 58,248 Costs and Expenses Purchased commodities - 15,779 - - 11,812 (4,948) 22,643 Production and operating expenses - 1,492 - - 5,756 (10) 7,238 Selling, general and administrative expenses 11 623 - 1 238 (19) 854 Exploration expenses - 659 - - 573 - 1,232 Depreciation, depletion and amortization - 907 - - 6,527 - 7,434 Impairments - 4 - - 525 - 529 Taxes other than income taxes - 236 - - 2,648 - 2,884 Accretion on discounted liabilities - 56 - - 378 - 434 Interest and debt expense 630 327 12 235 237 (829) 612 Foreign currency transaction (gains) losses 52 3 - (349) 236 - (58) Total Costs and Expenses 693 20,086 12 (113) 28,930 (5,806) 43,802 Income from continuing operations before income taxes 7,765 8,393 1 418 15,835 (17,966) 14,446 Provision (benefit) for income taxes (213) 19 - 31 6,572 - 6,409 Income From Continuing Operations 7,978 8,374 1 387 9,263 (17,966) 8,037 Income from discontinued operations 1,178 1,178 - - 1,178 (2,356) 1,178 Net income 9,156 9,552 1 387 10,441 (20,322) 9,215 Less: net income attributable to noncontrolling interests - - - - (59) - (59) Net Income Attributable to ConocoPhillips $ 9,156 9,552 1 387 10,382 (20,322) 9,156 Comprehensive Income Attributable to ConocoPhillips $ 7,071 7,467 1 99 7,782 (15,349) 7,071
Schedule of Condensed Balance Sheet	Millions of Dollars At December 31, 2015 Balance Sheet ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated 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 Balance Sheet At December 31, 2014 Assets Cash and cash equivalents $ - 770 7 4,285 - 5,062 Accounts and notes receivable 20 2,813 22 6,671 (2,719) 6,807 Inventories - 281 - 1,050 - 1,331 Prepaid expenses and other current assets 6 754 15 1,138 (45) 1,868 Total Current Assets 26 4,618 44 13,144 (2,764) 15,068 Investments, loans and long-term receivables* 55,568 70,732 3,965 32,467 (137,593) 25,139 Net properties, plants and equipment - 9,730 - 65,714 - 75,444 Other assets 40 67 208 1,338 (765) 888 Total Assets $ 55,634 85,147 4,217 112,663 (141,122) 116,539 Liabilities and Stockholders’ Equity Accounts payable $ 1 4,149 14 6,581 (2,719) 8,026 Short-term debt (5) 6 5 176 - 182 Accrued income and other taxes - 117 - 934 - 1,051 Employee benefit obligations - 595 - 283 - 878 Other accruals 170 337 71 868 (46) 1,400 Total Current Liabilities 166 5,204 90 8,842 (2,765) 11,537 Long-term debt 7,541 8,197 2,974 3,671 - 22,383 Asset retirement obligations and accrued environmental costs - 1,328 - 9,319 - 10,647 Deferred income taxes - 265 - 14,811 (6) 15,070 Employee benefit obligations - 2,162 - 802 - 2,964 Other liabilities and deferred credits* 2,577 7,391 1,142 17,218 (26,663) 1,665 Total Liabilities 10,284 24,547 4,206 54,663 (29,434) 64,266 Retained earnings 37,983 21,448 (1,096) 17,355 (31,186) 44,504 Other common stockholders’ equity 7,367 39,152 1,107 40,283 (80,502) 7,407 Noncontrolling interests - - - 362 - 362 Total Liabilities and Stockholders’ Equity $ 55,634 85,147 4,217 112,663 (141,122) 116,539 *Includes intercompany loans.
Condensed Consolidated Statement of Cash Flows	Millions of Dollars Statement of Cash Flows Year Ended December 31, 2015 ConocoPhillips ConocoPhillips Company ConocoPhillips Canada Funding Company I All Other Subsidiaries Consolidating Adjustments Total Consolidated Cash Flows From Operating Activities Net Cash Provided by (Used in) Operating Activities (225) 245 9 7,519 24 7,572 Cash Flows From Investing Activities Capital expenditures and investments - (3,064) - (8,386) 1,400 (10,050) Working capital changes associated with investing activities - (4) - (964) - (968) Proceeds from asset dispositions 3,500 826 - 1,225 (3,599) 1,952 Long-term advances/loans—related parties - (278) - (2,245) 2,523 - Collection of advances/loans—related parties - - - 205 (100) 105 Intercompany cash management 102 46 - (148) - - Other - 304 - 1 1 306 Net Cash Provided by (Used in) Investing Activities 3,602 (2,170) - (10,312) 225 (8,655) Cash Flows From Financing Activities Issuance of debt - 4,743 - 278 (2,523) 2,498 Repayment of debt - (100) - (103) 100 (103) Issuance of company common stock 283 - - (2) (363) (82) Dividends paid (3,664) - - (339) 339 (3,664) Other 4 (3,484) - 1,204 2,198 (78) Net Cash Provided by (Used in) Financing Activities (3,377) 1,159 - 1,038 (249) (1,429) Effect of Exchange Rate Changes on Cash and Cash Equivalents - - (1) (181) - (182) Net Change in Cash and Cash Equivalents - (766) 8 (1,936) - (2,694) Cash and cash equivalents at beginning of period - 770 7 4,285 - 5,062 Cash and Cash Equivalents at End of Period $ - 4 15 2,349 - 2,368 Statement of Cash Flows Year Ended December 31, 2014* Cash Flows From Operating Activities Net cash provided by 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 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 sales 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 provided by (used in) continuing financing activities (5,058) (31,480) - 944 33,020 (2,574) Net cash used in discontinued operations - - - (335) 335 - Net Cash Provided by (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 *Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to the Consolidated Financial Statements. Millions of Dollars Statement of Cash Flows Year Ended December 31, 2013* ConocoPhillips ConocoPhillips Company ConocoPhillips Australia Funding 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 $ (295) 22,928 (2) 1 14,510 (21,286) 15,856 Net cash provided by discontinued operations - 91 - - 642 (448) 285 Net Cash Provided by (Used in) Operating Activities (295) 23,019 (2) 1 15,152 (21,734) 16,141 Cash Flows From Investing Activities Capital expenditures and investments - (4,821) - - (13,566) 2,850 (15,537) Working capital changes associated with investing activities - 68 - - (123) - (55) Proceeds from asset dispositions - 2,633 - - 9,745 (2,158) 10,220 Net purchases of short-term investments - - - - (263) - (263) Long-term advances/loans—related parties - (342) - - (545) 887 - Collection of advances/loans—related parties - 174 750 169 3,010 (3,958) 145 Intercompany cash management 2,511 (15,919) - - 13,408 - - Other - 21 - - (233) - (212) Net cash provided by (used in) continuing investing activities 2,511 (18,186) 750 169 11,433 (2,379) (5,702) Net cash used in discontinued operations - (52) - - (603) 52 (603) Net Cash Provided by (Used in) Investing Activities 2,511 (18,238) 750 169 10,830 (2,327) (6,305) Cash Flows From Financing Activities Issuance of debt - 522 - - 365 (887) - Repayment of debt - (2,924) (750) - (1,230) 3,958 (946) Change in restricted cash 748 - - - - - 748 Issuance of company common stock 365 - - - - (345) 20 Dividends paid (3,334) - (4) - (21,984) 21,988 (3,334) Other 3 52 - - (2,984) (692) (3,621) Net cash used in continuing financing activities (2,218) (2,350) (754) - (25,833) 24,022 (7,133) Net cash used in discontinued operations - - - - (39) 39 - Net Cash Used in Financing Activities (2,218) (2,350) (754) - (25,872) 24,061 (7,133) Effect of Exchange Rate Changes on Cash and Cash Equivalents - (9) - - (66) - (75) Net Change in Cash and Cash Equivalents (2) 2,422 (6) 170 44 - 2,628 Cash and cash equivalents at beginning of period 2 12 6 59 3,539 - 3,618 Cash and Cash Equivalents at End of Period $ - 2,434 - 229 3,583 - 6,246 *Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to the Consolidated Financial Statements.

Schedule II (Tables)

Schedule II (Tables)	12 Months Ended
	Dec. 31, 2015
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 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 2013 Deducted from asset accounts: Allowance for doubtful accounts and notes receivable $ 10 - - (2) (b) 8 Deferred tax asset valuation allowance 1,345 (357) 3 (22) 969 Included in other liabilities: Restructuring accruals 17 10 (1) (7) (c) 19 (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, 2015
Accounting Policies Textual [Abstract]
Number of Operating Segments	6

Discontinued Operations (Detail

Discontinued Operations (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Sales and other operating revenues and income (loss) from discontinued operations
Income tax expense (benefit)		$ 0	$ 16	$ 283
Income from discontinued operations	[1]	$ 0	1,131	1,178
Kashagan, Algeria and Nigeria [Member]
Sales and other operating revenues and income (loss) from discontinued operations
Sales and other operating revenues from discontinued operations			480	1,185
Discontinued operation, income			1,147	1,461
Income tax expense (benefit)			16	283
Income from discontinued operations			$ 1,131	$ 1,178
[1]	Net of provision for income taxes on discontinued operations of: $0, $16, $283

Discontinued Operations - Textu

Discontinued Operations - Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Other Discontinued Operations [Abstract]
Deposit	$ 550
Kashagan [Member]
Other Discontinued Operations [Abstract]
Ownership percentage in equity investment	8.40%
Proceeds from asset dispositions		$ 5,392
Gain on sale, before tax		22
Carrying value at disposal		5,370
Other current assets at disposal		212
Long-term receivables at disposal		239
Amount of PP&E in carrying value of asset		5,149
Other current liabilities at disposal		144
Asset retirement obligation at disposal		86
Algeria [Member]
Other Discontinued Operations [Abstract]
Deposit		0
Proceeds from asset dispositions		1,652
Gain on sale, before tax		938
Carrying value at disposal		714
Other current assets at disposal		48
Amount of PP&E in carrying value of asset		883
Other current liabilities at disposal		41
Amount of deferred taxes in carrying value of asset		139
Asset retirement obligation at disposal		37
Nigeria Upstream Affiliates [Member]
Other Discontinued Operations [Abstract]
Deposit	$ 100	$ 15	$ 435
Deferred income taxes	825
Proceeds from asset dispositions	1,359
Gain on sale, before tax	1,052
Carrying value at disposal	307
Other current assets at disposal	233
Amount of PP&E in carrying value of asset	1,211
Other current liabilities at disposal	298
Asset retirement obligation at disposal	$ 14

Inventories (Details)

Inventories (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Inventories
Crude oil and natural gas	$ 406	$ 538
Materials, supplies and other	718	793
Total Inventories	1,124	1,331
Inventories (Textual) [Abstract]
Inventories valued on the LIFO basis	317	440
Excess of current replacement cost over LIFO cost of inventories	6	$ 6
Effect of LIFO Inventory Liquidation on Income	25
Lower of cost or market write down	$ 44

Assets Held for Sale or Sold (D

Assets Held for Sale or Sold (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2013
Cedar Creek Anticline [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions		$ 994
Gain (Loss) on Sale of Oil and Gas Property		(43)
Net carrying value		1,037
Amount of PP&E in carrying value of asset		1,066
Asset retirement obligation at disposal		28
Browse And Canning Basins [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions		402
Amount of PP&E in carrying value of asset		486
Clyden [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions		724
Gain (Loss) on Sale of Oil and Gas Property		614
Net carrying value		$ 110
Phoenix Park Gas Processors Limited [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Equity Method Investment, Ownership Percentage		39.00%
Equity Method Investment Sales Proceeds		$ 593
Carrying Value of Equity Investment Sold		176
Gain (Loss) on sale of equity investment		$ 417
western Canadian Properties [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions	$ 198
Gain (Loss) on Sale of Oil and Gas Property	66
Net carrying value	132
Amount of PP&E in carrying value of asset	379
Asset retirement obligation at disposal	248
western Canadian Properties Alberta [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions	130
Gain (Loss) on Sale of Oil and Gas Property	(235)
Net carrying value	365
Amount of PP&E in carrying value of asset	488
Asset retirement obligation at disposal	126
east Texas North Louisiana [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions	412
Gain (Loss) on Sale of Oil and Gas Property	189
Net carrying value	223
Amount of PP&E in carrying value of asset	351
Asset retirement obligation at disposal	128
South Texas Properties [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions	358
Gain (Loss) on Sale of Oil and Gas Property	201
Net carrying value	157
Amount of PP&E in carrying value of asset	369
Asset retirement obligation at disposal	212
Texas Pipeline Gathering Assets [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Proceeds from asset dispositions	201
Gain (Loss) on Sale of Oil and Gas Property	193
Net carrying value	8
Amount of PP&E in carrying value of asset	24
Asset retirement obligation at disposal	$ 18
PolarLightsCompany [Member]
Assets Held for Sale or Sold (Textual) [Abstract]
Equity Method Investment, Ownership Percentage	50.00%
Equity Method Investment Sales Proceeds	$ 98
Carrying Value of Equity Investment Sold	40
Gain (Loss) on sale of equity investment	$ 58

Investments, Loans and LT Recei

Investments, Loans and LT Receivables Components (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Components of investments, loans and long-term receivables
Equity investments	$ 19,850	$ 23,426
Loans and advances-related parties	696	804
Long-term receivables	519	444
Other investments	121	465
Total	$ 21,186	$ 25,139

Investments, Loans and LT Rec63

Investments, Loans and LT Receivables - Financial Info (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Summarized financial information for equity method investments in affiliated companies
Revenues	$ 11,003	$ 19,243	$ 18,035
Income before income taxes	1,866	6,746	6,384
Net income	1,801	6,630	$ 6,125
Current assets	2,504	4,512
Noncurrent assets	58,431	58,570
Current liabilities	1,863	3,346
Noncurrent liabilities	$ 24,820	$ 20,210

Investments, Loans and LT Rec64

Investments, Loans and LT Receivables Textuals (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)ft3 / D	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)
Schedule of Equity Method Investments [Line Items]
Undistributed earnings of affiliates in retained earnings	$ 1,323
Dividends received from affiliates	876	$ 2,648	$ 1,425
Book value of equity method investment	19,850	23,426
Cumulative translation effect	(5,804)	(641)	$ 2,826	$ 5,512
Equity Method Investment, Other than Temporary Impairment	$ 1,507
Australia Pacific APLNG [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment	37.50%		42.50%
Gain (Loss) on sale of equity investment			$ 133
Carrying Value of Equity Investment Sold			453
Reduction in currency translation adjustment associated with investment			320
Project finance facility				8,500
Book value of equity method investment	$ 10,185
Cumulative translation effect	1,522
Historical cost basis	7,470
Difference between estimated value and book value of equity method investment	2,715
Annual amortization of basis difference	21	24	$ 16
Amount drawn from project finance facility	8,400
Equity Method Investment, Other than Temporary Impairment	$ 1,502
Number of APLNG Long-term Sales and Purchase Agreements	2
Australia Pacific APLNG [Member] | Export-Import Bank of US [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility				2,900
Australia Pacific APLNG [Member] | Export-Import Bank of China [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility				2,700
Australia Pacific APLNG [Member] | Australian and International Commercial Bank Syndicate [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility				$ 2,900
Australia Pacific APLNG [Member] | Origin Energy [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	37.50%		42.50%
Australia Pacific APLNG [Member] | Sinopec [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	25.00%		15.00%
FCCL [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment	50.00%
Dividends received from affiliates		1,300
Book value of equity method investment	$ 8,165
Cumulative translation effect	$ 1,955
Initial acquisition obligation to joint venture			$ 7,500
Fixed annual interest rate			5.30%
Payoff of remaining balance of obligation			$ 2,810
FCCL [Member] | Cenovus Energy Inc. [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	50.00%
QG 3 [Member]
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment	30.00%
Project finance facility	$ 4,000
Book value of equity method investment	808
Loans to related parties - project financing	$ 804
Percentage of interest in terminal and pipeline use agreements	12.40%
QG 3 [Member] | Export credit agencies [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility	$ 1,300
QG 3 [Member] | Commerical Banks [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility	1,500
QG 3 [Member] | Conoco Philips [Member]
Schedule of Equity Method Investments [Line Items]
Project finance facility	$ 1,200
QG 3 [Member] | Qatar Petroleum [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	68.50%
QG 3 [Member] | Mitsui & Co, Ltd. [Member]
Schedule of Equity Method Investments [Line Items]
Equity Interest Of Others	1.50%
Freeport LNG [Member]
Schedule of Equity Method Investments [Line Items]
Loans to related parties - project financing		$ 454
Previous long-term Agreement to Use Regasification Capacity Cubic Feet Per Day | ft3 / D		900,000,000
Termination Payment		$ 522
After Tax Charge		540
Termination Cash Outflow		$ 63
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%

Suspended Wells Net Changes in

Suspended Wells Net Changes in Well Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Net changes in suspended Exploratory well costs
Beginning balance	$ 1,299	$ 994	[1]	$ 1,038
Additions pending the determination of proved reserves	331	478		466
Reclassifications to proved properties	(28)	(9)		(29)
Sales of suspended well investment	0	(57)		(481)
Charged to dry hole expense	(342)	(107)		0
Ending balance	1,260	1,299		$ 994	[1]
Assets Held for Sale [Line Items]
Capitalized exploratory well costs in assets held for sale	$ 57	190
Kazakhstan [Member]
Assets Held for Sale [Line Items]
Capitalized exploratory well costs in assets held for sale		133
Nigeria [Member]
Assets Held for Sale [Line Items]
Capitalized exploratory well costs in assets held for sale		$ 57
[1]	*Includes $57 million of assets that were held for sale in Nigeria.

Suspended Wells - Aging of susp

Suspended Wells - Aging of suspended well balances (Details) $ in Millions	Dec. 31, 2015USD ($)numberofprojects	Dec. 31, 2014USD ($)numberofprojects	Dec. 31, 2013USD ($)numberofprojects		Dec. 31, 2012USD ($)
Aging of suspended well cost
Exploratory well costs capitalized for a period of one year or less	$ 235	$ 466	$ 437
Exploratory well costs capitalized for a period greater than one year	1,025	833	557
Ending balance	$ 1,260	$ 1,299	$ 994	[1]	$ 1,038
Number of projects that have exploratory well costs that have been capitalized for a period greater than one year | numberofprojects	28	30	29
[1]	*Includes $57 million of assets that were held for sale in Nigeria.

Suspended Wells-Exploratory Cap

Suspended Wells-Exploratory Capitalized Well Costs (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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		$ 1,025	$ 833	$ 557
2012-2014 [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		734
2009-2011 [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		142
2002-2008 [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		149
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] | 2012-2014 [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]	165
Greater Poseidon-Australia [Member] | 2009-2011 [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]	12
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] | 2002-2008 [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
FAN-Senegal [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]	117
FAN-Senegal [Member] | 2012-2014 [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]	117
FAN-Senegal [Member] | 2009-2011 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year		0
FAN-Senegal [Member] | 2002-2008 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year		0
Fiord West-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	[1]	16
Fiord West-Alaska [Member] | 2009-2011 [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
Fiord West-Alaska [Member] | 2002-2008 [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]	16
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]	127
Greater Clair-UK [Member] | 2012-2014 [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]	113
Greater Clair-UK [Member] | 2009-2011 [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]	14
Greater Clair-UK [Member] | 2002-2008 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year		0
Kamunsu East-Malaysia
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year	[1]	19
Kamunsu East-Malaysia | 2012-2014 [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
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 | 2012-2014 [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
NC 98-Libya [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
NC 98-Libya [Member] | 2012-2014 [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 [Member] | 2009-2011 [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 [Member] | 2002-2008 [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
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] | 2012-2014 [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] | 2009-2011 [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]	17
NPR-A-Alaska [Member] | 2002-2008 [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]	6
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]	94
Shenandoah-Lower 48 [Member] | 2012-2014 [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]	51
Shenandoah-Lower 48 [Member] | 2009-2011 [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
Shenandoah-Lower 48 [Member] | 2002-2008 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year		0
SNE-Senegal [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
SNE-Senegal [Member] | 2012-2014 [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
SNE-Senegal [Member] | 2009-2011 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year		0
SNE-Senegal [Member] | 2002-2008 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year		0
Sunrise-Australia[Member]
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] | 2012-2014 [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] | 2009-2011 [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] | 2002-2008 [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
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]	89
Surmont 3 and beyond-Canada [Member] | 2012-2014 [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]	58
Surmont 3 and beyond-Canada [Member] | 2009-2011 [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]	14
Surmont 3 and beyond-Canada [Member] | 2002-2008 [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]	17
Tiber-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]	100
Tiber-Lower 48 [Member] | 2012-2014 [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]	60
Tiber-Lower 48 [Member] | 2009-2011 [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]	40
Tiber-Lower 48 [Member] | 2002-2008 [Member]
Aging of exploratory well costs that have been capitalized for more than one year
Aging of Exploratory Well Cost that have been capitalized for more than one year		0
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]	42
Other of $10 million or less each [Member] | 2012-2014 [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]	24
Other of $10 million or less each [Member] | 2009-2011 [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]	2
Other of $10 million or less each [Member] | 2002-2008 [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]	$ 16
[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	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	$ 4,192	$ 2,045	$ 1,232
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 drill ship capitalized rig costs [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	48
Angola Block 36 [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	$ 93

Impairments (Details)

Impairments (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Impairment charges by segment, before-tax
Asset Impairment Charges		$ 2,245	$ 856	$ 529
Exploration expenses		4,192	2,045	1,232
Alaska [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges		10	59	3
Chukchi [Member]
Impairment charges by segment, before-tax
Exploration expenses		575
Lower 48 [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges		(2)	208	2
Exploration expenses			239
Gulf of Mexico [Member]
Impairment charges by segment, before-tax
Exploration expenses		240
Gila [Member]
Impairment charges by segment, before-tax
Exploration expenses		159
Canada [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges		4	38	216
Exploration expenses			145
Duvernay Thornbury Saleski Crow Lake [Member]
Impairment charges by segment, before-tax
Exploration expenses		102
Europe and North Africa
Impairment charges by segment, before-tax
Asset Impairment Charges		724	541	301
Asia Pacific and Middle East [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges		1,508	7	3
Palangkaraya [Member]
Impairment charges by segment, before-tax
Exploration expenses		105
Block 37 and Block 36 [Member]
Impairment charges by segment, before-tax
Exploration expenses	$ 116	377
Corporate [Member]
Impairment charges by segment, before-tax
Asset Impairment Charges		$ 1	$ 3	$ 4

Asset Retirement Obligations 70

Asset Retirement Obligations and Accrued Environmental Costs (Details) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset retirement obligations and accrued environmental costs
Asset retirement obligations		$ 9,911	$ 10,939	$ 10,076
Accrued environmental costs		258	344
Total asset retirement obligations and accrued environmental costs		10,169	11,283
Asset retirement obligations and accrued environmental costs due within one year	[1]	(589)	(636)
Long-term asset retirement obligations and accrued environmental costs		$ 9,580	10,647
Asset retirement obligations and accrued environmental costs due within one year that are held for sale			$ 14
[1]	*Classified as a current liability on the balance sheet under "Other accruals."

Asset Retirement Obligations 71

Asset Retirement Obligations and Accrued Environmental Costs - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Changes in overall asset retirement obligation changed
Balance at	$ 10,939	$ 10,076
Accretion of discount	480	479
New obligations	135	368
Changes in estimates of existing obligations	267	1,175
Spending on existing obligations	(437)	(365)
Property dispositions	(726)	(20)
Foreign currency translation	(747)	(774)
Balance at	$ 9,911	$ 10,939

Asset Retirement Obligations 72

Asset Retirement Obligations and Accrued Environmental Costs - Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Environmental Liabilities [Line Items]
Accrued environmental costs	$ 258	$ 344
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	$ 12
Accrued environmental costs, undiscounted due within second year	13
Accrued environmental costs, undiscounted due within three year	9
Accrued environmental costs, undiscounted due within fourth year	6
Accrued environmental costs, undiscounted due within fifth year	4
Accrued environmental costs, undiscounted due after fifth year	117
Cleanup Remediation Activities [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	184	250
Corporate and Other Environmental Liabilities [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	57	79
Federal Comprehensive Environmental Response Compensation and Liability Act or Similar State Laws [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	17	$ 15
Acquired Environmental Obligations [Member]
Environmental Liabilities [Line Items]
Discounted accrued environmental costs	$ 105

Debt (Details)

Debt (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Long-term debt
Debt at face value	$ 23,778	$ 21,335
Capitalized leases	818	858
Net unamortized premiums and discounts	284	372
Total debt	24,880	22,565
Short-term debt	(1,427)	(182)
Long-term debt	23,453	22,383
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	$ 2,250	$ 2,250
Debt (Additional Textual) [Abstract]
Stated percentage of debt	6.50%	6.50%
6.50% Notes due 2039 [Member]
Long-term debt
Debt at face value	$ 500	$ 500
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%
5.90% 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	$ 1,250	$ 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%
4.3% 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%
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
Debt (Additional Textual) [Abstract]
Stated percentage of debt	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
Debt (Additional Textual) [Abstract]
Stated percentage of debt	2.20%
1.5% Notes due 2018 [Member]
Long-term debt
Debt at face value	$ 750
Debt (Additional Textual) [Abstract]
Stated percentage of debt	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 notes due 2018 at 0.61% - 0.69% during 2015 [Member]
Long-term debt
Debt at face value	$ 250
Debt (Additional Textual) [Abstract]
Stated percentage of debt minimum	0.606%
Stated percentage of debt maximum	0.692%
Floating rate notes due 2022 at 1.18% - 1.26% during 2015 [Member]
Long-term debt
Debt at face value	$ 500
Debt (Additional Textual) [Abstract]
Stated percentage of debt minimum	1.176%
Stated percentage of debt maximum	1.262%
Commercial paper at 0.16% - 0.80% at year-end 2015 and 0.14% - 0.21% at year-end 2014 [Member]
Long-term debt
Debt at face value	$ 803	$ 860
Debt (Additional Textual) [Abstract]
Stated percentage of debt minimum	0.16%	0.14%
Stated percentage of debt maximum	0.80%	0.21%
Industrial Development Bonds due 2015 through 2038 at 0.01% - 0.13% at year-end 2015 and 0.02% - 0.13% at year-end 2014
Long-term debt
Debt at face value	$ 18	$ 18
Debt (Additional Textual) [Abstract]
Stated percentage of debt minimum	0.01%	0.02%
Stated percentage of debt maximum	0.13%	0.13%
Marine Terminal Revenue Refunding Bonds due 2031 at 0.01% - 0.14% at year-end 2015 and 0.02% - 0.15% at year-end 2014
Long-term debt
Debt at face value	$ 265	$ 265
Debt (Additional Textual) [Abstract]
Stated percentage of debt minimum	0.01%	0.02%
Stated percentage of debt maximum	0.14%	0.15%
Other Debt [Member]
Long-term debt
Debt at face value	$ 24	$ 24

Debt Capital Lease (Details 2)

Debt Capital Lease (Details 2) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Capital lease obligations
2,016	$ 91
2,017	76
2,018	76
2,019	76
2,020	76
Remaining years	648
Capital lease payments	1,043
Less portion representing imputed interest	(225)
Capital Lease Obligations, Total	$ 818	$ 858

Debt (Details Textual)

Debt (Details Textual) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2013	Dec. 31, 2014
Debt (Textual) [Abstract]
Maturities of long-term borrowings in 2016	$ 1,427
Maturities of long-term borrowings in 2017	1,081
Maturities of long-term borrowings in 2018	1,859
Maturities of long-term borrowings in 2019	3,014
Maturities of long-term borrowings in 2020	1,576
Classification of short-term debt as long-term debt	695
Capital Leased Assets [Line Items]
Capital lease obligations	$ 818		$ 858
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 under revolving credit facilities	$ 340
Credit facilities remaining after commercial paper outstanding and issuance of letters of credit	6,200
Debt Instrument [Line Items]
Debt Instrument, Face Amount	23,778		$ 21,335
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	707	$ 906	802
Capital Leases Other Accumulated Depreciation	122		20
1.5% Notes due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 750
Stated percentage of debt	1.50%
Floating rate notes due 2018 at 0.61% - 0.69% during 2015 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 250
Floating Rate Notes	three-month LIBOR, plus 0.33%
2.2% Notes due 2020 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 500
Stated percentage of debt	2.20%
Floating rate notes due 2022 at 1.18% - 1.26% during 2015 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 500
Floating Rate Notes	three-month LIBOR, plus 0.90%
3.35% Notes due 2025 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	$ 500
Stated percentage of debt	3.35%
ConocoPhillips [Member]
Short-term Debt [Line Items]
Commercial paper program	$ 6,100
ConocoPhillips Qatar Funding Ltd. [Member]
Short-term Debt [Line Items]
Commercial paper program	900
Commercial paper outstanding	803		$ 860
Under Revolving Credit Facilities [Member]
Short-term Debt [Line Items]
Revolving credit facilities	7,000
Letters of credit outstanding	500
Minimum limit of debt for cross default provision	200
Letters of credit issued under revolving credit facilities	$ 0

Guarantees (Details)

Guarantees (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)	Dec. 31, 2013
Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Ownership percentage in equity investment	37.50%	42.50%
Train 1 and Train 2 [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 110
Terms of Guarantees Outstanding	one year
Construction completion guarantee [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 3,200
Maximum potential amount of future payments - based on pro-rata share	3,200
Carrying value of the guarantee to third-party lenders	114
Continued development [Member] | Australia Pacific APLNG [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 160
Terms of Guarantees Outstanding	up to 30 years or the life of the venture
Other Guarantees [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 590
Terms of Guarantees Outstanding	up to eight years or the life of the venture
Number Of Joint Ventures Backed By Guarantee	1
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	90
Indemnification [Member] | Refinery Supplier [Member]
Guarantees (Textual) [Abstract]
Maximum potential amount of future payments	$ 1,600
Terms of Guarantees Outstanding	nine 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	$ 1,800
Terms of Guarantees Outstanding	1 to 26 years

Contingencies and Commitments (

Contingencies and Commitments (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Contingencies and Commitments (Textual) [Abstract]
Letters of Credit Outstanding, Amount	$ 340
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	27
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Second Year	27
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Third Year	22
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	80
Total payments under Long-Term Throughput Agreements and Take-or-Pay Agreements	$ 27	$ 127	$ 127

Derivative and Financial Inst78

Derivative and Financial Instruments - Commodity Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	$ 768	$ 4,500
Other assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	60	157
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	754	4,426
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	$ 46	$ 144

Derivative and Financial Inst79

Derivative and Financial Instruments - Commodity GainLoss (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Sales and other operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ 231	$ 523	$ (160)
Other Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	2	1	4
Purchased commodities [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (201)	$ (458)	$ 139

Derivative and Financial Inst80

Derivative and Financial Instruments - Commodity Notional (Details 2) pure in Billions	Dec. 31, 2015	Dec. 31, 2014
Natural gas and power, Fixed price [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	(14)	(11)
Natural gas and power, Basis [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	(17)	18

Derivative and Financial Inst81

Derivative and Financial Instruments - FX Balance Sheet (Details 3) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	$ 47	$ 1
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative liabilities	$ 8	$ 1

Derivative and Financial Inst82

Derivative and Financial Instruments - FX GainLoss (Details 4) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Foreign currency transaction (gains) losses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Foreign currency transaction (gains) losses	$ (33)	$ 3	$ 4

Derivative and Financial Inst83

Derivative and Financial Instruments - FX Notional (Details 5) - Foreign Exchange Contract [Member] - Not Designated as Hedging Instrument [Member] - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014
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]	$ 347	$ 7
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]	20	44
Buy British pound, sell other currencies [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Net notional position of foreign currency exchange derivatives	[3]	$ 567	$ 20
[1]	*Primarily Canadian dollar, Norwegian krone and British pound.
[2]	**Primarily Canadian dollar and Norwegian krone.
[3]	***Primarily Canadian dollar and euro.

Derivative and Financial Inst84

Derivative and Financial Instruments - Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	[1]	Dec. 31, 2012	[1]
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents, at Carrying Value, Total	$ 2,368	$ 5,062	$ 6,246		$ 3,618
Cash and Cash Equivalents [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash	528	946
Money Market Funds At Carrying Value		50
Time Deposits	$ 1,840	3,726
Commercial Paper		$ 340
[1]	*Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to Consolidated Financial Statements.

Derivative and Financial Inst85

Derivative and Financial Instruments - Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Schedule of Credit Risk [Line items]
Collateral was posted for derivative instruments in a liability position	$ 2	$ 0
Aggregate fair value of all derivative instruments in a liability position	$ 158	$ 150
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	$ 156
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	$ 0

Fair Value Measurement - FV Hie

Fair Value Measurement - FV Hierarchy (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative asset, gross	$ 828	$ 4,657
Commodity derivative liability, gross	800	4,570
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Deferred compensation investments	21	297
Commodity derivative asset, gross	828	4,657
Total assets	849	4,954
Commodity derivative liability, gross	800	4,570
Total liabilities	800	4,570
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Deferred compensation investments	21	297
Commodity derivative asset, gross	516	4,221
Total assets	537	4,518
Commodity derivative liability, gross	515	4,200
Total liabilities	515	4,200
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	242	361
Total assets	242	361
Commodity derivative liability, gross	273	354
Total liabilities	273	354
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	70	75
Total assets	70	75
Commodity derivative liability, gross	12	16
Total liabilities	$ 12	$ 16

Fair Value Measurement - FV of

Fair Value Measurement - FV of Commodity Derivatives (Details 1) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Offsetting Derivative Assets [Abstract]
Assets - gross amounts recognized	$ 828	$ 4,657
Assets - gross amounts offset	600	4,352
Assets - net amounts presented	228	305
Assets - cash collateral	0	8
Assets - amounts without right of setoff	8	28
Assets - net amounts	220	269
Offsetting Derivative Liabilities [Abstract]
Liabilities - gross amounts recognized	800	4,570
Liabilities - gross amounts offset	600	4,352
Liabilities - net amounts presented	200	218
Liabilities - cash collateral	1	4
Liabilities - amounts without right of setoff	11	22
Liabilities - net amounts	$ 188	$ 192

Fair Value Measurement - Nonrec

Fair Value Measurement - Nonrecurring (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for use)	[1]	$ 440	$ 87
Before-Tax Loss - Net PP&E (held for use)		681	756
Fair Value - Net PP&E (unproved property)	[1]	104	39
Before-Tax Loss - Net PP&E (unproved propery)		240	158
Fair Value - Equity Method Investments	[1]	10,210
Equity method investments, before tax loss		1,507
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)		440	87
Fair Value - Net PP&E (unproved property)		104	$ 39
Fair Value - Equity Method Investments		$ 10,210
[1]	*Represents the fair value at the time of the impairment.

Fair Value Measurement - Fair V

Fair Value Measurement - Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Financial Assets
Commodity derivatives, assets	$ 220	$ 269
Financial Liabilities
Commodity derivatives, liability	188	192
Carrying (Reported) Amount, Fair Value Disclosure [Member]
Financial Assets
Deferred compensation investments	21	297
Commodity derivatives, assets	228	297
Loans to related parties - project financing	808	913
Financial Liabilities
Total debt, excluding capital leases, carrying amount	24,062	21,707
Commodity derivatives, liability	199	214
Deferred Compensation Liquidation [Member]
Financial Assets
Deferred compensation investments	267
Portion at Fair Value, Fair Value Disclosure [Member]
Financial Assets
Deferred compensation investments	21	297
Commodity derivatives, assets	228	297
Loans to related parties - project financing	808	913
Financial Liabilities
Total debt, excluding capital leases, fair value	24,785	25,191
Commodity derivatives, liability	$ 199	$ 214

Fair Value Measurement - Textua

Fair Value Measurement - Textuals (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Financial Instruments and Derivative Contracts (Textual) [Abstract]
Obligations to return cash collateral	$ 0	$ 8
Rights to reclaim cash collateral	$ 1	$ 4

Equity - changes in shares of c

Equity - changes in shares of common stock (Details) - shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Common Stock [Member]
Changes in shares of common stock
Beginning Balance, Common Stock	1,773,583,368	1,768,169,906	1,762,247,949
Distributed under benefit plans	4,643,020	5,413,462	5,921,957
Ending Balance, Common Stock	1,778,226,388	1,773,583,368	1,768,169,906
Treasury Stock [Member]
Changes in shares of common stock
Beginning Balance, Common Stock	0	0	0
Repurchase of common stock			0
Distributed under benefit plans			0
Ending Balance, Common Stock	0	0	0

Equity - Textuals (Details)

Equity - Textuals (Details) - USD ($) $ / shares in Units, $ in Millions	Dec. 31, 2015	Dec. 31, 2014
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	$ 320	$ 362

Non Mineral Leases (Details)

Non Mineral Leases (Details) $ in Millions	Dec. 31, 2015USD ($)
Future minimum rental payments due under noncancelable leases
2,016	$ 671
2,017	360
2,018	215
2,019	156
2,020	374
Remaining Years	381
Total	2,157
Less income from subleases	(9)
Net Minimum Operating Lease Payments	$ 2,148

Non-Mineral Leases - Operating

Non-Mineral Leases - Operating lease rental (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating lease rental expense
Total rentals	$ 432	$ 474	$ 317	[1]
Less sublease rentals	(9)	(10)	(12)
Operating Leases, Rent Expense, Total	$ 423	$ 464	$ 305
[1]

Employee Benefit Plans - Change

Employee Benefit Plans - Change in Benefit Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
United States Pension Plans of US Entity, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	$ 4,387	[1]	$ 3,954
Service cost	138		124		$ 138
Interest cost	161		165		143
Actuarial (gain) loss	(212)		477
Benefits paid	(729)		(333)
Defined Benefit Plan, Curtailments	27
Benefit obligation at December 31	3,772	[1]	4,387	[1]	3,954
Accumulated benefit at year end	3,573		3,957
Foreign Pension Plans, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	3,984	[1]	3,583
Service cost	124		109		102
Interest cost	135		166		145
Plan participant contributions	5		6
Actuarial (gain) loss	(442)		598
Benefits paid	(162)		(122)
Defined Benefit Plan, Curtailments	(43)
Recognition of termination benefits	68
Foreign currency exchange rate change	(348)		(356)
Benefit obligation at December 31	3,321	[1]	3,984	[1]	3,583
Accumulated benefit at year end	2,953		3,111
Other Postretirement Benefit Plans, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	716		682
Service cost	4		3		3
Interest cost	22		29		26
Plan participant contributions	21		21
Plan amendments	(303)
Actuarial (gain) loss	(49)		53
Benefits paid	(63)		(70)
Defined Benefit Plan, Curtailments	8
Foreign currency exchange rate change	(4)		(2)
Benefit obligation at December 31	$ 352		$ 716		$ 682
[1]	*Accumulated benefit obligation portion of above at December 31: $3,573, $2,953, $3,957, $3,111

Employee Benefit Plans - Chan96

Employee Benefit Plans - Change in Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
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	$ 3,266	$ 3,092
Actual return on plan assets	(4)	234
Company contributions	73	273
Benefits paid	(729)	(333)
Fair value of plan assets at December 31	2,606	3,266
Funded Status	(1,166)	(1,121)
Foreign Pension Plans, Defined Benefit [Member]
Change in Fair Value of Plan Assets
Fair value of plan assets at January 1	3,278	3,132
Actual return on plan assets	96	410
Company contributions	120	203
Plan participant contributions	5	6
Benefits paid	(162)	(122)
Foreign currency exchange rate change	(274)	(351)
Fair value of plan assets at December 31	3,063	3,278
Funded Status	(258)	(706)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Change in Fair Value of Plan Assets
Company contributions	42	49
Plan participant contributions	21	21
Benefits paid	(63)	(70)
Funded Status	$ (352)	$ (716)

Employee Benefit Plans - Amount

Employee Benefit Plans - Amounts recognized in Balance Sheet And Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent liabilities	$ (2,286)	$ (2,964)
United States Pension Plans of US Entity, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Current liabilities	(99)	(26)
Noncurrent liabilities	(1,067)	(1,095)
Total recognized	$ (1,166)	$ (1,121)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	4.50%	3.80%
Rate of compensation increase	4.00%	4.75%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	4.00%	4.40%
Expected return on plan assets	7.00%	7.00%
Rate of compensation increase	4.75%	4.75%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 773	$ 1,146
Unrecognized prior service cost (credit)	9	16
Foreign Pension Plans, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent assets	175	13
Current liabilities	(34)	(9)
Noncurrent liabilities	(399)	(710)
Total recognized	$ (258)	$ (706)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.95%	3.55%
Rate of compensation increase	4.05%	4.35%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	3.55%	4.75%
Expected return on plan assets	5.40%	5.75%
Rate of compensation increase	4.35%	4.60%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 273	$ 852
Unrecognized prior service cost (credit)	(30)	(43)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Current liabilities	(45)	(49)
Noncurrent liabilities	(307)	(667)
Total recognized	$ (352)	$ (716)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	3.90%	4.15%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	4.05%	4.45%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ (18)	$ 25
Unrecognized prior service cost (credit)	$ (292)	$ (4)

Employee Benefit Plans - Source

Employee Benefit Plans - Sources of Change in Other Comprehensive Income (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015		Dec. 31, 2014	Dec. 31, 2013
Sources of change in other comprehensive income
Net actuarial gain (loss) arising during the period		$ 592		$ (840)	$ 688
Amortization of (gain) loss included in income		403		131	294
Prior service (cost) credit arising during the period		301		(3)	1
Reclassification adjustment for amortization of prior service cost included in net income		(19)		(6)	$ (5)
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		61		(456)
Amortization of (gain) loss included in income		312	[1]	77
Net change during the period		373		(379)
Reclassification adjustment for amortization of prior service cost included in net income		7		6
Net change during the period		7		6
Amounts included in accumulated other comprehensive income that are expected to be amortized into net periodic postretirement cost
Unrecognized net actuarial loss (gain)		78
Unrecognized prior service cost (credit)		5
Foreign Pension Plans, Defined Benefit [Member]
Sources of change in other comprehensive income
Net actuarial gain (loss) arising during the period		490		(331)
Amortization of (gain) loss included in income	[1]	89		57
Net change during the period		579		(274)
Prior service (cost) credit arising during the period		(2)		(3)
Reclassification adjustment for amortization of prior service cost included in net income		(11)		(8)
Net change during the period		(13)		(11)
Amounts included in accumulated other comprehensive income that are expected to be amortized into net periodic postretirement cost
Unrecognized net actuarial loss (gain)		30
Unrecognized prior service cost (credit)		(6)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Sources of change in other comprehensive income
Net actuarial gain (loss) arising during the period		41		(53)
Amortization of (gain) loss included in income		2	[1]	(3)
Net change during the period		43		(56)
Prior service (cost) credit arising during the period		303
Reclassification adjustment for amortization of prior service cost included in net income		(15)		(4)
Net change during the period		288		$ (4)
Amounts included in accumulated other comprehensive income that are expected to be amortized into net periodic postretirement cost
Unrecognized net actuarial loss (gain)		(2)
Unrecognized prior service cost (credit)		(34)
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 2015.

Employee Benefit Plans - Compon

Employee Benefit Plans - Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net periodic benefit cost of all defined benefit plans
Settlements	$ 204		$ 67
Curtailments (gain) loss	33
Special pension termination benefits	$ 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	$ 138	$ 124	138
Interest cost	161	165	143
Expected return on plan assets	(201)	(213)	(186)
Amortization of prior service cost (credit)	6	6	6
Recognized net actuarial loss (gain)	115	77	151
Settlements	197	0	67
Curtailments (gain) loss	35
Net periodic benefit cost	451	159	319
Special pension termination benefits	$ 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	6.75%
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	3.00%
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	$ 124	109	102
Interest cost	135	166	145
Expected return on plan assets	(164)	(181)	(160)
Amortization of prior service cost (credit)	(7)	(8)	(7)
Recognized net actuarial loss (gain)	82	57	73
Settlements	7
Curtailments (gain) loss	(4)
Net periodic benefit cost	173	143	153
Europe [Member]
Net periodic benefit cost of all defined benefit plans
Special pension termination benefits	$ 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	$ 4	3	3
Interest cost	22	29	26
Amortization of prior service cost (credit)	(17)	(4)	(4)
Recognized net actuarial loss (gain)	2	(3)	3
Curtailments (gain) loss	2
Net periodic benefit cost	$ 13	$ 25	$ 28

Employee Benefit Plans - Fair v

Employee Benefit Plans - Fair values of pension plan assets (Details) - USD ($) $ in Millions	Dec. 31, 2015		Dec. 31, 2014		Dec. 31, 2013
Fair values of our pension plan assets
Fair value of participating interest in annuity contract	$ 125		$ 116
Net payables receivables related to security transactions	32		21
Fair Value, Inputs, Level 3 [Member]
Fair values of our pension plan assets
Fair value of participating interest in annuity contract	125		116
United States Pension Plans of US Entity, Defined Benefit [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	2,606		3,266		$ 3,092
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	782		1,049
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	485		671
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	569		542
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	141		207
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	348		430
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		115
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	60		67
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		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	(7)		2
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	63		55
United States Pension Plans of US Entity, Defined Benefit [Member] | Excluding reconciling items [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	2,521	[1]	3,138	[2]
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	777		1,039
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	485		671
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	85		132
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		5
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Excluding reconciling items [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	1,347	[1]	1,847	[2]
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	3		2
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	569		542
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	56		75
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	331		426
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		115
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	60		67
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	(7)		(3)
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Excluding reconciling items [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	1,092	[1]	1,224	[2]
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	2		8
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	17		4
United States Pension Plans of US Entity, 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
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	63		55
United States Pension Plans of US Entity, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Excluding reconciling items [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	82	[1]	67	[2]
Foreign Pension Plans, Defined Benefit [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	3,063		3,278		$ 3,132
Foreign Pension Plans, Defined Benefit [Member] | U.S. (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	609		628
Foreign Pension Plans, Defined Benefit [Member] | International (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	450		445
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	214		227
Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Equity Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	340		338
Foreign Pension Plans, Defined Benefit [Member] | Government (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	493		624
Foreign Pension Plans, Defined Benefit [Member] | Corporate (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	172		166
Foreign Pension Plans, Defined Benefit [Member] | Agency and Mortgage Backed Securities(Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	36		47
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	406		396
Foreign Pension Plans, Defined Benefit [Member] | Mutual Funds (Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	136		167
Foreign Pension Plans, Defined Benefit [Member] | Cash and Cash Equivalents [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	56		68
Foreign Pension Plans, Defined Benefit [Member] | Private Equity Funds [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	0		1
Foreign Pension Plans, Defined Benefit [Member] | Derivatives [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	(26)		(4)
Foreign Pension Plans, Defined Benefit [Member] | Real Estate [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	169		166
Foreign Pension Plans, Defined Benefit [Member] | Excluding reconciling items [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	3,055	[1]	3,269	[2]
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	609		628
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	450		445
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	234		241
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	493		624
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	136		167
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	46		50
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	(26)		(4)
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 1 [Member] | Excluding reconciling items [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	1,942	[1]	2,151	[2]
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	214		227
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	106		97
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	172		166
Foreign Pension Plans, 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	36		46
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	406		396
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	10		18
Foreign Pension Plans, 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
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 2 [Member] | Excluding reconciling items [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	944	[1]	950	[2]
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Agency and Mortgage Backed Securities(Debt Securities) [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	0		1
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		1
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	169		166
Foreign Pension Plans, Defined Benefit [Member] | Fair Value, Inputs, Level 3 [Member] | Excluding reconciling items [Member]
Fair values of our pension plan assets
Fair Value of Option Plan Assets	$ 169	[1]	$ 168	[2]
[1]	Excludes the participating interest in the annuity contract with a net asset value of $125 million and net receivables related to security transactions of $32 million.
[2]	Excludes the participating interest in the annuity contract with a net asset value of $116 million and net receivables related to security transactions of $21 million.

Employee Benefit Plans - Benefi

Employee Benefit Plans - Benefit payments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based compensation expense recognized in income and the associated tax benefit
Compensation cost	$ 362	$ 358	$ 308
Tax benefit	$ 123	$ 125	$ 109
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:
2,015	$ 414
2,016	347
2,017	335
2,018	335
2,019	338
2020-2024	1,544
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:
2,015	150
2,016	144
2,017	140
2,018	143
2,019	149
2020-2024	858
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:
2,015	45
2,016	43
2,017	41
2,018	39
2,019	38
2020-2024	$ 158

Employee Benefit Plans (Severan

Employee Benefit Plans (Severances) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Supplemental Unemployment Benefits [Line Items]
Foreign currency translation adjustments	$ (5,199)	$ (3,539)	$ (2,705)
Employee Severance
Supplemental Unemployment Benefits [Line Items]
Severance Accrual	156	$ 61
Payments For Postemployment Benefits	(200)
Severance accrual current period change	306
Foreign currency translation adjustments	(8)
Short term supplemental unemployment beneffits	121
Employee severance accrual reversal [Member]
Supplemental Unemployment Benefits [Line Items]
Severance accrual current period change	$ (3)

Employee Benefit Plans - Stock

Employee Benefit Plans - Stock option activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Assumptions used
Risk-free interest rate	1.79%	1.86%	1.09%
Dividend yield	4.00%	4.00%	4.00%
Volatility factor	23.32%	25.31%	28.95%
Expected life (years)	5 years 9 months 14 days	6 years 1 month 13 days	5 years 11 months 12 days
Summary of Stock Options Activity
Stock option, exercisable	13,192,751
Weighted-Average Exercise Price at the beginning of year	$ 52.61
Weighted-Average Exercise Price, granted	69.25
Weighted-Average Exercise Price, exercised	42.11
Weighted-Average Exercise Price, forfeited	69.2
Weighted-Average Exercise Price, expired or canceled	23.37
Weighted-Average Exercise Price at the end of year	55.88	$ 52.61
Weighted-Average Exercise Price, vested	53.66
Weighted-Average Exercise Price, Exercisable	$ 50.34
Aggregate Intrinsic Value, outstanding	$ 42	$ 284
Aggregate Intrinsic Value, vested	42
Aggregate Intrinsic Value, exercisable	$ 42
Stock option Outstanding at the beginning of year	17,117,871
Stock option, granted	3,873,700
Stock option, exercised	(548,707)
Stock option, forfeited	(258,010)
Stock option, expired or canceled	(44)
Stock option Outstanding at the end of year	20,184,810	17,117,871
Stock option, vested	16,650,347

Employee Benefit Plans - Sto104

Employee Benefit Plans - Stock unit activity (Details) - Stock Unit Program [Member] - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Summary of stock unit activity
Stock Units, Outstanding beginning of year	11,782,856
Stock Units, Granted	3,455,150
Stock Units, Forfeited	(660,298)
Stock Units, Issued/Settled	(5,399,543)
Stock Units, Outstanding ending of year	9,178,165	11,782,856
Stock Units Not Vested, ending of year	6,289,931
Weighted-Average Grant-Date Fair Value, beginning of year	$ 55.75
Weighted-Average Grant-Date Fair Value, Granted	65.4
Weighted-Average Grant-Date Fair Value, Forfeited	63.11
Weighted-Average Grant-Date Fair Value, ending of year	59.8	$ 55.75
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 59.87
Total Fair Value, Issued	$ 316	$ 256	$ 245

Employee Benefit Plans - Perfor

Employee Benefit Plans - Performance Share Program activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Stock Settled Performance Share Program [Member]
Summary of Performance Share Program activity
Stock Units, Outstanding beginning of year	4,651,244
Stock Units, Granted	59,807
Stock Units, Forfeited	0
Stock Units, Issued/Settled	440,829
Stock Units, Outstanding ending of year	4,270,222	4,651,244
Stock Units Not Vested, ending of year	702,623
Weighted-Average Grant-Date Fair Value, beginning of year	$ 51.75
Weighted-Average Grant-Date Fair Value, Granted	69.25
Weighted-Average Grant-Date Fair Value, Forfeited	0
Weighted-Average Grant-Date Fair Value, ending of year	51.95	$ 51.75
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 53.9
Total Fair Value, Issued	$ 25	$ 18	$ 18
Cash Settled Performance Share Program [Member]
Summary of Performance Share Program activity
Stock Units, Outstanding beginning of year	675,587
Stock Units, Granted	903,398
Stock Units, Forfeited	0
Stock Units, Issued/Settled	(119,749)
Stock Units, Outstanding ending of year	1,459,236	675,587
Stock Units Not Vested, ending of year	873,853
Weighted-Average Grant-Date Fair Value, beginning of year	$ 69.23
Weighted-Average Grant-Date Fair Value, Granted	46.54
Weighted-Average Grant-Date Fair Value, Forfeited	0
Weighted-Average Grant-Date Fair Value, ending of year	46.54	$ 69.23
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 46.54
Total Fair Value, Issued	$ 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, 2015USD ($)$ / sharesshares
Summary of aggregate activity of restricted shares and units
Stock Units, Outstanding beginning of year | shares	1,207,035
Stock Units, Granted | shares	108,306
Stock Units, Forfeited | shares	(6,969)
Stock Units, Issued/Settled | shares	(36,236)
Stock Units, Outstanding ending of year | shares	1,272,136
Weighted-Average Grant-Date Fair Value, beginning of year | $ / shares	$ 31.48
Weighted-Average Grant-Date Fair Value, Granted | $ / shares	58.66
Weighted-Average Grant-Date Fair Value, Forfeited | $ / shares	22.62
Weighted-Average Grant-Date Fair Value, ending of year | $ / shares
Weighted-Average Grant-Date Fair Value Not Vested, ending of year | $ / shares	$ 33.25
Total Fair Value, Issued | $	$ 3

Employee Benefits Plans (Detail

Employee Benefits Plans (Details Textual) $ in Millions	12 Months Ended
	Dec. 31, 2016	Dec. 31, 2015USD ($)investmentsshares	Dec. 31, 2014USD ($)shares	Dec. 31, 2013USD ($)
Pension And Postretirement Plans (Textual) [Abstract]
Decrease in pension liabilities due to separation				$ 0
Decrease in deferred taxes due to pension separation				0
Decrease in other comprehensive income due to pension separation				0
Pension settlement losses		$ 204		$ 67
Plan Assets (Textual) [Abstract]
Fair value of participating interest in annuity contract		125	$ 116
Decrease In Fair Value Of Debt Securities		23
Decrease in Present Value of Contract Obligation		$ 32
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		35
Employer matching contribution up to a certain percentage of pay	6.00%			0.00%
Employer matching discretionary contribution	6.00%
Company contributions in savings plan and predecessor plans except leveraged employee stock ownership plan charged to expense		$ 103	$ 116	$ 101
Eligibility of employees to participate in leveraged employee stock ownership plan				1.00%
CPSP stock savings feature shares
Allocated shares | shares		7,243,832	8,198,873
Dividends used to service debt				$ 0
Interest incurred on the CPSP debt				0
Defined contribution plan employee contribution percent	1.00%
Share Based Compensation Plans (Textual) [Abstract]
Omnibus Stock and Performance Incentive Plan life		10 years
Authorized common stock for compensation plan, maximum | shares		79,000,000
Common stock available under incentive stock options, maximum | shares		40,000,000
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		9.00%
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		58.00%
Debt Securities [Member]
Plan Assets (Textual) [Abstract]
Target allocations for plan assets		36.00%
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 annuity contract		$ 125	$ 116
Fair value of participating interest in debt security		305	328
Accumulated benefit obligation covered by the contract		180	212
United States Pension Plans of US Entity, Defined Benefit [Member]
Pension And Postretirement Plans (Textual) [Abstract]
Pension settlement losses		197	0	67
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		190
Defined Contribution Plans (Textual) [Abstract]
Company contributions in savings plan and predecessor plans except leveraged employee stock ownership plan charged to expense		55	66	60
Domestic qualified and nonqualified pension and postretirement benefit plans [Member]
Plan Assets (Textual) [Abstract]
Expected contribution to qualified and nonqualified pension and postretirement benefit		220
Tax qualified pension plan [Member]
Pension And Postretirement Plans (Textual) [Abstract]
Tax-qualified pension plans with projected benefit obligations in excess of plan assets		5,720	7,584
Tax-qualified pension plans with accumulated benefit obligation in excess of plan assets		5,314	6,503
Tax-qualified pension plans with fair value of plan assets in excess of plan assets		4,759	6,446
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		639	703
Tax-qualified pension plans with accumulated benefit obligation in excess of plan assets		$ 564	$ 482
Discontinued Operations [Member]
Pension And Postretirement Plans (Textual) [Abstract]
Pension settlement losses				$ 24

Employee Benefits Plans (Det108

Employee Benefits Plans (Details Textual 1) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
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 10 months 2 days
Weighted-average remaining contractual term exercisable	4 years 5 months 5 days
Weighted-Average Grant-Date Fair Value, granted	$ 9.54	$ 10.17	$ 9.9
Aggregate Intrinsic Value, exercised	$ 10	$ 89	$ 95
Cash received from exercise of stock options	23
Tax benefit from exercise of options	16
Unrecognized compensation cost from stock options	$ 16
Weighted average period of recognition of unvested options, in months	1 year 2 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		$ 62.72	$ 57.99
Unrecognized compensation cost from stock options	$ 155
Weighted average period of recognition of unvested options, in months	1 year 6 months 11 days
Longest weighted-average period of recognition of unvested options, in months	2 years 8 months 1 day
Total Fair Value, Issued	$ 316	$ 256	$ 245
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	$ 2
Stock Settled Performance Share Program [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 65.46	$ 60
Years of service required for award	5 years
Retirement eligible age	55
Unrecognized compensation cost from stock options	$ 9
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	4 years 11 months 27 days
Total Fair Value, Issued	$ 25	$ 18	$ 18
Cash Settled Performance Share Program [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 69.23	$ 58.08
Years of service required for award	5 years
PSU termination date		Dec. 31, 2015	Dec. 31, 2014
Unrecognized compensation cost from stock options	$ 18
Weighted average period of recognition of unvested options, in months	2 years 1 month 6 days
Longest weighted-average period of recognition of unvested options, in months	4 years 1 month 17 days
Total Fair Value, Issued	$ 6	$ 0
Other [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Weighted-Average Grant-Date Fair Value, granted		$ 71.23	$ 62.52
Total Fair Value, Issued		$ 3	$ 2

Income Taxes (Details)

Income Taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Deferred Tax Liabilities
Properties, plants and equipment, and intangibles	$ 16,378	$ 20,054
Investment in joint ventures	866	1,013
Inventory	25	51
Deferred state income tax (liability)	128	63
Partnership income deferral	44	155
Other	453	509
Total deferred tax liabilities	17,894	21,845
Deferred Tax Assets
Benefit plan accruals	1,160	1,552
Asset retirement obligations and accrued environmental costs	4,426	4,971
Deferred state income tax	0	0
Other financial accruals and deferrals	616	552
Loss and credit carryforwards	1,579	1,568
Other	134	329
Total deferred tax assets	7,915	8,972
Less valuation allowance	(734)	(970)
Net deferred tax assets	7,181	8,002
Net deferred tax liabilities	10,713	13,843
Reconciliation of the beginning and ending unrecognized tax benefits
Unrecognized Tax Benefits, Balance at January 1	442	655	$ 872
Additions based on tax positions related to the current year	54	46	52
Additions for tax positions of prior years	4	7	30
Reductions for tax positions of prior years	(37)	(228)	(251)
Settlements	(4)	(28)	(48)
Lapse of statute	0	(10)	0
Unrecognized Tax Benefits, Balance at December 31	459	442	655
Income (loss) before income taxes, Income Tax Reconciliation
Income (loss) before taxes - United States	(4,150)	2,310	5,046
Income (loss) before taxes - foreign	(3,089)	7,080	9,400
Income (loss) from continuing operations before income taxes	(7,239)	9,390	14,446
Federal statutory income tax	(2,534)	3,287	5,056
Foreign taxes in excess of federal statutory rate	381	376	1,389
Foreign tax law change	(426)
U.S. fair value election	(185)
Capital loss benefit	0	0	(79)
Federal manufacturing deduction	0	(15)	(35)
State income tax	(89)	(44)	79
Other	(15)	(21)	(1)
Provision for income taxes	$ (2,868)	$ 3,583	$ 6,409
Income (loss) before income taxes, Percent of Pretax Income
Income (loss) before income taxes, United States, Percentage	57.30%	24.60%	34.90%
Income (loss) before income taxes, Foreign, Percentage	42.70%	75.40%	65.10%
Income (loss) before income taxes, Percent	100.00%	100.00%	100.00%
Domestic federal statutory rate	35.00%	35.00%	35.00%
Foreign taxes in excess of federal statutory rate	(5.30%)	4.00%	9.60%
Foreign tax law change percent	5.90%
U.S. fair value election percent	2.60%
Capital loss benefit, Percent	0.00%	0.00%	(0.50%)
Federal manufacturing deduction, Rate	0.00%	(0.20%)	(0.20%)
State income tax, Rate	1.20%	(0.50%)	0.50%
Other, Rate	0.20%	(0.20%)	0.00%
Total Income taxes charged to income (loss), Rate	39.60%	38.10%	44.40%
Income Taxes (Textual) [Abstract]
Deferred taxes Included in current assets	$ 0	$ 865
Deferred taxes Included in long-term assets	286	370
Deferred taxes Included in current liabilities	0	8
Deferred taxes Included in long-term liabilities	10,999	15,070
Income considered to be permanently reinvested in foreign subsidiaries and foreign corporate joint ventures	3,300
Unrecognized tax benefits that if recognized, would affect effective tax rate	354	348	$ 440
Accrued liabilities for interest and penalties	79	65	120
Interest and penalties (benefiting) charging earnings	11	(43)	$ (9)
UK Tax Relief Rate			0.00%
Earnings reduction due to deferred tax remeasurement			$ 0
Valuation Allowance [Line Items]
Worthless Security Deduction	491	122	19
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)	745	$ 2,846	$ 4,249
Valuation Allowance Amount Of Decrease [Member]
Valuation Allowance [Line Items]
Increase (decrease) in valuation allowance	(236)
Canada [Member]
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)	$ 129
Corporation Tax Rate pre legislation	25.00%
Corporation Tax Rate post legislation	27.00%
United Kingdom [Member]
Current Income Tax Expense Benefit [Line Items]
Current Foreign Tax Expense (Benefit)	$ (555)
Corporation Tax Rate pre legislation	62.00%
Corporation Tax Rate post legislation	50.00%

Income Taxes (Details 1)

Income Taxes (Details 1) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Federal
Current	$ (718)	$ 188	$ 724
Deferred	(1,443)	365	811
Foreign
Current	745	2,846	4,249
Deferred	(1,315)	252	504
State and local
Current	8	46	220
Deferred	(145)	(114)	(99)
Provision for income taxes	$ (2,868)	$ 3,583	$ 6,409

Accumulated Other Comprehens111

Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Accumulated other comprehensive income
Defined Benefit Plans, Beginning Balance		$ (1,261)	$ (824)	$ (1,425)
Foreign Currency Translation, Beginning Balance		(641)	2,826	5,512
Hedging, Beginning Balance			0	0
Accumulated Other Comprehensive Income (loss), Beginning Balance		(1,902)	2,002	4,087
Defined Benefit Pension Plans		818	(437)	601
Defined Benefit Plans, Separation of Downstream Business				0
Foreign Currency Translation		(5,163)	(3,467)	(2,686)
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		(4,345)	(3,904)	(2,085)
Defined Benefit Plans, Ending Balance		(443)	(1,261)	(824)
Foreign Currency Translation, Ending Balance		(5,804)	(641)	2,826
Hedging, Ending Balance				0
Accumulated Other Comprehensive Income (loss), Ending Balance		(6,247)	(1,902)	$ 2,002
Reclassification out of Accumulated Other Comprehensive Income [Abstract]
Defined Benefit Plans	[1],[2]	251	81
Other Comprehensive (Income) Loss Reclassification Adjustment From AOCI Pension And Other Postretirement Benefit Plans, Tax		$ 133	$ 44
[1]	Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $133 $44
[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, 2015		Dec. 31, 2014		Dec. 31, 2013
Noncash Investing and Financing Activities
Increase in PP&E related to increase in asset retirement obligations	$ 402		$ 1,611	[1]	$ 1,329	[1]
Increase in PP&E and debt related to a capital lease asset and obligation	7		(84)		906
Cash payments
Interest	920		669		566
Income taxes	523	[2]	4,203		4,910
Proceeds From Income Tax Refunds	642
Net Sales (Purchases) of Short-Term Investments
Short-term investments purchased	0		(876)		(361)
Short-term investments sold	0		1,129		98
Net Sales (Purchases) of Short-Term Investments	0		253	[3]	(263)	[3]
ARO increase related to UK tax law changes	0		68		212
Accounting Changes And Error Corrections [Abstract]
Working capital changes associated with investing activities	$ (968)		$ 180	[3]	$ (55)	[3]
[1]	*Includes $68 million and $212 million in 2014 and 2013, respectively, primarily related to the impact of U.K. tax law changes on the deductibility of decommissioning costs.
[2]	**Net of $642 million in 2015 related to a refund received from the Internal Revenue Service for 2014 overpaid taxes.
[3]	*Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to Consolidated Financial Statements.

Other Financial Information (De

Other Financial Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		$ (64)	$ (44)		$ (33)
Incurred
Debt		1,130	1,063		1,087
Other		84	73		192
Interest Costs Incurred, Total		1,214	1,136		1,279
Capitalized		(294)	(488)		(667)
Expensed		920	648		612
Other Income
Interest income		45	83		113
Other, net		80	283		261
Other Nonoperating Income		125	366		374
Research and Development Expenditures - expensed		222	263		258
Shipping and Handling Costs	[1]	1,181	1,360		1,137
Lower 48 [Member]
Other Income
Interest income		0	35		43
Canada [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		0	(4)		(6)
Europe and North Africa
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		(22)	(56)	[2]	(29)	[2]
Other Income
Interest income		2	2		1
Asia Pacific and Middle East [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		(78)	0		(29)
Other Income
Interest income		6	6		8
Other International [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		(9)	0	[2]	0	[2]
Other Income
Interest income		1	0		1
Corporate and Other [Member]
Foreign Currency Transaction [Abstract]
Foreign currency transaction gain loss after tax		45	16		31
Other Income
Interest income		$ 36	$ 40		$ 60
[1]	*Amounts included in production and operating expenses.
[2]	*2014 and 2013 restated to conform to current period presentation.

Other Financial Information - P

Other Financial Information - Property, Plant and Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Properties, Plants And Equipment
Proved properties	$ 122,796	$ 130,448
Unproved properties	7,410	8,951
Other	6,653	6,831
Gross properties, plants and equipment	136,859	146,230
Accumulated depreciation	(70,413)	(70,786)
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $70,413 million in 2015 and $70,786 million in 2014)	$ 66,446	75,444
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, 2015	Dec. 31, 2014	Dec. 31, 2013
Significant transactions with related parties
Operating revenues and other income		$ 118	$ 119	$ 102
Purchases		97	190	184
Operating expenses and selling, general and administrative expenses		62	70	35
Net interest expense	[1]			$ 31
Net Interest Income	[2]	$ (9)	$ (44)
[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, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Sales and Operating Revenues by Segment
Sales and other operating revenues		$ 29,564	$ 52,524	$ 54,413
Number of Operating Segments		6
Alaska [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		$ 4,351	8,382	8,553
Lower 48 Before Intersegment Eliminations [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		11,976	21,721	19,480
Intersegment Eliminations before Lower 48 [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		(63)	(107)	(104)
Lower 48 [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		11,913	21,614	19,376
Canada before Intersegment Eliminations [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		2,454	5,162	5,254
Intersegment Eliminations before Canada [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		(318)	(753)	(607)
Canada [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues	[1]	2,136	4,409	4,647
Europe and North Africa before Intersegment Eliminations [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		6,110	10,665	13,248
Intersegment Eliminations before Europe [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		(4)	(49)	0
Europe and North Africa
Sales and Operating Revenues by Segment
Sales and other operating revenues		6,106	10,616	13,248
Asia Pacific before Intersegment Eliminations [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		4,746	7,425	8,426
Intersegment Eliminations before Asia Pacific [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		(1)	(1)	0
Asia Pacific and Middle East [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		4,745	7,424	8,426
Other International [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		1	0	0
Corporate and Other [Member]
Sales and Operating Revenues by Segment
Sales and other operating revenues		$ 312	$ 79	$ 163
[1]	Sales and other operating revenues are attributable to countries based on the location of the operations generating the revenues.

Segment Disclosures - Depreciat

Segment Disclosures - Depreciation, Equity Earnings, Income Tax (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	$ 11,358	$ 9,185	$ 7,963
Equity in Earnings of Affiliates
Equity in earnings of affiliates	655	2,529	2,219
Income Taxes
Provision (benefit) for income taxes	(2,868)	3,583	6,409
Alaska State [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	690	584	533
Equity in Earnings of Affiliates
Equity in earnings of affiliates	4	9	7
Income Taxes
Provision (benefit) for income taxes	(71)	1,081	1,275
Lower 48 [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	4,227	3,911	3,247
Equity in Earnings of Affiliates
Equity in earnings of affiliates	(5)	1	(2)
Income Taxes
Provision (benefit) for income taxes	(1,119)	(92)	398
Canada [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	788	962	1,531
Equity in Earnings of Affiliates
Equity in earnings of affiliates	78	1,385	984
Income Taxes
Provision (benefit) for income taxes	(223)	236	(44)
Europe and North Africa
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	2,565	2,345	1,363
Equity in Earnings of Affiliates
Equity in earnings of affiliates	23	37	27
Income Taxes
Provision (benefit) for income taxes	(854)	1,590	3,258
Asia Pacific and Middle East [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	2,981	1,275	1,188
Equity in Earnings of Affiliates
Equity in earnings of affiliates	550	1,089	1,162
Income Taxes
Provision (benefit) for income taxes	467	1,194	1,512
Other International [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	0	1	1
Equity in Earnings of Affiliates
Equity in earnings of affiliates	8	9	43
Income Taxes
Provision (benefit) for income taxes	(456)	(102)	134
Corporate and Other [Member]
Depreciation, Depletion, Amortization, and Impairments
Depreciation, Depletion, Amortization and Impairments, Total	107	107	100
Equity in Earnings of Affiliates
Equity in earnings of affiliates	(3)	(1)	(2)
Income Taxes
Provision (benefit) for income taxes	$ (612)	$ (324)	$ (124)

Segment Disclosures - Net Incom

Segment Disclosures - Net Income (Loss), Investments, Total Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	$ (4,428)	$ 6,869	$ 9,156
Investments In and Advances To Affiliates
Investments in and advances to affiliates	20,546	24,230	24,337
Total Assets
Total assets	97,484	116,539	118,057
Alaska State [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	4	2,041	2,274
Investments In and Advances To Affiliates
Investments in and advances to affiliates	61	53	53
Total Assets
Total assets	12,555	12,655	11,662
Lower 48 [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(1,932)	(22)	754
Investments In and Advances To Affiliates
Investments in and advances to affiliates	455	471	905
Total Assets
Total assets	26,932	30,185	29,552
Canada [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(1,044)	940	718
Investments In and Advances To Affiliates
Investments in and advances to affiliates	8,165	9,484	10,273
Total Assets
Total assets	17,221	21,764	22,394
Europe and North Africa
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	409	814	1,297
Investments In and Advances To Affiliates
Investments in and advances to affiliates	70	126	143
Total Assets
Total assets	13,703	16,970	18,109
Asia Pacific and Middle East [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(463)	2,939	3,532
Investments In and Advances To Affiliates
Investments in and advances to affiliates	11,780	14,022	12,806
Total Assets
Total assets	22,318	25,976	25,473
Other International [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(593)	(100)	223
Investments In and Advances To Affiliates
Investments in and advances to affiliates	0	59	141
Total Assets
Total assets	282	1,116	819
Corporate and Other [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	(809)	(874)	(820)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	15	15	16
Total Assets
Total assets	4,473	7,815	8,367
Discontinued Operations [Member]
Net Income (Loss) Attributable to ConocoPhillips
Consolidated net income (loss) attributable to ConocoPhillips	0	1,131	1,178
Total Assets
Total assets	$ 0	$ 58	$ 1,681

Segment Disclosures - Capital E

Segment Disclosures - Capital Expenditures and Interest (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Capital Expenditures and Investments
Consolidated capital expenditures and investments	$ 10,050	$ 17,085	$ 15,537
Interest Income and Expense
Interest income	45	83	113
Alaska State [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	1,352	1,564	1,140
Lower 48 [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	3,765	6,054	5,210
Interest Income and Expense
Interest income	0	35	43
Canada [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	1,255	2,340	2,232
Interest Income and Expense
Interest and debt expense	0	0	80
Europe and North Africa
Capital Expenditures and Investments
Consolidated capital expenditures and investments	1,573	2,540	3,126
Interest Income and Expense
Interest income	2	2	1
Asia Pacific and Middle East [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	1,812	3,877	3,382
Interest Income and Expense
Interest income	6	6	8
Other International [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	173	520	265
Interest Income and Expense
Interest income	1	0	1
Corporate and Other [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	120	190	182
Interest Income and Expense
Interest income	36	40	60
Interest and debt expense	$ 920	$ 648	$ 532

Segment Disclosures - Sales by

Segment Disclosures - Sales by Product (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product		$ 29,564	$ 52,524	$ 54,413
Crude Oil [Member]
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product		12,830	23,784	24,899
Natural Gas [Member]
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product		11,888	20,717	22,539
Natural Gas Liquids [Member]
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product		952	2,245	2,111
Other Products [Member]
Sales And Other Operating Revenues By Product [Abstract]
Consolidated sales and other operating revenues by product	[1]	$ 3,894	$ 5,778	$ 4,864
[1]	*Includes LNG and bitumen.

Segment Disclosures - Geographi

Segment Disclosures - Geographic Information (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Geographic Information
Sales and other operating revenues		$ 29,564	$ 52,524	$ 54,413
Long-Lived Assets	[1]	86,992	99,674	97,164
UNITED STATES
Geographic Information
Sales and other operating revenues	[2]	16,284	30,019	27,954
Long-Lived Assets	[1]	37,445	39,641	37,593
AUSTRALIA
Geographic Information
Sales and other operating revenues	[2],[3]	2,127	3,258	3,571
Long-Lived Assets	[1],[3]	12,788	14,969	13,450
CANADA
Geographic Information
Sales and other operating revenues	[2]	2,136	4,409	4,647
Long-Lived Assets	[1]	16,766	20,874	21,380
CHINA
Geographic Information
Sales and other operating revenues	[2]	782	1,701	2,120
Long-Lived Assets	[1]	1,647	1,913	2,143
INDONESIA
Geographic Information
Sales and other operating revenues	[2]	1,165	1,963	2,083
Long-Lived Assets	[1]	1,191	1,526	1,780
MALAYSIA
Geographic Information
Sales and other operating revenues	[2]	598	403	281
Long-Lived Assets	[1]	3,599	3,811	3,406
NORWAY
Geographic Information
Sales and other operating revenues	[2]	2,107	3,794	4,323
Long-Lived Assets	[1]	6,933	8,142	8,089
UNITED KINGDOM
Geographic Information
Sales and other operating revenues	[2]	4,005	6,594	7,717
Long-Lived Assets	[1]	4,154	5,327	5,959
Segment Geographical Groups of Countries Other [Member]
Geographic Information
Sales and other operating revenues	[2]	360	383	1,717
Long-Lived Assets	[1]	$ 2,469	$ 3,471	$ 3,364
[1]	Defined as net PP&E plus investments in and advances to affiliated companies.
[2]	Sales and other operating revenues are attributable to countries based on the location of the operations generating the revenues.
[3]	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, 2015
Segment Disclosures and Related Information (Textual) [Abstract]
Number of operating segments	6

Supplementary Information - 123

Supplementary Information - Condensed Consolidating Financial Information Income Statement (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues and Other Income
Sales and other operating revenues		$ 29,564	$ 52,524	$ 54,413
Equity in earnings of affiliates		655	2,529	2,219
Gain on dispositions		591	98	1,242
Other income		125	366	374
Intercompany Revenues			0	0
Total Revenues and Other Income		30,935	55,517	58,248
Costs and Expenses
Purchased commodities		12,426	22,099	22,643
Production and operating expenses		7,016	8,909	7,238
Selling, general and administrative expenses		953	735	854
Exploration expenses		4,192	2,045	1,232
Depreciation, depletion and amortization		9,113	8,329	7,434
Impairments		2,245	856	529
Taxes other than income taxes		901	2,088	2,884
Accretion on discounted liabilities		483	484	434
Interest and debt expense		920	648	612
Foreign currency transaction (gains) losses		(75)	(66)	(58)
Total Costs and Expenses		38,174	46,127	43,802
Income (loss) before income taxes		(7,239)	9,390	14,446
Provision (benefit) for income taxes		(2,868)	3,583	6,409
Income (Loss) From Continuing Operations		(4,371)	5,807	8,037
Income (loss) from discontinued operations	[1]	0	1,131	1,178
Net income (loss)		(4,371)	6,938	9,215
Less: net income attributable to noncontrolling interests		(57)	(69)	(59)
Net income (loss) attributable to ConocoPhillips		(4,428)	6,869	9,156
Comprehensive Income Attributable to ConocoPhillips		(8,773)	2,965	7,071
ConocoPhillips [Member]
Revenues and Other Income
Equity in earnings of affiliates		(4,081)	6,108	8,374
Other income		0	(6)	2
Intercompany Revenues		74	79	82
Total Revenues and Other Income		(4,007)	6,181	8,458
Costs and Expenses
Production and operating expenses			0
Selling, general and administrative expenses		9	9	11
Exploration expenses			0
Depreciation, depletion and amortization			0
Impairments			0
Taxes other than income taxes			0
Accretion on discounted liabilities			0
Interest and debt expense		485	571	630
Foreign currency transaction (gains) losses		114	62	52
Total Costs and Expenses		608	642	693
Income (loss) before income taxes		(4,615)	5,539	7,765
Provision (benefit) for income taxes		(187)	(199)	(213)
Income (Loss) From Continuing Operations		(4,428)	5,738	7,978
Income (loss) from discontinued operations		0	1,131	1,178
Net income (loss)		(4,428)	6,869	9,156
Net income (loss) attributable to ConocoPhillips		(4,428)	6,869	9,156
Comprehensive Income Attributable to ConocoPhillips		(8,773)	2,965	7,071
ConocoPhillips Company [Member]
Revenues and Other Income
Sales and other operating revenues		11,473	20,083	18,186
Equity in earnings of affiliates		(1,950)	8,090	9,200
Gain on dispositions		332	9	364
Other income		12	67	271
Intercompany Revenues		341	465	458
Total Revenues and Other Income		10,208	28,714	28,479
Costs and Expenses
Purchased commodities		9,905	17,591	15,779
Production and operating expenses		1,469	2,600	1,492
Selling, general and administrative expenses		744	575	623
Exploration expenses		2,093	1,036	659
Depreciation, depletion and amortization		1,201	1,059	907
Impairments		15	127	4
Taxes other than income taxes		173	285	236
Accretion on discounted liabilities		58	58	56
Interest and debt expense		423	299	327
Foreign currency transaction (gains) losses		1	10	3
Total Costs and Expenses		16,082	23,640	20,086
Income (loss) before income taxes		(5,874)	5,074	8,393
Provision (benefit) for income taxes		(1,793)	(1,034)	19
Income (Loss) From Continuing Operations		(4,081)	6,108	8,374
Income (loss) from discontinued operations		0	1,131	1,178
Net income (loss)		(4,081)	7,239	9,552
Net income (loss) attributable to ConocoPhillips		(4,081)	7,239	9,552
Comprehensive Income Attributable to ConocoPhillips		(8,426)	3,335	7,467
ConocoPhillips Australia Funding Company [Member]
Revenues and Other Income
Intercompany Revenues				13
Total Revenues and Other Income				13
Costs and Expenses
Interest and debt expense				12
Total Costs and Expenses				12
Income (loss) before income taxes				1
Provision (benefit) for income taxes				0
Income (Loss) From Continuing Operations				1
Net income (loss)				1
Net income (loss) attributable to ConocoPhillips				1
Comprehensive Income Attributable to ConocoPhillips				1
ConocoPhillips Canada Funding Company I [Member]
Revenues and Other Income
Intercompany Revenues		246	283	305
Total Revenues and Other Income		246	283	305
Costs and Expenses
Selling, general and administrative expenses		1	1	1
Interest and debt expense		226	231	235
Foreign currency transaction (gains) losses		(708)	(372)	(349)
Total Costs and Expenses		(481)	(140)	(113)
Income (loss) before income taxes		727	423	418
Provision (benefit) for income taxes		21	19	31
Income (Loss) From Continuing Operations		706	404	387
Net income (loss)		706	404	387
Net income (loss) attributable to ConocoPhillips		706	404	387
Comprehensive Income Attributable to ConocoPhillips		71	58	99
All Other Subsidiaries [Member]
Revenues and Other Income
Sales and other operating revenues		18,091	32,441	36,227
Equity in earnings of affiliates		1,364	2,932	2,611
Gain on dispositions		259	89	878
Other income		113	305	101
Intercompany Revenues		3,365	5,883	4,948
Total Revenues and Other Income		23,192	41,650	44,765
Costs and Expenses
Purchased commodities		5,838	10,415	11,812
Production and operating expenses		5,585	6,368	5,756
Selling, general and administrative expenses		209	166	238
Exploration expenses		2,099	1,009	573
Depreciation, depletion and amortization		7,912	7,270	6,527
Impairments		2,230	729	525
Taxes other than income taxes		728	1,803	2,648
Accretion on discounted liabilities		425	426	378
Interest and debt expense		447	275	237
Foreign currency transaction (gains) losses		518	234	236
Total Costs and Expenses		25,991	28,695	28,930
Income (loss) before income taxes		(2,799)	12,955	15,835
Provision (benefit) for income taxes		(909)	4,797	6,572
Income (Loss) From Continuing Operations		(1,890)	8,158	9,263
Income (loss) from discontinued operations		0	113	1,178
Net income (loss)		(1,890)	8,271	10,441
Less: net income attributable to noncontrolling interests		(57)	(69)	(59)
Net income (loss) attributable to ConocoPhillips		(1,947)	8,202	10,382
Comprehensive Income Attributable to ConocoPhillips		(6,705)	4,589	7,782
Consolidating Adjustments [Member]
Revenues and Other Income
Equity in earnings of affiliates		5,322	(14,601)	(17,966)
Intercompany Revenues		(4,026)	(6,710)	(5,806)
Total Revenues and Other Income		1,296	(21,311)	(23,772)
Costs and Expenses
Purchased commodities		(3,317)	(5,907)	(4,948)
Production and operating expenses		(38)	(59)	(10)
Selling, general and administrative expenses		(10)	(16)	(19)
Interest and debt expense		(661)	(728)	(829)
Total Costs and Expenses		(4,026)	(6,710)	(5,806)
Income (loss) before income taxes		5,322	(14,601)	(17,966)
Income (Loss) From Continuing Operations		5,322	(14,601)	(17,966)
Income (loss) from discontinued operations		0	(1,244)	(2,356)
Net income (loss)		5,322	(15,845)	(20,322)
Net income (loss) attributable to ConocoPhillips		5,322	(15,845)	(20,322)
Comprehensive Income Attributable to ConocoPhillips		$ 15,060	$ (7,982)	$ (15,349)
[1]	Net of provision for income taxes on discontinued operations of: $0, $16, $283

Supplementary Information - 124

Supplementary Information - Condensed Consolidating Financial Information Balance Sheet (Details 1) - USD ($) $ in Millions		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013		Dec. 31, 2012
Assets
Cash and cash equivalents		$ 2,368	$ 5,062	$ 6,246	[1]	$ 3,618	[1]
Accounts and notes receivable		4,514	6,807
Inventories		1,124	1,331
Prepaid expenses and other current assets		783	1,868
Total Current Assets		8,789	15,068
Investments, loans and long-term receivables	[2]	21,186	25,139
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $65,321 million in 2013 and $58,916 million in 2012)		66,446	75,444
Other assets		1,063	888
Total Assets		97,484	116,539	118,057
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable		4,933	8,026
Short-term debt		1,427	182
Accrued income and other taxes		499	1,051
Employee benefit obligations		887	878
Other accruals		1,510	1,400
Total Current Liabilities		9,256	11,537
Long-term debt		23,453	22,383
Long-term asset retirement obligations and accrued environmental costs		9,580	10,647
Deferred income taxes		10,999	15,070
Employee benefit obligations		2,286	2,964
Other liabilities and deferred credits	[2]	1,828	1,665
Total Liabilities		57,402	64,266
Retained earnings		36,414	44,504
Other common stockholders' equity		3,348	7,407
Noncontrolling interests		320	362
Total Liabilities and Equity		97,484	116,539
ConocoPhillips [Member]
Assets
Cash and cash equivalents		0		0		2
Short-term investments		0
Accounts and notes receivable		21	20
Inventories		0	0
Prepaid expenses and other current assets		2	6
Total Current Assets		23	26
Investments, loans and long-term receivables	[2]	43,532	55,568
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		7	40
Total Assets		43,562	55,634
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable		0	1
Short-term debt		(9)	(5)
Accrued income and other taxes		0	0
Employee benefit obligations		0	0
Other accruals		170	170
Total Current Liabilities		161	166
Long-term debt		7,518	7,541
Long-term asset retirement obligations and accrued environmental costs		0
Deferred income taxes		0
Employee benefit obligations		0
Other liabilities and deferred credits	[2]	2,681	2,577
Total Liabilities		10,360	10,284
Retained earnings		29,892	37,983
Other common stockholders' equity		3,310	7,367
Noncontrolling interests		0	0
Total Liabilities and Equity		43,562	55,634
ConocoPhillips Company [Member]
Assets
Cash and cash equivalents		4	770	2,434		12
Short-term investments		0
Accounts and notes receivable		2,905	2,813
Inventories		142	281
Prepaid expenses and other current assets		206	754
Total Current Assets		3,257	4,618
Investments, loans and long-term receivables	[2]	64,015	70,732
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $65,321 million in 2013 and $58,916 million in 2012)		8,110	9,730
Other assets		950	67
Total Assets		76,332	85,147
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable		5,684	4,149
Short-term debt		1	6
Accrued income and other taxes		62	117
Employee benefit obligations		629	595
Other accruals		465	337
Total Current Liabilities		6,841	5,204
Long-term debt		10,660	8,197
Long-term asset retirement obligations and accrued environmental costs		1,107	1,328
Deferred income taxes		0	265
Employee benefit obligations		1,760	2,162
Other liabilities and deferred credits	[2]	7,291	7,391
Total Liabilities		27,659	24,547
Retained earnings		17,366	21,448
Other common stockholders' equity		31,307	39,152
Noncontrolling interests		0	0
Total Liabilities and Equity		76,332	85,147
ConocoPhillips Canada Funding Company I [Member]
Assets
Cash and cash equivalents		15	7	229		59
Accounts and notes receivable		21	22
Inventories		0
Prepaid expenses and other current assets		252	15
Total Current Assets		288	44
Investments, loans and long-term receivables	[2]	3,264	3,965
Other assets		233	208
Total Assets		3,785	4,217
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable		13	14
Short-term debt		1,255	5
Other accruals		52	71
Total Current Liabilities		1,320	90
Long-term debt		1,716	2,974
Deferred income taxes			0
Other liabilities and deferred credits	[2]	667	1,142
Total Liabilities		3,703	4,206
Retained earnings		(389)	(1,096)
Other common stockholders' equity		471	1,107
Total Liabilities and Equity		3,785	4,217
All Other Subsidiaries [Member]
Assets
Cash and cash equivalents		2,349	4,285	$ 3,583		$ 3,539
Short-term investments		0	0
Accounts and notes receivable		7,228	6,671
Inventories		982	1,050
Prepaid expenses and other current assets		589	1,138
Total Current Assets		11,148	13,144
Investments, loans and long-term receivables	[2]	27,839	32,467
Net properties, plants and equipment (net of accumulated depreciation, depletion and amortization of $65,321 million in 2013 and $58,916 million in 2012)		58,336	65,714
Other assets		1,158	1,338
Total Assets		98,481	112,663
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable		4,897	6,581
Short-term debt		180	176
Accrued income and other taxes		437	934
Employee benefit obligations		258	283
Other accruals		1,087	868
Total Current Liabilities		6,859	8,842
Long-term debt		3,559	3,671
Long-term asset retirement obligations and accrued environmental costs		8,473	9,319
Deferred income taxes		11,814	14,811
Employee benefit obligations		526	802
Other liabilities and deferred credits	[2]	15,181	17,218
Total Liabilities		46,412	54,663
Retained earnings		15,177	17,355
Other common stockholders' equity		36,572	40,283
Noncontrolling interests		320	362
Total Liabilities and Equity		98,481	112,663
Consolidating Adjustments [Member]
Assets
Accounts and notes receivable		(5,661)	(2,719)
Prepaid expenses and other current assets		(266)	(45)
Total Current Assets		(5,927)	(2,764)
Investments, loans and long-term receivables	[2]	(117,464)	(137,593)
Other assets		(1,285)	(765)
Total Assets		(124,676)	(141,122)
Liabilities and Stockholders Equity
Accounts payable and related party accounts payable		(5,661)	(2,719)
Accrued income and other taxes		0	0
Other accruals		(264)	(46)
Total Current Liabilities		(5,925)	(2,765)
Deferred income taxes		(815)	(6)
Other liabilities and deferred credits	[2]	(23,992)	(26,663)
Total Liabilities		(30,732)	(29,434)
Retained earnings		(25,632)	(31,186)
Other common stockholders' equity		(68,312)	(80,502)
Total Liabilities and Equity		$ (124,676)	$ (141,122)
[1]	*Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to Consolidated Financial Statements.
[2]	Includes intercompany loans

Supplementary Information - 125

Supplementary Information - Condensed Consolidating Financial Information Balance Sheet (Details Textual) - USD ($) $ in Billions	Mar. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Conocophillips [Member]
Condensed Financial Statements, Captions [Line Items]
Intercompany return of capital			$ (17)
Intercompany other liabilities	$ 2.3	$ 3.5	34.5
Intercompany Investment	(2.3)	(3.5)	(17.5)
Conocophillips Company [Member]
Condensed Financial Statements, Captions [Line Items]
Intercompany return of capital	2.3	3.5	17
Intercompany distribution of earnings			17.5
Intercompany other liabilities	$ (2.3)	$ (3.5)	$ (34.5)

Supplementary Information - 126

Supplementary Information - Condensed Consolidating Financial Information Cash Flow (Details 2) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014		Dec. 31, 2013
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities		$ 7,572	$ 16,412	[1]	$ 15,856	[1]
Net cash provided by (used in) discontinued operations		0	157	[1]	285	[1]
Net Cash Provided by (Used in) Operating Activities		7,572	16,569	[1]	16,141	[1]
Cash Flows From Investing Activities
Capital expenditures and investments		(10,050)	(17,085)	[1]	(15,537)	[1]
Working capital changes associated with investing activities		(968)	180	[1]	(55)	[1]
Proceeds from asset dispositions		1,952	1,603	[1]	10,220	[1]
Net sales (purchases) of short-term investments		0	253	[1]	(263)	[1]
Collection of advances/loans-related parties		105	603	[1]	145	[1]
Other		306	(446)	[1]	(212)	[1]
Net Cash Provided by (Used in) Investing Activities, Continuing Operations		(8,655)	(14,892)	[1]	(5,702)	[1]
Net cash provided by (used in) discontinued operations		0	(73)	[1]	(603)	[1]
Net Cash Provided by (Used in) Investing Activities		(8,655)	(14,965)	[1]	(6,305)	[1]
Cash Flows From Financing Activities
Issuance of debt		2,498	2,994	[1]	0	[1]
Repayment of debt		(103)	(2,014)	[1]	(946)	[1]
Change in restricted cash		0	0	[1]	748	[1]
Issuance of company common stock		(82)	35	[1]	20	[1]
Dividends paid on company common stock		(3,664)	(3,525)	[1]	(3,334)	[1]
Other		(78)	(64)	[1]	(3,621)	[1]
Net cash provided by (used in) continuing financing activities		(1,429)	(2,574)	[1]	(7,133)	[1]
Net cash provided by (used in) discontinued operations		0	0	[1]	0	[1]
Net Cash Provided by (Used in) Financing Activities		(1,429)	(2,574)	[1]	(7,133)	[1]
Effect of Exchange Rate Changes on Cash and Cash Equivalents		(182)	(214)	[1]	(75)	[1]
Net Change in Cash and Cash Equivalents		(2,694)	(1,184)	[1]	2,628	[1]
Cash and cash equivalents at beginning of period		5,062	6,246	[1]	3,618	[1]
Cash and Cash Equivalents at End of Period		2,368	5,062		6,246	[1]
ConocoPhillips [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities		(225)	17,259	[1]	(295)	[1]
Net cash provided by (used in) discontinued operations	[1]		0
Net Cash Provided by (Used in) Operating Activities		(225)	17,259	[1]	(295)	[1]
Cash Flows From Investing Activities
Capital expenditures and investments	[1]		0
Working capital changes associated with investing activities	[1]		0
Proceeds from asset dispositions		3,500	16,912	[1]
Net sales (purchases) of short-term investments	[1]		0
Long-term advances/loans-related parties	[1]		0
Collection of advances/loans-related parties	[1]		0
Intercompany Cash Management		102	(29,113)	[1]	2,511	[1]
Other	[1]		0
Net Cash Provided by (Used in) Investing Activities, Continuing Operations		3,602	(12,201)	[1]	2,511	[1]
Net cash provided by (used in) discontinued operations	[1]		0		0
Net Cash Provided by (Used in) Investing Activities		3,602	(12,201)	[1]	2,511	[1]
Cash Flows From Financing Activities
Issuance of debt	[1]		0
Repayment of debt		0	(1,909)	[1]	0
Change in restricted cash	[1]				748
Issuance of company common stock		283	377	[1]	365	[1]
Dividends paid on company common stock		(3,664)	(3,525)	[1]	(3,334)	[1]
Other		4	(1)	[1]	3	[1]
Net cash provided by (used in) continuing financing activities		(3,377)	(5,058)	[1]	(2,218)	[1]
Net cash provided by (used in) discontinued operations	[1]		0
Net Cash Provided by (Used in) Financing Activities		(3,377)	(5,058)	[1]	(2,218)	[1]
Net Change in Cash and Cash Equivalents		0			(2)	[1]
Cash and cash equivalents at beginning of period			0		2
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		245	2,948	[1]	22,928	[1]
Net cash provided by (used in) discontinued operations		0	202	[1]	91	[1]
Net Cash Provided by (Used in) Operating Activities		245	3,150	[1]	23,019	[1]
Cash Flows From Investing Activities
Capital expenditures and investments		(3,064)	(6,507)	[1]	(4,821)	[1]
Working capital changes associated with investing activities		(4)	17	[1]	68	[1]
Proceeds from asset dispositions		826	1,588	[1]	2,633	[1]
Net sales (purchases) of short-term investments		0	0	[1]
Long-term advances/loans-related parties		(278)	(736)	[1]	(342)	[1]
Collection of advances/loans-related parties		0	593	[1]	174	[1]
Intercompany Cash Management		46	31,993	[1]	(15,919)	[1]
Other		304	(415)	[1]	21	[1]
Net Cash Provided by (Used in) Investing Activities, Continuing Operations		(2,170)	26,533	[1]	(18,186)	[1]
Net cash provided by (used in) discontinued operations		0	133	[1]	(52)	[1]
Net Cash Provided by (Used in) Investing Activities		(2,170)	26,666	[1]	(18,238)	[1]
Cash Flows From Financing Activities
Issuance of debt		4,743	2,994	[1]	522	[1]
Repayment of debt		(100)	(16)	[1]	(2,924)	[1]
Issuance of company common stock		0	0	[1]
Dividends paid on company common stock		0	(17,588)	[1]
Other		(3,484)	(16,870)	[1]	52	[1]
Net cash provided by (used in) continuing financing activities		1,159	(31,480)	[1]	(2,350)	[1]
Net cash provided by (used in) discontinued operations		0	0	[1]	0	[1]
Net Cash Provided by (Used in) Financing Activities		1,159	(31,480)	[1]	(2,350)	[1]
Effect of Exchange Rate Changes on Cash and Cash Equivalents	[1]				(9)
Net Change in Cash and Cash Equivalents		(766)	(1,664)	[1]	2,422	[1]
Cash and cash equivalents at beginning of period		770	2,434		12
Cash and Cash Equivalents at End of Period		4	770		2,434
ConocoPhillips Australia Funding Company [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities	[1]				(2)
Net Cash Provided by (Used in) Operating Activities	[1]				(2)
Cash Flows From Investing Activities
Collection of advances/loans-related parties	[1]				750
Intercompany Cash Management	[1]				0
Other	[1]				0
Net Cash Provided by (Used in) Investing Activities, Continuing Operations	[1]				750
Net cash provided by (used in) discontinued operations	[1]				0
Net Cash Provided by (Used in) Investing Activities	[1]				750
Cash Flows From Financing Activities
Repayment of debt	[1]				(750)
Dividends paid on company common stock	[1]				(4)
Net cash provided by (used in) continuing financing activities	[1]				(754)
Net cash provided by (used in) discontinued operations	[1]				0
Net Cash Provided by (Used in) Financing Activities	[1]				(754)
Net Change in Cash and Cash Equivalents	[1]				(6)
Cash and cash equivalents at beginning of period					6
ConocoPhillips Canada Funding Company I [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities		9	27	[1]	1	[1]
Net Cash Provided by (Used in) Operating Activities		9	27	[1]	1	[1]
Cash Flows From Investing Activities
Long-term advances/loans-related parties		0	(241)	[1]	0
Collection of advances/loans-related parties		0	0		169	[1]
Net Cash Provided by (Used in) Investing Activities, Continuing Operations		0	(241)	[1]	169	[1]
Net Cash Provided by (Used in) Investing Activities		0	(241)	[1]	169	[1]
Cash Flows From Financing Activities
Issuance of debt					0
Repayment of debt					0
Net cash provided by (used in) continuing financing activities					0
Net Cash Provided by (Used in) Financing Activities	[1]				0
Effect of Exchange Rate Changes on Cash and Cash Equivalents		(1)	(8)	[1]	0	[1]
Net Change in Cash and Cash Equivalents		8	(222)	[1]	170	[1]
Cash and cash equivalents at beginning of period		7	229		59
Cash and Cash Equivalents at End of Period		15	7		229
All Other Subsidiaries [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities		7,519	16,941	[1]	14,510	[1]
Net cash provided by (used in) discontinued operations		0	408	[1]	642	[1]
Net Cash Provided by (Used in) Operating Activities		7,519	17,349	[1]	15,152	[1]
Cash Flows From Investing Activities
Capital expenditures and investments		(8,386)	(14,840)	[1]	(13,566)	[1]
Working capital changes associated with investing activities		(964)	163	[1]	(123)	[1]
Proceeds from asset dispositions		1,225	253	[1]	9,745	[1]
Net sales (purchases) of short-term investments		0	253	[1]	(263)	[1]
Long-term advances/loans-related parties		(2,245)	(7)	[1]	(545)	[1]
Collection of advances/loans-related parties		205	112	[1]	3,010	[1]
Intercompany Cash Management		(148)	(2,880)	[1]	13,408	[1]
Other		1	(31)	[1]	(233)	[1]
Net Cash Provided by (Used in) Investing Activities, Continuing Operations		(10,312)	(16,977)	[1]	11,433	[1]
Net cash provided by (used in) discontinued operations		0	(73)	[1]	(603)	[1]
Net Cash Provided by (Used in) Investing Activities		(10,312)	(17,050)	[1]	10,830	[1]
Cash Flows From Financing Activities
Issuance of debt		278	984	[1]	365	[1]
Repayment of debt		(103)	(191)	[1]	(1,230)	[1]
Issuance of company common stock		(2)
Dividends paid on company common stock		(339)	(3,768)	[1]	(21,984)	[1]
Other		1,204	3,919	[1]	(2,984)	[1]
Net cash provided by (used in) continuing financing activities		1,038	944	[1]	(25,833)	[1]
Net cash provided by (used in) discontinued operations		0	(335)	[1]	(39)	[1]
Net Cash Provided by (Used in) Financing Activities		1,038	609	[1]	(25,872)	[1]
Effect of Exchange Rate Changes on Cash and Cash Equivalents		(181)	(206)	[1]	(66)	[1]
Net Change in Cash and Cash Equivalents		(1,936)	702	[1]	44	[1]
Cash and cash equivalents at beginning of period		4,285	3,583		3,539
Cash and Cash Equivalents at End of Period		2,349	4,285		3,583
Consolidating Adjustments [Member]
Cash Flows From Operating Activities
Net cash provided by (used in) continuing operating activities		24	(20,763)	[1]	(21,286)	[1]
Net cash provided by (used in) discontinued operations		0	(453)	[1]	(448)	[1]
Net Cash Provided by (Used in) Operating Activities		24	(21,216)	[1]	(21,734)	[1]
Cash Flows From Investing Activities
Capital expenditures and investments		1,400	4,262	[1]	2,850	[1]
Proceeds from asset dispositions		(3,599)	(17,150)	[1]	(2,158)	[1]
Long-term advances/loans-related parties		2,523	984	[1]	887	[1]
Collection of advances/loans-related parties		(100)	(102)	[1]	(3,958)	[1]
Other		1
Net Cash Provided by (Used in) Investing Activities, Continuing Operations		225	(12,006)	[1]	(2,379)	[1]
Net cash provided by (used in) discontinued operations		0	(133)	[1]	52	[1]
Net Cash Provided by (Used in) Investing Activities		225	(12,139)	[1]	(2,327)	[1]
Cash Flows From Financing Activities
Issuance of debt		(2,523)	(984)	[1]	(887)	[1]
Repayment of debt		100	102	[1]	3,958	[1]
Issuance of company common stock		(363)	(342)	[1]	(345)	[1]
Dividends paid on company common stock		339	21,356	[1]	21,988	[1]
Other		2,198	12,888	[1]	(692)	[1]
Net cash provided by (used in) continuing financing activities		(249)	33,020	[1]	24,022	[1]
Net cash provided by (used in) discontinued operations		0	335	[1]	39	[1]
Net Cash Provided by (Used in) Financing Activities		$ (249)	$ 33,355	[1]	$ 24,061	[1]
[1]	*Certain amounts have been reclassified to conform to current-period presentation. See Note 21—Cash Flow Information, in the Notes to Consolidated Financial Statements.

Schedule ll (Details)

Schedule ll (Details) - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Allowance for Doubtful Accounts [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at January 1		$ 5	$ 8	$ 10
Charged to Expense		4	0	0
Other	[1]	(2)	(2)	0
Deductions	[2]	0	(1)	(2)
Balance at December 31		7	5	8
Valuation Allowance of Deferred Tax Assets [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at January 1		970	969	1,345
Charged to Expense		6	127	(357)
Other	[1]	(21)	(26)	3
Deductions		(221)	(100)	(22)
Balance at December 31		734	970	969
Business Restructuring Reserves [Member]
Valuation and Qualifying Accounts Disclosure [Line Items]
Balance at January 1		61	19	17
Charged to Expense		303	71	10
Other	[1]	(8)	(6)	(1)
Deductions	[3]	(200)	(23)	(7)
Balance at December 31		$ 156	$ 61	$ 19
[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.