0001562762-21-000027 | 10-K | XBRL Viewer

Prior service (cost) credit arising during the period

$ (2,655)

$ 7,257

$ 6,305

Defined benefit plans

(7)

Reclassification adjustment for amortization of prior service credit included in net income (loss)

(32)

(35)

(40)

Net change during the period

(3)

(35)

(47)

Net actuarial loss arising during the period

(210)

(55)

(150)

Reclassification adjustment for amortization of prior service credit included in net income (loss)

117

146

279

Net change

(93)

129

Nonsponsored plans

^[1]

(3)

(1)

Income taxes on defined benefit plans

(2)

(42)

Defined benefit plans, net of tax

(75)

Unrealized holding gain on securities

Unrealized gain on securities, net of tax

Foreign currency translation adjustments

209

699

(645)

Income taxes on foreign currency translation adjustments

(4)

Foreign currency translation adjustments, net of tax

212

695

(642)

Other comprehensive income (loss), net of tax

139

746

(603)

Comprehensive income (loss)

(2,516)

8,003

5,702

Less: comprehensive income attributable to noncontrolling interests

(46)

(68)

(48)

Comprehensive Income (Loss) Attributable to ConocoPhillips

$ (2,562)

$ 7,935

$ 5,654

[1]	<div>Plans for which ConocoPhillips is not the primary obligor—primarily those administered by equity affiliates.</div>

Consolidated Balance Sheet - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Assets
Cash and cash equivalents	$ 2,991,000,000	$ 5,088,000,000
Short-term Investments	3,609,000,000	3,028,000,000
Accounts and notes receivable (net of allowance of $4 and $13, respectively)	2,634,000,000	3,267,000,000
Accounts and notes receivable-related parties	120,000,000	134,000,000
Investment in Cenovus Energy	1,256,000,000	2,111,000,000
Inventories	1,002,000,000	1,026,000,000
Prepaid expenses and other current assets	454,000,000	2,259,000,000
Total Current Assets	12,066,000,000	16,913,000,000
Investments and long-term receivables	8,017,000,000	8,687,000,000
Loans and advances-related parties	114,000,000	219,000,000
Net properties, plants and equipment (net of accumulated DD&A of $62,213 and $55,477, respectively)	39,893,000,000	42,269,000,000
Other assets	2,528,000,000	2,426,000,000
Total Assets	62,618,000,000	70,514,000,000
Liabilities
Accounts payable	2,669,000,000	3,176,000,000
Accounts payable-related parties	29,000,000	24,000,000
Short-term debt	619,000,000	105,000,000
Accrued income and other taxes	320,000,000	1,030,000,000
Employee benefit obligations	608,000,000	663,000,000
Other accruals	1,121,000,000	2,045,000,000
Total Current Liabilities	5,366,000,000	7,043,000,000
Long-term debt	14,750,000,000	14,790,000,000
Long-term asset retirement obligations and accrued environmental costs	5,430,000,000	5,352,000,000
Deferred taxes Included in long-term liabilities	3,747,000,000	4,634,000,000
Employee benefit obligations	1,697,000,000	1,781,000,000
Other liabilities and deferred credits	1,779,000,000	1,864,000,000
Total Liabilities	32,769,000,000	35,464,000,000
Equity
Common stock (2,500,000,000 shares authorized at $0.01 par value) Issued (2020 - 1,798,844,267 shares; 2019 - 1,795,652,203 shares)	18,000,000	18,000,000
Capital in excess of par	47,133,000,000	46,983,000,000
Treasury stock (at cost: 2020 - 730,802,089 shares; 2019 - 710,783,814 shares)	(47,297,000,000)	(46,405,000,000)
Accumulated other comprehensive income (loss)	(5,218,000,000)	(5,357,000,000)
Retained earnings	35,213,000,000	39,742,000,000
Total Common Stockholders' Equity	29,849,000,000	34,981,000,000
Noncontrolling interests	0	69,000,000
Total Equity	29,849,000,000	35,050,000,000
Total Liabilities and Equity	$ 62,618,000,000	$ 70,514,000,000

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Consolidated Balance Sheet [Abstract]
Allowance for accounts and notes receivable	$ 4	$ 13
Accumulated depreciation, depletion and amortization	$ 62,213	$ 55,477
Common stock, shares authorized	2,500,000,000	2,500,000,000
Common stock, par value	$ 0.01	$ 0.01
Common stock, shares issued	1,798,844,267	1,795,652,203
Treasury stock, shares	730,802,089	710,783,814

Consolidated Statement of Cash Flows - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2020

Dec. 31, 2019

Dec. 31, 2018

Cash Flows From Operating Activities

Adjustments to reconcile net income to net cash provided by operating activities

$ (2,655)

$ 7,257

$ 6,305

Depreciation, depletion and amortization

5,521

6,090

5,956

Impairments

813

405

Dry hole costs and leasehold impairments related to exploration only

1,083

421

Accretion on discounted liabilities

252

326

353

Deferred taxes

(834)

(444)

283

Undistributed equity earnings

645

594

152

Gain on dispositions

(549)

(1,966)

(1,063)

Unrealized (gain) loss on investment in Cenovus Energy

855

(649)

437

Decrease in accounts and notes receivable

(351)

(246)

Working capital adjustments

521

505

235

Decrease (increase) in inventories

(25)

(67)

Decrease (increase) in prepaid expenses and other current assets

(55)

Decrease in accounts payable

(249)

(378)

(52)

Increase (decrease) in taxes and other accruals

(695)

(676)

421

Net Cash Provided by Operating Activities

4,802

11,104

12,934

Cash Flows From Investing Activities

Capital expenditures and investments

(4,715)

(6,636)

(6,750)

Working capital charges associated with investing activities

(155)

(103)

(68)

Proceeds from asset dispositions

1,317

3,012

1,082

Net Sales (Purchases) of Investments

(658)

(2,910)

1,620

Collections of advances/loans - related parties

116

127

119

Net Cash Used in Investing Activities

(26)

(108)

154

(4,121)

(6,618)

(3,843)

Cash Flows From Financing Activities

Issuance of debt

300

Repayment of debt

(254)

(80)

(4,995)

Issuance of company common stock

(5)

(30)

121

Repurchase of company common stock

(892)

(3,500)

(2,999)

(1,831)

(1,500)

(1,363)

Net Cash Provided by (Used in) Financing Activities

(26)

(119)

(123)

(2,708)

(5,229)

(9,359)

Effect of Exchange Rate Changes on Cash and Cash Equivalents and Restricted Cash

(20)

(46)

(117)

Net Change in Cash and Cash Equivalents and Restricted Cash Increase (Decrease)

(2,047)

(789)

(385)

Cash and Cash Equivalents and Restricted Cash at beginning of period

5,362

^[1]

6,151

^[1]

6,536

Cash and Cash Equivalents and Restricted Cash at end of period

^[1]

$ 3,315

$ 5,362

$ 6,151

[1]	See Notes to Consolidated Financial Statements.

Consolidated Statement of Cash Flows (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Other Assets [Member]
Restricted Cash	$ 230	$ 184
Prepaid Expenses and Other Current Assets [Member]
Restricted Cash	$ 94	$ 90

Consolidated Statement of Changes in Equity - USD ($)
$ in Millions

Total

Common Stock [Member]

Capital in excess of par

Treasury Stock [Member]

Accumulated Other Comprehensive Income (Loss) [Member]

Retained Earnings [Member]

Noncontrolling Interest [Member]

Beginning Balance at Dec. 31, 2017

$ 30,801

$ 18

$ 46,622

$ (39,906)

$ (5,518)

$ 29,391

$ 194

Other comprehensive income (loss)

6,305

6,257

(603)

Treasury Stock Value Acquired Cost Method

(1,363)

(2,999)

Distributions to noncontrolling interests and other

(121)

Distributed under benefit plans

257

Ending Balance at Dec. 31, 2018

32,064

46,879

(42,905)

(6,063)

34,010

125

Changes in Accounting Principles

^[1]

(220)

(278)

Other comprehensive income (loss)

7,257

7,189

746

Treasury Stock Value Acquired Cost Method

(1,500)

(3,500)

Distributions to noncontrolling interests and other

(128)

Distributed under benefit plans

104

Ending Balance at Dec. 31, 2019

35,050

46,983

(46,405)

(5,357)

39,742

Changes in Accounting Principles

^[2]

(40)

Other comprehensive income (loss)

(2,655)

(2,701)

139

Treasury Stock Value Acquired Cost Method

(1,831)

(892)

Distributions to noncontrolling interests and other

(32)

Disposition

(84)

Distributed under benefit plans

150

Ending Balance at Dec. 31, 2020

$ 29,849

$ 18

$ 47,133

$ (47,297)

$ (5,218)

$ 35,213

$ 0

[1]	<div>*Cumulative effect of the adoption of ASC Topic 606, "Revenue from Contracts with Customers," and ASU No. 2016-01, "Recognition and Measurement of Financial Assets and Liabilities," at January 1, 2018.</div>
[2]	<div>**Cumulative effect of the adoption of ASU No. 2018-02, "Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income." See Notes to Consolidated Financial Statements.</div>

Consolidated Statement of Changes in Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Statement of Stockholders' Equity [Abstract]
Common Stock, Dividends, Per Share, Cash Paid	$ 1.69	$ 1.34	$ 1.16

Accounting Policies	12 Months Ended
Accounting Policies	Dec. 31, 2020
Accounting Policies [Abstract]
Accounting Policies	Note 1—Accounting Policies ■ Consolidation Principles and Investments —Our consolidated financial statements include the accounts of majority-owned, controlled subsidiaries and variable interest entities where we are the primary beneficiary. The equity method is used to account for investments in affiliates in which we have the ability to exert significant influence over the affiliates’ operating and financial policies. When we do not have the ability to exert significant influence, the investment is measured at fair value except when the investment does not have a readily determinable fair value. For those exceptions, it will be measured at cost minus impairment, plus or minus observable price changes in orderly transactions for an identical or similar investment of the same issuer. 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, Middle East and North Africa; Asia Pacific; and Other International. For additional information, see Note 24—Segment Disclosures and Related Information. The unrealized (gain) loss on investment in Cenovus Energy included on our consolidated statement of cash flows, previously reflected on the line item “Other” within net cash provided by operating activities, has been reclassified in the comparative periods to conform with the current period’s presentation. ■ 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 loss in common stockholders’ equity. Foreign currency transaction gains and losses are included in current earnings. Some 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 U.S. 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 the sales of crude oil, bitumen, natural gas, LNG, NGLs and other items are recognized at the point in time when the customer obtains control of the asset. In evaluating when a customer has control of the asset, we primarily consider whether the transfer of legal title and physical delivery has occurred, whether the customer has significant risks and rewards of ownership, and whether the customer has accepted delivery and a right to payment exists. These products are typically sold at prevailing market prices. We allocate variable market-based consideration to deliveries (performance obligations) in the current period as that consideration relates specifically to our efforts to transfer control of current period deliveries to the customer and represents the amount we expect to be entitled to in exchange for the related products. Payment is typically due within 30 days or less. 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 typically incur shipping and handling costs prior to control transferring to the customer and account for these activities as fulfillment costs. Accordingly, we include shipping and handling costs in production and operating expenses for production activities. Transportation costs related to marketing activities are recorded in purchased commodities. Freight costs billed to customers are treated as a component of the transaction price and recorded as a component of revenue when the customer obtains control. ■ 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 include investments in bank time deposits and marketable securities (commercial paper and government obligations) which are carried at cost plus accrued interest and have original maturities of greater than 90 days but within one year or when the remaining maturities are within one year. We also invest in financial instruments classified as available for sale debt securities which are carried at fair value. Those instruments are included in short-term investments when they have remaining maturities within one year as of the balance sheet date. ■ Long-Term Investments in Debt Securities —Long-term investments in debt securities includes financial instruments classified as available for sale debt securities with remaining maturities greater than one year as of the balance sheet date. They are carried at fair value and presented within the “Investments and long-term receivables” line of our consolidated balance sheet. ■ Inventories —We have several valuation methods for our various types of inventories and consistently use the following methods for each type of inventory. The majority of our commodity-related inventories are recorded at cost using the LIFO basis. We measure these inventories at the lower-of-cost-or-market in the aggregate. Any necessary lower-of-cost-or-market write-downs at year end are recorded as permanent adjustments to the LIFO cost basis. LIFO is used to better match current inventory costs with current revenues. Costs include both direct and indirect expenditures incurred in bringing an item or product to its existing condition and location, but not unusual/nonrecurring costs or research and development costs. Materials, supplies and other miscellaneous inventories, such as tubular goods and well equipment, are valued using various methods, including the weighted-average-cost method, and the FIFO method, consistent with industry practice. ■ Fair Value Measurements —Assets and liabilities measured at fair value and required to be categorized within the fair value hierarchy are categorized into one of three different levels depending on the observability of the inputs employed in the measurement. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting significant modifications to observable related market data or our assumptions about pricing by market participants. ■ Derivative Instruments —Derivative instruments are recorded on the balance sheet at fair value. If the right of offset exists and certain 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 the derivative. Gains and losses from derivatives not accounted for as hedges are recognized immediately in earnings. We do not apply hedge accounting on our derivative instruments. ■ Oil and Gas Exploration and Development —Oil and gas exploration and development costs are accounted for using the successful efforts method of accounting. Property Acquisition Costs —Oil and gas leasehold acquisition costs are capitalized and included in the balance sheet caption 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 reclassified to proved properties. Exploratory Costs —Geological and geophysical costs and the costs of carrying and retaining undeveloped properties are expensed as incurred. Exploratory well costs are capitalized, or “suspended,” on the balance sheet pending further evaluation of whether economically recoverable reserves have been found. If economically recoverable reserves are not found, exploratory well costs are expensed as dry holes. If exploratory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For complex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on the balance sheet for several years while we perform additional appraisal drilling and seismic work on the potential oil and gas field or while we seek government or co-venturer approval of development plans or seek environmental permitting. Once all required approvals and permits have been obtained, the projects are moved into the development phase, and the oil and gas resources are designated as proved 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 7— Suspended Wells and Exploration Expenses, for additional information on suspended wells. Development Costs —Costs incurred to drill and equip development wells, including unsuccessful development wells, are capitalized. Depletion and Amortization —Leasehold costs of producing properties are depleted using the unit- of-production method based on estimated proved oil and gas reserves. Amortization of intangible development costs is based on the unit-of-production method using estimated proved developed oil and gas reserves. ■ Capitalized Interest —Interest from external borrowings is capitalized on major projects with an expected construction period of one year or longer. Capitalized interest is added to the cost of the underlying asset and is amortized over the useful lives of the assets in the same manner as the underlying assets. ■ Depreciation and Amortization —Depreciation and amortization of PP&E on producing hydrocarbon properties and SAGD facilities and certain pipeline and LNG assets (those which are expected to have a declining utilization pattern), are determined by the unit-of-production method. Depreciation and amortization of all other PP&E are determined by either the individual-unit-straight-line method or the group-straight-line method (for those individual units that are highly integrated with other units). ■ Impairment of Properties, Plants and Equipment —PP&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. If there is an indication the carrying amount of an asset may not be recovered, a recoverability test is performed using management’s assumptions such as for prices, volumes and future development plans. If, upon review, the sum of the undiscounted cash flows before income-taxes is less than the carrying value of the asset group, the carrying value is written down to estimated fair value and reported as an impairment in the period 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 independent of the cash flows of other groups of assets—generally on a field-by-field basis for E&P assets. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates and prices 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 available, or present value of expected future cash flows as previously described. The expected future cash flows used for impairment reviews and related fair value calculations are based on estimated future production volumes, prices and costs, considering all available evidence at the date of review. The impairment review includes cash flows from proved developed and undeveloped reserves, including any development expenditures necessary to achieve that production. Additionally, when probable and possible reserves exist, an appropriate risk-adjusted amount of these reserves may be included in the impairment calculation. ■ Impairment of Investments in Nonconsolidated Entities —Investments in nonconsolidated entities are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred. When such a condition is judgmentally determined to be other than temporary, the carrying value of the investment is written 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 and prices believed to be consistent with those used by principal market participants, plus market analysis of comparable assets owned by the investee, if appropriate. ■ Maintenance and Repairs —Costs of maintenance and repairs, which are not significant improvements, are expensed when incurred. ■ Property Dispositions —When complete units of depreciable property are sold, the asset cost and related accumulated depreciation are eliminated, with any gain or loss reflected in the “Gain on dispositions” line of our consolidated income statement. When less than complete units of depreciable property are disposed of or retired which do not significantly alter the DD&A rate, 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 long-lived assets are recorded in the period in which the obligation is incurred (typically when the asset is installed at the production location). Fair value is estimated using a present value approach, incorporating assumptions about estimated amounts and timing of settlements and impacts of the use of technologies. 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 depreciated over the useful life of the related asset. Reductions to estimated liabilities for assets that are no longer producing are recorded as a credit to impairment, if the asset had been previously impaired, or as a credit to DD&A, if the asset had not been previously impaired. For additional information, see Note 9—Asset Retirement Obligations and Accrued Environmental Costs. Environmental expenditures are expensed or capitalized, depending upon their future economic benefit. 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 through a business combination, which we record on a discounted basis) when environmental assessments or cleanups are probable and the costs can be reasonably estimated. Recoveries of environmental remediation costs from other parties are recorded as assets when their receipt is probable and estimable. ■ Guarantees —The fair value of a guarantee is determined and recorded as a liability at the time the guarantee is given. The initial liability is subsequently reduced as we are released from exposure under the guarantee. We amortize the guarantee liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of guarantee. In cases where the guarantee term is indefinite, we reverse the liability when we have information indicating the liability is essentially relieved or amortize it over an appropriate time period as the fair value of our guarantee exposure declines over time. We amortize the guarantee liability to the related income statement line item based on the nature of the guarantee. When it becomes probable that we will have to perform on a guarantee, we accrue a separate liability if it is reasonably estimable, based on the facts and circumstances at that time. We reverse the fair value liability only when there is no further exposure under the guarantee. ■ Share-Based Compensation —We recognize share-based compensation expense over the shorter of the service period (i.e., the stated period of time required to 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 cumulative translation adjustment considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures. Allowable tax credits are applied currently as reductions of the provision for income taxes. Interest related to unrecognized tax benefits is reflected in interest and debt expense, and penalties related to unrecognized tax benefits are reflected in production and operating expenses. ■ Taxes Collected from Customers and Remitted to Governmental Authorities —Sales and value- added taxes are recorded net. ■ Net Income (Loss) Per Share of Common Stock —Basic net income (loss) per share of common stock is calculated based upon the daily weighted-average number of common shares outstanding during the year. Also, this calculation includes fully vested stock and unit awards that have not yet been issued as common stock, along with an adjustment to net income (loss) for dividend equivalents paid on unvested unit awards that are considered participating securities. Diluted net income per share of common stock includes unvested stock, unit or option awards granted under our compensation plans and vested but unexercised stock options, but only to the extent these instruments dilute net income per share, primarily under the treasury-stock method. Diluted net loss per share, which is calculated the same as basic net loss per share, does not assume conversion or exercise of securities that would have an antidilutive effect. Treasury stock is excluded from the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the participating securities is immaterial.

Change in Accounting Priniciples	12 Months Ended
Change in Accounting Priniciples	Dec. 31, 2020
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Standards [Text Block]	Note 2—Changes in Accounting Principles We adopted the provisions of FASB ASU No. 2016-13, “Measurement of Credit Losses on Financial Instruments,” (ASC Topic 326) and its amendments, beginning January 1, 2020. This ASU, as amended, sets forth the current expected credit loss model, a new forward-looking impairment model for certain financial instruments measured at amortized cost basis based on expected losses rather than incurred losses. This ASU, as amended, which primarily applies to our accounts receivable, also requires credit losses related to available- for-sale debt securities to be recorded through an allowance for credit losses. The adoption of this ASU did not have a material impact to our financial statements. The majority of our receivables are due within 30 days or less. We monitor the credit quality of our counterparties through review of collections, credit ratings, and other analyses. We develop our estimated allowance for credit losses primarily using an aging method and analyses of historical loss rates as well as consideration of current and future conditions that could impact our counterparties’ credit quality and liquidity.

The entire disclosure for change in accounting principle. Includes, but is not limited to, nature, reason, and method of adopting amendment to accounting standards or other change in accounting principle.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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-Name Accounting Standards Codification
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Reference 3: http://www.xbrl.org/2003/role/disclosureRef
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Reference 6: http://www.xbrl.org/2003/role/disclosureRef
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Reference 7: http://www.xbrl.org/2003/role/disclosureRef
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Inventories	12 Months Ended
Inventories	Dec. 31, 2020
Inventories [Abstract]
Inventories	Note 3—Inventories Inventories at December 31 were: Millions of Dollars 2020 2019 Crude oil and natural gas $ 461 472 Materials and supplies 541 554 $ 1,002 1,026 Inventories valued on the LIFO basis totaled $ 282 million and $ 286 million at December 31, 2020 and 2019, respectively. In the first quarter of 2020, we recorded a lower of cost or market adjustment of $ 228 million to our crude oil and natural gas inventories, which is included in the “Purchased commodities” line on our consolidated income statement. Commodity prices have since improved. The estimated excess of current replacement cost over LIFO cost of inventories was approximately $ 87 million and $ 155 million at December 31, 2020 and 2019, respectively.

Assets Acquisitions and Dispositions	12 Months Ended
Assets Acquisitions and Dispositions	Dec. 31, 2020
Disposal Group Not Discontinued Operation Disposal Disclosures [Abstract]
Long Lived Assets Held For Sale [Text Block]	Note 4—Asset Acquisitions and Dispositions All gains or losses on asset dispositions are reported before-tax and are included net in the “Gain on dispositions” line on our consolidated income statement. All cash proceeds and payments are included in the “Cash Flows From Investing Activities” section of our consolidated statement of cash flows. On January 15, 2021, we completed our acquisition of Concho Resources Inc. (Concho), an independent oil and gas exploration and production company with operations across New Mexico and West Texas focused in the Permian Basin. Total consideration for the all-stock transaction was valued at $ 13.1 billion, in which 1.46 shares of ConocoPhillips common stock was exchanged for each outstanding share of Concho common stock, resulting in the issuance of approximately 286 million shares of ConocoPhillips common stock. We also assumed $ 3.9 billion in aggregate principal amount of outstanding debt for Concho, which was recorded at fair value of $ 4.7 billion as of the closing date. For additional information related to this transaction, see Note 25—Acquisition of Concho Resources Inc. 2020 Asset Acquisition In August 2020, we completed the acquisition of additional Montney acreage in Canada from Kelt Exploration Ltd. for $ 382 million after customary adjustments, plus the assumption of $ 31 million in financing obligations associated with partially owned infrastructure. This acquisition consisted primarily of undeveloped properties and included 140,000 net acres in the liquids-rich Inga Fireweed asset Montney zone, which is directly adjacent to our existing Montney position. The transaction increased our Montney acreage position to approximately 295,000 net acres with a 100 percent working interest. This agreement was accounted for as an asset acquisition resulting in the recognition of $ 490 million of PP&E; $ 77 million of ARO and accrued environmental costs; and $ 31 million of financing obligations recorded primarily to long-term debt. Results of operations for the Montney asset are reported in our Canada segment. Assets Sold In February 2020, we sold our Waddell Ranch interests in the Permian Basin for $ 184 million after customary adjustments. No gain or loss was recognized on the sale. Results of operations for the Waddell Ranch interests sold were reported in our Lower 48 segment. In March 2020, we completed the sale of our Niobrara interests for approximately $ 359 million after customary adjustments and recognized a before-tax loss on disposition of $ 38 million. At the time of disposition, our interest in Niobrara had a net carrying value of $ 397 million, consisting primarily of $ 433 million of PP&E and $ 34 million of ARO. The before-tax losses associated with our interests in Niobrara, including the loss on disposition noted above and an impairment of $ 386 million recorded when we signed an agreement to sell our interests in the fourth quarter of 2019, were $ 25 million and $ 372 million for the years ended December 31, 2020 and 2019, respectively. The before-tax earnings associated with our interests in Niobrara for the year ended December 31, 2018 was $ 35 million. Results of operations for the Niobrara interests sold were reported in our Lower 48 segment. In May 2020, we completed the divestiture of our subsidiaries that held our Australia-West assets and operations, and based on an effective date of January 1, 2019, we received proceeds of $ 765 million with an additional $ 200 million due upon final investment decision of the proposed Barossa development project. We recognized a before-tax gain of $ 587 million related to this transaction in 2020. At the time of disposition, the net carrying value of the subsidiaries sold was approximately $ 0.2 billion, excluding $ 0.5 billion of cash. The net carrying value consisted primarily of $ 1.3 billion of PP&E and $ 0.1 billion of other current assets offset by $ 0.7 billion of ARO, $ 0.3 billion of deferred tax liabilities, and $ 0.2 billion of other liabilities. The before-tax earnings associated with the subsidiaries sold, including the gain on disposition noted above, were $ 851 million, $ 372 million and $ 364 million for the years ended December 31, 2020, 2019 and 2018, respectively. Production from the beginning of the year through the disposition date in May 2020 averaged 43 MBOED. Results of operations for the subsidiaries sold were reported in our Asia Pacific segment. 2019 Assets Sold In January 2019, we entered into agreements to sell our 12.4 percent ownership interests in the Golden Pass LNG Terminal and Golden Pass Pipeline. We also entered into agreements to amend our contractual obligations for retaining use of the facilities. As a result of entering into these agreements, we recorded a before-tax impairment of $ 60 million in the first quarter of 2019 which is included in the “Equity in earnings of affiliates” line on our consolidated income statement. We completed the sale in the second quarter of 2019. Results of operations for these assets were reported in our Lower 48 segment. See Note 14—Fair Value Measurement for additional information. In April 2019, we entered into an agreement to sell two ConocoPhillips U.K. subsidiaries to Chrysaor E&P Limited for $ 2.675 billion plus interest and customary adjustments, with an effective date of January 1, 2018. On September 30, 2019, we completed the sale for proceeds of $ 2.2 billion and recognized a $ 1.7 billion before-tax and $ 2.1 billion after-tax gain associated with this transaction in 2019. Together the subsidiaries sold indirectly held our exploration and production assets in the U.K. At the time of disposition, the net carrying value was approximately $ 0.5 billion, consisting primarily of $ 1.6 billion of PP&E, $ 0.5 billion of cumulative foreign currency translation adjustments, and $ 0.3 billion of deferred tax assets, offset by $ 1.8 billion of ARO and negative $ 0.1 billion of working capital. The before-tax earnings associated with the subsidiaries sold, including the gain on dispositions noted above, were $ 2.1 billion and $ 0.9 billion for the years ended December 31, 2019 and 2018, respectively. Results of operations for the U.K. were reported within our Europe, Middle East and North Africa segment. In the second quarter of 2019, we recognized an after-tax gain of $ 52 million upon the closing of the sale of our 30 percent interest in the Greater Sunrise Fields to the government of Timor-Leste for $ 350 million. The Greater Sunrise Fields were included in our Asia Pacific segment. In the fourth quarter of 2019, we sold our interests in the Magnolia field and platform for net proceeds of $ 16 million and recognized a before-tax gain of $ 82 million. At the time of sale, the net carrying value consisted of $ 4 million of PP&E offset by $ 70 million of ARO. The Magnolia results of operations were reported within our Lower 48 segment. 2018 Assets Sold In the first quarter of 2018, we completed the sale of certain properties in the Lower 48 segment for net proceeds of $ 112 million. No gain or loss was recognized on the sale. In the second quarter of 2018, we completed the sale of a package of largely undeveloped acreage in the Lower 48 segment for net proceeds of $ 105 million and no gain or loss was recognized on the sale. In the third quarter of 2018, we completed a noncash exchange of undeveloped acreage in the Lower 48 segment. The transaction was recorded at fair value resulting in the recognition of a $ 56 million gain. In the fourth quarter of 2018, we sold several packages of undeveloped acreage in the Lower 48 segment for total net proceeds of $ 162 million and recognized gains of approximately $ 140 million. On October 31, 2018, we completed the sale of our interests in the Barnett to Lime Rock Resources for $ 196 million after customary adjustments and recognized a loss of $ 5 million. We recorded an impairment of $87 million in 2018 to reduce the net carrying value of the Barnett to fair value. At the time of the disposition, our interest in Barnett had a net carrying value of $ 201 million, consisting of $ 250 million of PP&E and $ 49 million of AROs. The before-tax loss associated with our interests in the Barnett, including both the impairment and loss on disposition noted above, was $ 59 million for the year ended December 31, 2018. The Barnett results of operations were included in our Lower 48 segment. On December 18, 2018, we completed the sale of a ConocoPhillips subsidiary to BP. The subsidiary held 16.5 percent of our 24 percent interest in the BP-operated Clair Field in the U.K. We retained a 7.5 percent interest in the field. At the same time, we acquired BP’s 39.2 percent nonoperated interest in the Greater Kuparuk Area in Alaska, including their 38 percent interest in the Kuparuk Transportation Company (Kuparuk Assets). The transaction was recorded at a fair value of $ 1,743 million and was cash neutral except for customary adjustments which resulted in net proceeds of $ 253 million. At closing, our interest in the Clair Field had a net carrying value of approximately $ 1,028 million consisting primarily of $ 1,553 million of PP&E, $ 485 million of deferred tax liabilities, and $ 59 million of AROs. We recognized a before-tax gain of $ 715 million on the transaction. The 2018 before-tax earnings associated with our 16.5 percent interest in the Clair Field, including the recognized gain, were $ 748 million. Results of operations for our interest in the Clair Field are reported within our Europe, Middle East and North Africa segment and the Kuparuk Assets were included in our Alaska segment. Acquisitions In May 2018, we completed the acquisition of Anadarko’s 22 percent nonoperated interest in the Western North Slope of Alaska, as well as its interest in the Alpine Transportation Pipeline for $ 386 million, after customary adjustments. This transaction was accounted for as a business combination resulting in the recognition of approximately $ 297 million of proved property and $ 114 million of unproved property within PP&E, $ 20 million of inventory, $ 14 million of investments, and $ 59 million of AROs. These assets are included in our Alaska segment. As discussed in the Clair Field transaction with BP above, we acquired BP’s Kuparuk Assets on December 18, 2018. The transaction was accounted for as an asset acquisition with a net acquisition cost of $ 1,490 million, comprised of the fair value of $ 1,743 million associated with the disposed 16.5 percent of our 24 percent interest in the Clair Field, reduced by the net proceeds of $ 253 million. Accordingly, we recorded approximately $ 1.9 billion to proved property within PP&E, $ 42 million to inventory, $ 15 million to investments, $ 374 million of AROs, and a $ 100 million decrease to net working capital. The Kuparuk Assets are included in our Alaska segment.

Investments, Loans and Long-Term Receivables	12 Months Ended
Investments, Loans and Long-Term Receivables	Dec. 31, 2020
Investments, Loans and Long-Term Receivables and Joint Venture Acquisition Obligation [Abstract]
Investments, Loans and Long-Term Receivables	Note 5—Investments, Loans and Long-Term Receivables Components of investments, loans and long-term receivables at December 31 were: Millions of Dollars 2020 2019 Equity investments $ 7,596 8,234 Loans and advances—related parties 114 219 Long-term receivables 137 243 Long-term investments in debt securities 217 133 Other investments 67 77 $ 8,131 8,906 Equity Investments Affiliated companies in which we had a significant equity investment at December 31, 2020, included: APLNG— 37.5 percent owned joint venture with Origin Energy ( 37.5 percent) and Sinopec ( 25 percent)— to produce CBM from the Bowen and Surat basins in Queensland, Australia, as well as process and export LNG. Qatar Liquefied Gas Company Limited (3) (QG3)—30 percent owned joint venture with affiliates of Qatar Petroleum ( 68.5 percent) and Mitsui & Co., Ltd. ( 1.5 percent)—produces and liquefies natural gas from Qatar’s North Field, as well as exports LNG. Summarized 100 percent earnings information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2020 2019 2018 Revenues $ 7,931 11,310 11,654 Income before income taxes 1,843 3,726 3,660 Net income 1,426 3,085 3,244 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2020 2019 Current assets $ 2,579 3,289 Noncurrent assets 35,257 38,905 Current liabilities 2,110 2,603 Noncurrent liabilities 18,099 22,168 Our share of income taxes incurred directly by an equity method investee is reported in equity in earnings of affiliates, and as such is not included in income taxes on our consolidated financial statements. At December 31, 2020, retained earnings included $ 41 million related to the undistributed earnings of affiliated companies. Dividends received from affiliates were $ 1,076 million, $ 1,378 million and $ 1,226 million in 2020, 2019 and 2018, respectively. APLNG APLNG is a joint venture focused on producing CBM from the Bowen and Surat basins in Queensland, Australia. Natural gas is sold to domestic customers and LNG is processed and exported to Asia Pacific markets. Our investment in APLNG gives us access to CBM resources in Australia and enhances our LNG position. 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 in 2012. The $8.5 billion project finance facility was initially composed of financing agreements executed by APLNG with the Export-Import Bank of the United States for approximately $ 2.9 billion, the Export-Import Bank of China for approximately $ 2.7 billion, and a syndicate of Australian and international commercial banks for approximately $ 2.9 billion. All amounts were drawn from the facility. APLNG made its first principal and interest repayment in March 2017 and is scheduled to make bi-annual payments until March 2029. APLNG made a voluntary repayment of $ 1.4 billion to the Export-Import Bank of China in September 2018. At the same time, APLNG obtained a United States Private Placement (USPP) bond facility of $ 1.4 billion. APLNG made its first interest payment related to this facility in March 2019, and principal payments are scheduled to commence in September 2023, with bi-annual payments due on the facility until September 2030. During the first quarter of 2019, APLNG refinanced $ 3.2 billion of existing project finance debt through two transactions. As a result of the first transaction, APLNG obtained a commercial bank facility of $ 2.6 billion. APLNG made its first principal and interest repayment in September 2019 with bi-annual payments due on the facility until March 2028. Through the second transaction, APLNG obtained a USPP bond facility of $ 0.6 billion. APLNG made its first interest payment in September 2019, and principal payments are scheduled to commence in September 2023, with bi-annual payments due on the facility until September 2030. In conjunction with the $ 3.2 billion debt obtained during the first quarter of 2019 to refinance existing project finance debt, APLNG made voluntary repayments of $ 2.2 billion and $ 1.0 billion to a syndicate of Australian and international commercial banks and the Export-Import Bank of China, respectively. At December 31, 2020, a balance of $ 6.2 billion was outstanding on the facilities. See Note 11—Guarantees, for additional information. During the fourth quarter of 2020, the estimated fair value of our investment in APLNG declined to an amount below carrying value, primarily due to the weakening of the U.S. dollar relative to the Australian dollar. Based on a review of the facts and circumstances surrounding this decline in fair value, we concluded the impairment was not other than temporary under the guidance of FASB ASC Topic 323, “Investments – Equity Method and Joint Ventures.” In reaching this conclusion, we primarily considered: (1) the volatility and uncertainty in commodity and exchange rate markets; (2) the intent and ability of ConocoPhillips to retain our investment in APLNG; and (3) the short length of time and extent to which fair value has been less than carrying value (fair value exceeded carrying value as of September 30, 2020). Fair value has been estimated based on an internal discounted cash flow model using the following estimated assumptions: estimated future production, an outlook of future prices from a combination of exchanges (short-term) coupled with pricing service companies and our internal outlook (long-term), operating and capital expenditures, a market outlook of foreign exchange rates provided by a third party, and a discount rate believed to be consistent with those used by principal market participants. At December 31, 2020, the fair value of our investment in APLNG was estimated to be $ 6,560 million, resulting in a not other than temporary impairment of $ 112 million. We will continue to monitor the relationship between the carrying value and fair value of APLNG. Should we determine in the future there has been a loss in the value of our investment that is other than temporary, we would record an impairment of our equity investment, calculated as the total difference between carrying value and fair value as of the end of the reporting period. At December 31, 2020, the carrying value of our equity method investment in APLNG was $ 6,672 million. The historical cost basis of our 37.5 percent share of net assets on the books of APLNG was $ 6,242 million, resulting in a basis difference of $ 430 million on our books. The basis difference, which is substantially all associated with PP&E and subject to amortization, has been allocated on a relative fair value basis to individual exploration and production license areas owned by APLNG, some of which are not currently in production. Any future additional payments are expected to be allocated in a similar manner. 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 2020, 2019 and 2018 was after-tax expense of $ 41 million, $ 36 million and $ 44 million, respectively, representing the amortization of this basis difference on currently producing licenses. 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 $ 220 million as described below under “Loans and Long- Term Receivables.” At December 31, 2020, the book value of our equity method investment in QG3, excluding the project financing, was $ 742 million. We have terminal and pipeline use agreements with Golden Pass LNG Terminal and affiliated Golden Pass Pipeline near Sabine Pass, Texas, intended to provide us with terminal and pipeline capacity for the receipt, storage and regasification of LNG purchased from QG3. We previously held a 12.4 percent interest in Golden Pass LNG Terminal and Golden Pass Pipeline, but we sold those interests in the second quarter of 2019 while retaining the basic use agreements. Currently, the LNG from QG3 is being sold to markets outside of the U.S. For additional information, see Note 4—Asset Acquisitions and Dispositions. Loans and Long-Term Receivables As part of our normal ongoing business operations and consistent with industry practice, we enter into numerous agreements with other parties to pursue business opportunities. Included in such activity are loans and long-term receivables to certain affiliated and non-affiliated companies. Loans are recorded when cash is transferred or seller financing is provided to the affiliated or non-affiliated company pursuant to a loan agreement. The loan balance will increase as interest is earned on the outstanding loan balance and will decrease as interest and principal payments are received. Interest is earned at the loan agreement’s stated interest rate. Loans and long-term receivables are assessed for impairment when events indicate the loan balance may not be fully recovered. At December 31, 2020, significant loans to affiliated companies include $ 220 million in project financing to QG3. We own a 30 percent interest in QG3, for which we use the equity method of accounting. The other participants in the project are affiliates of Qatar Petroleum and Mitsui. QG3 secured project financing of $ 4.0 billion in December 2005, consisting of $ 1.3 billion of loans from export credit agencies (ECA), $ 1.5 billion from commercial banks, and $ 1.2 billion from ConocoPhillips. The ConocoPhillips loan facilities have substantially the same terms as the ECA and commercial bank facilities. On December 15, 2011, QG3 achieved financial completion and all project loan facilities became nonrecourse to the project participants. Semi-annual repayments began in January 2011 and will extend through July 2022. The long-term portion of these loans is included in the “Loans and advances—related parties” line on our consolidated balance sheet, while the short-term portion is in “Accounts and notes receivable—related parties.”

Investment in Cenovus Energy	12 Months Ended
Investment in Cenovus Energy	Dec. 31, 2020
Investment in Cenovus Energy [Abstract]
Investments in Debt and Marketable Equity Securities (and Certain Trading Assets) Disclosure [Text Block]	Note 6—Investment in Cenovus Energy On May 17, 2017, we completed the sale of our 50 percent nonoperated interest in the FCCL Partnership, as well as the majority of our western Canada gas assets, to Cenovus Energy. Consideration for the transaction included 208 million Cenovus Energy common shares, which, at closing, approximated 16.9 percent of issued and outstanding Cenovus Energy common stock. The fair value and cost basis of our investment in 208 million Cenovus Energy common shares was $ 1.96 billion based on a price of $ 9.41 per share on the NYSE on the closing date. At December 31, 2020, the investment included on our consolidated balance sheet was $ 1.26 billion and is carried at fair value. The fair value of the 208 million Cenovus Energy common shares reflects the closing price of $ 6.04 per share on the NYSE on the last trading day of the quarter, a decrease of $ 855 million from its fair value of $ 2.11 billion at December 31, 2019. The decrease in fair value resulted in a net unrealized loss recorded within the “Other income (loss)” line of our consolidated income statement for the year ended December 31, 2020 relating to the shares held at the reporting date. For the years ended 2019 and 2018, we recorded an unrealized gain of $ 649 million and an unrealized loss of $ 437 million, respectively. See Note 14—Fair Value Measurement and Note 21—Other Financial Information, for additional information. Subject to market conditions, we intend to decrease our investment over time through market transactions, private agreements or otherwise. On January 4, 2021, Cenovus Energy completed its all-stock acquisition of Husky Energy Inc. As a result of this transaction, our investment now approximates 10 percent of the issued and outstanding Cenovus Energy common stock.

Suspended Wells	12 Months Ended
Suspended Wells	Dec. 31, 2020
Suspended Wells [Abstract]
Suspended Wells	Note 7—Suspended Wells and Exploration Expenses The following table reflects the net changes in suspended exploratory well costs during 2020, 2019 and 2018: Millions of Dollars 2020 2019 2018 Beginning balance at January 1 $ 1,020 856 853 Additions pending the determination of proved reserves 164 239 140 Reclassifications to proved properties (42) (11) (37) Sales of suspended wells (313) (54) (93) Charged to dry hole expense (147) (10) (7) Ending balance at December 31 $ 682 1,020 * 856 Includes $ 313 million of assets held for sale in Australia at December 31, 2019. For additional details on suspended wells charged to dry hole expense, see the Exploration Expenses section of this Note. The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2020 2019 2018 Exploratory well costs capitalized for a period of one year or less $ 156 206 145 Exploratory well costs capitalized for a period greater than one year 526 814 711 Ending balance $ 682 1,020 856 Number of projects with exploratory well costs capitalized for a period greater than one year 22 23 24 *Includes $ 313 million of assets held for sale in Australia at December 31, 2019. 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, 2020: Millions of Dollars Suspended Since Total 2017–2019 2014–2016 2004–2013 NPRA—Alaska (1) 240 190 50 - Surmont—Canada (1) 120 4 31 85 Narwhal Trend—Alaska (1) 52 52 - - PL782S—Norway (1) 22 22 - - WL4-00—Malaysia (1) 17 17 - - NC 98—Libya (2) 13 - 9 4 Other of $10 million or less each (1)(2) 62 26 19 17 Total $ 526 311 109 106 (1)Additional appraisal wells planned. (2)Appraisal drilling complete; costs being incurred to assess development. Exploration Expenses The charges discussed below are included in the “Exploration expenses” line on our consolidated income statement. 2020 In our Alaska segment, we recorded a before-tax impairment of $ 828 million for the entire associated carrying value of capitalized undeveloped leasehold costs related to our Alaska North Slope Gas asset. In 2016, we, along with affiliates of Exxon Mobil Corporation, BP p.l.c. and Alaska Gasline Development Corporation (AGDC), a state-owned corporation, completed preliminary FEED technical work for a potential LNG project which would liquefy and export natural gas from Alaska’s North Slope and deliver it to market. In 2016, we, along with the affiliates of ExxonMobil and BP, indicated our intention not to progress into the next phase of the project due to changes in the economic environment; however, AGDC decided to continue on its own, focusing primarily on permitting efforts. Currently, AGDC is in the process of seeking new sponsors for the project. Given current market conditions, we no longer believe the project will advance and, there is no current market for the asset. In our Other International segment, our interests in the Middle Magdalena Basin of Colombia are in force majeure. We have no immediate plans to perform under existing contracts; therefore, in 2020, we recorded a before-tax expense totaling $ 84 million for dry hole costs of a previously suspended well and an impairment of the associated capitalized undeveloped leasehold carrying value. In our Asia Pacific segment, we recorded before-tax expense of $ 50 million related to dry hole costs of a previously suspended well and an impairment of the associated capitalized undeveloped leasehold carrying value associated with the Kamunsu East Field in Malaysia that is no longer in our development plans. 2019 In our Lower 48 segment, we recorded a before-tax impairment of $ 141 million for the associated carrying value of capitalized undeveloped leasehold costs and dry hole expenses of $ 111 million before-tax due to our decision to discontinue exploration activities related to our Central Louisiana Austin Chalk acreage.

Impairments	12 Months Ended
Impairments	Dec. 31, 2020
Impairment Of Long Lived Assets [Abstract]
Impairments	Note 8—Impairments During 2020, 2019 and 2018, we recognized the following before-tax impairment charges: Millions of Dollars 2020 2019 2018 Alaska $ - - 20 Lower 48 804 402 63 Canada 3 2 9 Europe, Middle East and North Africa 6 1 (79) Asia Pacific - - 14 $ 813 405 27 2020 During 2020, we recorded impairments of $ 813 million, primarily related to certain non-core assets in the Lower 48. Due to a significant decrease in the outlook for current and long-term natural gas prices in early 2020, we recorded impairments of $ 523 million, primarily for the Wind River Basin operations area, consisting of developed properties in the Madden Field and the Lost Cabin Gas Plant, in the first quarter of 2020. Additionally, due primarily to changes in development plans solidified in the last quarter of 2020, we recognized additional impairments of $ 287 million in the Lower 48 during the fourth quarter. See Note 14— Fair Value Measurement, for additional information. 2019 In the Lower 48, we recorded impairments of $ 402 million, primarily related to developed properties in our Niobrara asset which were written down to fair value less costs to sell. See Note 4—Asset Acquisitions and Dispositions, for additional information on this disposition. 2018 In Alaska, we recorded impairments of $ 20 million primarily due to cancelled projects. In the Lower 48, we recorded impairments of $ 63 million, primarily related to developed properties in our Barnett asset which were written down to fair value less costs to sell, partly offset by a revision to reflect finalized proceeds on a separate transaction. In our Europe, Middle East and North Africa segment, we recorded a credit to impairment of $ 79 million, primarily due to decreased ARO estimates on fields in the U.K. which ceased production and were impaired in prior years, partly offset by an increased ARO estimate on a field in Norway which ceased production.

Asset Retirement Obligations and Accrued Environmental Costs	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations and Accrued Environmental Costs	Note 9—Asset Retirement Obligations and Accrued Environmental Costs Asset retirement obligations and accrued environmental costs at December 31 were: Millions of Dollars 2020 2019 Asset retirement obligations $ 5,573 6,206 Accrued environmental costs 180 171 Total asset retirement obligations and accrued environmental costs 5,753 6,377 Asset retirement obligations and accrued environmental costs due within one year* (323) (1,025) Long-term asset retirement obligations and accrued environmental costs $ 5,430 5,352 Asset Retirement Obligations We record the fair value of a liability for an ARO when it is incurred (typically when the asset is installed at the production location). When the liability is initially recorded, we capitalize the associated asset retirement cost by increasing the carrying amount of the related PP&E. If, in subsequent periods, our estimate of this liability changes, we will record an adjustment to both the liability and PP&E. Over time, the liability increases for the change in its present value, while the capitalized cost depreciates over the useful life of the related asset. We have numerous AROs we are required to perform under law or contract once an asset is permanently taken out of service. Most of these obligations are not expected to be paid until several years, or decades, in the future and will be funded from general company resources at the time of removal. Our largest individual obligations involve plugging and abandonment of wells and removal and disposal of offshore oil and gas platforms around the world, as well as oil and gas production facilities and pipelines in Alaska. During 2020 and 2019, our overall ARO changed as follows: Millions of Dollars 2020 2019 Balance at January 1 $ 6,206 7,908 Accretion of discount 248 322 New obligations 262 155 Changes in estimates of existing obligations (307) 50 Spending on existing obligations (116) (229) Property dispositions (771) (1,920) Foreign currency translation 51 (80) Balance at December 31 $ 5,573 6,206 Accrued Environmental Costs Total accrued environmental costs at December 31, 2020 and 2019, were $ 180 million and $ 171 million, respectively. We had accrued environmental costs of $ 116 million and $ 112 million at December 31, 2020 and 2019, respectively, related to remediation activities in the U.S. and Canada. We had also accrued in Corporate and Other $ 48 million and $ 47 million of environmental costs associated with sites no longer in operation at December 31, 2020 and 2019, respectively. In addition, $ 16 million and $ 12 million were included at both December 31, 2020 and 2019, respectively, where the company 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 extending 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 $ 106 million at December 31, 2020. The expected future undiscounted payments related to the portion of the accrued environmental costs that have been discounted are: $ 23 million in 2021, $ 17 million in 2022, $ 18 million in 2023, $ 3 million in 2024, $ 2 million in 2025, and $ 103 million for all future years after 2025.	*Classified as a current liability on the balance sheet under “Other accruals.” For 2019, $ 741 million relates to assets which were held for sale as of December 31, 2019, and subsequently sold in 2020. For additional information see Note 4—Asset Acquisitions and Dispositions.

Debt	12 Months Ended
Debt	Dec. 31, 2020
Debt [Abstract]
Debt	Note 10—Debt Long-term debt at December 31 was: Millions of Dollars 2020 2019 9.125 % Debentures due 2021 $ 123 123 2.4 % Notes due 2022 329 329 7.65 % Debentures due 2023 78 78 3.35 % Notes due 2024 426 426 8.2 % Debentures due 2025 134 134 3.35 % Notes due 2025 199 199 6.875 % Debentures due 2026 67 67 4.95 % Notes due 2026 1,250 1,250 7.8 % Debentures due 2027 203 203 7.375 % Debentures due 2029 92 92 7 % Debentures due 2029 200 200 6.95 % Notes due 2029 1,549 1,549 8.125 % Notes due 2030 390 390 7.2 % Notes due 2031 575 575 7.25 % Notes due 2031 500 500 7.4 % Notes due 2031 500 500 5.9 % Notes due 2032 505 505 4.15 % Notes due 2034 246 246 5.95 % Notes due 2036 500 500 5.951 % Notes due 2037 645 645 5.9 % Notes due 2038 600 600 6.5 % Notes due 2039 2,750 2,750 4.3 % Notes due 2044 750 750 5.95 % Notes due 2046 500 500 7.9 % Debentures due 2047 60 60 Floating rate notes due 2022 at 1.12 % – 2.81 % during 2020 and 2.81 % – 3.58 % during 2019 500 500 Marine Terminal Revenue Refunding Bonds due 2031 at 0.1 % – 7.5 % during 2020 and 1.08 % – 2.45 % during 2019 265 265 Industrial Development Bonds due 2035 at 0.11 % – 7.5 % during 2020 and 1.08 % – 2.45 % during 2019 18 18 Commercial Paper at 0.08 % – 0.23 % during 2020 300 Other 38 17 Debt at face value 14,292 13,971 Finance leases 891 720 Net unamortized premiums, discounts and debt issuance costs 186 204 Total debt 15,369 14,895 Short-term debt (619) (105) Long-term debt $ 14,750 14,790 Maturities of long-term borrowings, inclusive of net unamortized premiums and discounts, in 2021 through 2025 are: $ 619 million, $ 1,001 million, $ 259 million, $ 579 million and $ 465 million, respectively. We have a revolving credit facility totaling $ 6.0 billion with an expiration date of May 2023. Our revolving credit facility may be used for direct bank borrowings, the issuance of letters of credit totaling up to $ 500 million, or as support for our commercial paper program. 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 ratios or credit ratings. The facility agreement contains a cross- default provision relating to the failure to pay principal or interest on other debt obligations of $ 200 million or more by ConocoPhillips, or any of its consolidated subsidiaries. The amount of the facility is not subject to redetermination prior to its expiration date. 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 U.S. 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. The revolving credit facility supports our ability to issue up to $ 6.0 billion of commercial paper, which is primarily a funding source for short-term working capital needs. Commercial paper maturities are generally limited to 90 days . We issued $ 300 million of commercial paper in the third quarter of 2020, which is included in the short-term debt on our consolidated balance sheet. With $ 300 million of commercial paper outstanding and no direct borrowings or letters of credit, we had access to $ 5.7 billion in available borrowing capacity under our revolving credit facility at December 31, 2020. We had no direct borrowings, letters of credit, nor outstanding commercial paper as of December 31, 2019. At both December 31, 2020 and 2019, we had $ 283 million of certain variable rate demand bonds (VRDBs) outstanding with maturities ranging through 2035. The VRDBs are redeemable at the option of the bondholders on any business day. If they are ever redeemed, we have the ability and intent to refinance on a long-term basis, therefore, the VRDBs are included in the “Long-term debt” line on our consolidated balance sheet. For information on Finance Leases, see Note 16—Non-Mineral Leases. On January 15, 2021, we completed the acquisition of Concho in an all-stock transaction. In the acquisition, we assumed Concho’s publicly traded debt, which was recorded at fair value of $ 4.7 billion on the acquisition date. On December 7, 2020, we launched a debt exchange offer which settled on February 8, 2021. Of the approximately $ 3.9 billion in aggregate principal amount of Concho’s notes subject to the exchange offer, 98 percent, or approximately $ 3.8 billion, was tendered and exchanged for new debt issued by ConocoPhillips. The new debt received in the exchange is fully and unconditionally guaranteed by ConocoPhillips Company. In conjunction with the exchange offer, Concho successfully solicited consents to amend each of the indentures governing the Concho notes to eliminate certain covenants, restrictive provisions, events of default and the requirements for certain Concho subsidiaries to make future guarantees. For additional information on the acquisition see Note 25—Acquisition of Concho Resources Inc.

Guarantees	12 Months Ended
Guarantees	Dec. 31, 2020
Guarantees [Abstract]
Guarantees	Note 11—Guarantees At December 31, 2020, 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 performing 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, 2020, 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 2020 exchange rates: ● During the third quarter of 2016, we issued a guarantee to facilitate the withdrawal of our pro-rata portion of the funds in a project finance reserve account. We estimate the remaining term of this guarantee to be 10 years . Our maximum exposure under this guarantee is approximately $ 170 million and may become payable if an enforcement action is commenced by the project finance lenders against APLNG. At December 31, 2020, the carrying value of this guarantee is approximately $ 14 million. ● In conjunction with our original purchase of an ownership interest in APLNG from Origin Energy in October 2008, we agreed to reimburse Origin Energy for our share of the existing contingent liability arising under guarantees of an existing obligation of APLNG to deliver natural gas under several sales agreements with remaining terms of 1 to 21 years . Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $ 770 million ($ 1.4 billion in the event of intentional or reckless breach) and would become payable if APLNG fails to meet its obligations under these agreements and the obligations cannot otherwise be mitigated. Future payments are considered 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 16 to 25 years or the life of the venture . Our maximum potential amount of future payments related to these guarantees is approximately $ 130 million and would become payable if APLNG does not perform. At December 31, 2020, the carrying value of these guarantees was approximately $ 7 million. Other Guarantees We have other guarantees with maximum future potential payment amounts totaling approximately $ 730 million, which consist primarily of guarantees of the residual value of leased office buildings, guarantees of the residual value of corporate aircraft, and a guarantee for our portion of a joint venture’s project finance reserve accounts. These guarantees have remaining terms of one to six years and would become payable if certain asset values are lower than guaranteed amounts at the end of the lease or contract term, business conditions decline at guaranteed entities, or as a result of nonperformance of contractual terms by guaranteed parties. At December 31, 2020, the carrying value of these guarantees was approximately $ 11 million. Indemnifications Over the years, we have entered into agreements to sell ownership interests in certain legal entities, joint ventures and assets that gave rise to qualifying indemnifications. These agreements include indemnifications for taxes and environmental liabilities. Most of these indemnifications are related to tax issues and the majority of these expire in 2021. Those related to environmental issues have terms that are generally indefinite and the maximum amounts of future payments are generally unlimited. The carrying amount recorded for these indemnifications at December 31, 2020, was approximately $ 50 million. We amortize the indemnification liability over the relevant time period the indemnity is in effect, 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 information the liability is essentially relieved or amortize the liability over an appropriate time period as the fair value of our indemnification exposure declines. Although it is reasonably possible future payments may exceed amounts recorded, due to the nature of the indemnifications, it is not possible to make a reasonable estimate of the maximum potential amount of future payments. For additional information about environmental liabilities, see Note 12—Contingencies and Commitments.

Contingencies and Commitments	12 Months Ended
Contingencies and Commitments	Dec. 31, 2020
Contingencies and Commitments [Abstract]
Contingencies and Commitments	Note 12—Contingencies and Commitments A number of lawsuits involving a variety of claims arising in the ordinary course of business have been filed against ConocoPhillips. We also may be required to remove or mitigate the effects on the environment of the placement, storage, disposal or release of certain chemical, mineral and petroleum substances at various active and inactive sites. We regularly assess the need for accounting recognition or disclosure of these contingencies. In the case of all known 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 than any other amount, then the low end of the range is accrued. We do not reduce these liabilities for potential insurance or third-party recoveries. We accrue receivables for insurance or other third-party recoveries when applicable. With respect to income tax-related contingencies, we use a cumulative probability-weighted loss accrual in cases where sustaining a tax position is less than certain. See Note 18—Income Taxes, for additional information about income tax- related contingencies. Based on currently available information, we believe it is remote that future costs related to known contingent liability exposures will exceed current accruals by an amount that would have a material adverse impact on our consolidated financial statements. 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 environmental 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 the 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 management’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 business 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. EPA or other organizations. 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 related 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 accordingly. As a result of various acquisitions in the past, we assumed certain environmental obligations. Some of these environmental obligations are mitigated by indemnifications made by others for our benefit, and some of the indemnifications are subject to dollar limits and time limits. We are currently participating in environmental assessments and cleanups at numerous federal Superfund and comparable state and international sites. After an assessment of environmental exposures for cleanup and other costs, we make accruals on an undiscounted basis (except those acquired in a purchase business combination, which we record on a discounted basis) for planned investigation and remediation activities for sites where it is probable future costs will be incurred and these costs can be reasonably estimated. We have not reduced these accruals for possible insurance recoveries. In the future, we may be involved in additional environmental assessments, cleanups and proceedings. See Note 9—Asset Retirement Obligations and Accrued Environmental Costs, for a summary of our accrued environmental liabilities. Litigation and Other Contingencies We are subject to various lawsuits and claims including but not limited to matters involving oil and gas royalty and severance tax payments, gas measurement and valuation methods, contract disputes, environmental damages, climate change, personal injury, and property damage. Our primary exposures for such matters relate to alleged royalty and tax underpayments 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, experience 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 exposures 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. We have contingent liabilities 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, 2020, we had performance obligations secured by letters of credit of $ 249 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, ConocoPhillips was unable to reach agreement with respect to the 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, ConocoPhillips initiated international arbitration on November 2, 2007, with the ICSID. On September 3, 2013, an ICSID arbitration tribunal held that Venezuela unlawfully expropriated ConocoPhillips’ significant oil investments in June 2007. On January 17, 2017, the Tribunal reconfirmed the decision that the expropriation was unlawful. In March 2019, the Tribunal unanimously ordered the government of Venezuela to pay ConocoPhillips approximately $ 8.7 billion in compensation for the government’s unlawful expropriation of the company’s investments in Venezuela in 2007. ConocoPhillips has filed a request for recognition of the award in several jurisdictions. On August 29, 2019, the ICSID Tribunal issued a decision rectifying the award and reducing it by approximately $ 227 million. The award now stands at $ 8.5 billion plus interest. The government of Venezuela sought annulment of the award before ICSID, and annulment proceedings are underway. In 2014, ConocoPhillips filed a separate and independent arbitration under the rules of the ICC against PDVSA under the contracts that had established the Petrozuata and Hamaca projects. The ICC Tribunal issued an award in April 2018, finding that PDVSA owed ConocoPhillips approximately $ 2 billion under their agreements in connection with the expropriation of the projects and other pre-expropriation fiscal measures. In August 2018, ConocoPhillips entered into a settlement with PDVSA to recover the full amount of this ICC award, plus interest through the payment period, including initial payments totaling approximately $500 million within a period of 90 days from the time of signing of the settlement agreement. The balance of the settlement is to be paid quarterly over a period of four and a half years. To date, ConocoPhillips has received approximately $ 754 million. Per the settlement, PDVSA recognized the ICC award as a judgment in various jurisdictions, and ConocoPhillips agreed to suspend its legal enforcement actions. ConocoPhillips sent notices of default to PDVSA on October 14 and November 12, 2019, and to date PDVSA has failed to cure its breach. As a result, ConocoPhillips has resumed legal enforcement actions. ConocoPhillips has ensured that the settlement and any actions taken in enforcement thereof meet all appropriate U.S. regulatory requirements, including those related to any applicable sanctions imposed by the U.S. against Venezuela. In 2016, ConocoPhillips filed a separate and independent arbitration under the rules of the ICC against PDVSA under the contracts that had established the Corocoro Project. On August 2, 2019, the ICC Tribunal awarded ConocoPhillips approximately $ 33 million plus interest under the Corocoro contracts. ConocoPhillips is seeking recognition and enforcement of the award in various jurisdictions. ConocoPhillips has ensured that all the actions related to the award meet all appropriate U.S. regulatory requirements, including those related to any applicable sanctions imposed by the U.S. against Venezuela. The Office of Natural Resources Revenue (ONRR) has conducted audits of ConocoPhillips’ payment of royalties on federal lands and has issued multiple orders to pay additional royalties to the federal government. ConocoPhillips has appealed these orders and strongly objects to the ONRR claims. The appeals are pending with the Interior Board of Land Appeals (IBLA), except for one order that is the subject of a lawsuit ConocoPhillips filed in 2016 in New Mexico federal court after its appeal was denied by the IBLA. Beginning in 2017, governmental and other entities in several states in the U.S. have filed lawsuits against oil and gas companies, including ConocoPhillips, seeking compensatory damages and equitable relief to abate alleged climate change impacts. Additional lawsuits with similar allegations are expected to be filed. The amounts claimed by plaintiffs are unspecified and the legal and factual issues involved in these cases are unprecedented. ConocoPhillips believes these lawsuits are factually and legally meritless and are an inappropriate vehicle to address the challenges associated with climate change and will vigorously defend against such lawsuits. Several Louisiana parishes and the State of Louisiana have filed 43 lawsuits under Louisiana’s State and Local Coastal Resources Management Act (SLCRMA) against oil and gas companies, including ConocoPhillips, seeking compensatory damages for contamination and erosion of the Louisiana coastline allegedly caused by historical oil and gas operations. ConocoPhillips entities are defendants in 22 of the lawsuits and will vigorously defend against them. Because Plaintiffs’ SLCRMA theories are unprecedented, there is uncertainty about these claims (both as to scope and damages) and any potential financial impact on the company. In 2016, ConocoPhillips, through its subsidiary, The Louisiana Land and Exploration Company LLC, submitted claims as the largest private wetlands owner in Louisiana within the settlement claims administration process related to the oil spill in the Gulf of Mexico in April 2010. In July 2020, the claims administrator issued an award to the company which, after fees and expenses, totaled approximately $ 90 million, and was received in the third quarter of 2020. In October 2020, the Bureau of Safety and Environmental Enforcement (BSEE) ordered the prior owners of Outer Continental Shelf (OCS) Lease P-0166, including ConocoPhillips, to decommission the lease facilities, including two offshore platforms located near Carpinteria, California. This order was sent after the current owner of OCS Lease P-0166 relinquished the lease and abandoned the lease platforms and facilities. Phillips Petroleum Company, a legacy company of ConocoPhillips, held a 25 percent interest in this lease and operated these facilities, but sold its interest approximately 30 years ago. ConocoPhillips has not had any connection to the operation or production on this lease since that time. ConocoPhillips is challenging this order. Long-Term Throughput Agreements and Take -or-Pay Agreements We have certain throughput agreements and take-or-pay agreements in support of financing arrangements. The agreements typically provide for natural gas or crude oil transportation to be used in the ordinary course of the company’s business. The aggregate amounts of estimated payments under these various agreements are: 2021—$ 7 million; 2022—$ 7 million; 2023—$ 7 million; 2024—$ 7 million; 2025—$ 7 million; and 2026 and after—$ 51 million. Total payments under the agreements were $ 25 million in 2020, $ 25 million in 2019 and $ 39 million in 2018.

Derivative and Financial Instruments	12 Months Ended
Derivative and Financial Instruments	Dec. 31, 2020
Derivative and Financial Instruments [Abstract]
Derivative and Financial Instruments	Note 13—Derivative and Financial Instruments We use futures, forwards, swaps and options in various markets to meet our customer needs, capture market opportunities, and manage foreign exchange currency risk. Commodity Derivative Instruments Our commodity business primarily consists of natural gas, crude oil, bitumen, LNG and NGLs. Commodity derivative instruments 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 designated with the NPNS exception are recognized upon settlement. We generally apply this exception to eligible crude contracts. We do not apply 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 2020 2019 Assets Prepaid expenses and other current assets $ 229 288 Other assets 26 34 Liabilities Other accruals 202 283 Other liabilities and deferred credits 18 28 The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars 2020 2019 2018 Sales and other operating revenues $ 19 141 45 Other income (loss) 4 4 7 Purchased commodities 11 (118) (41) The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts: Open Position Long/(Short) 2020 2019 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (20) (5) Basis (10) (23) Foreign Currency Exchange Derivatives We have foreign currency exchange rate risk resulting from international operations. Our foreign currency exchange derivative activity primarily relates to managing our cash-related foreign currency exchange rate exposures, such as firm commitments for capital programs or local currency tax payments, dividends and cash returns from net investments in foreign affiliates, and investments in equity securities. 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 2020 2019 Assets Prepaid expenses and other current assets $ 2 1 Liabilities Other accruals 16 20 Other liabilities and deferred credits - 8 The (gains) losses from foreign currency exchange derivatives incurred and the line item where they appear on our consolidated income statement were: Millions of Dollars 2020 2019 2018 Foreign currency transaction (gains) losses $ (40) 16 1 We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency 2020 2019 Foreign Currency Exchange Derivatives Buy British pound, sell euro GBP - 4 Sell British pound, buy euro GBP 5 - Sell Canadian dollar, buy U.S. dollar CAD 370 1,337 At December 31, 2020, we had outstanding foreign currency exchange forward contracts to sell $0.45 billion CAD at $0.748 CAD against the U.S. dollar. At December 31, 2019, we had outstanding foreign currency exchange forward contracts to sell $1.35 billion CAD at $0.748 CAD against the U.S. dollar . Financial Instruments We invest in financial instruments with maturities based on our cash forecasts for the various accounts and currency pools we manage. The types of financial instruments in which we currently invest include: ● Time deposits: Interest bearing deposits placed with financial institutions for a predetermined amount of time. ● Demand deposits: Interest bearing deposits placed with financial institutions. Deposited funds can be withdrawn without notice. ● Commercial paper: Unsecured promissory notes issued by a corporation, commercial bank or government agency purchased at a discount to mature at par. ● U.S. government or government agency obligations: Securities issued by the U.S. government or U.S. government agencies. ● Foreign government obligations: Securities issued by foreign governments. ● Corporate bonds: Unsecured debt securities issued by corporations. ● Asset-backed securities: Collateralized debt securities. The following investments are carried on our consolidated balance sheet at cost, plus accrued interest and the table reflects remaining maturities at December 31, 2020 and 2019: Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments Investments and Long- Term Receivables 2020 2019 2020 2019 2020 2019 Cash $ 597 759 Demand Deposits 1,133 1,483 Time Deposits 1 to 90 days 1,225 2,030 2,859 1,395 91 to 180 days 448 465 Within one year 13 - One year through five years 1 - Commercial Paper 1 to 90 days - 413 - 1,069 U.S. Government Obligations 1 to 90 days 23 394 - - $ 2,978 5,079 3,320 2,929 1 - The following investments in debt securities classified as available for sale are carried on our consolidated balance sheet at fair value as of December 31, 2020 and 2019: Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments Investments and Long- Term Receivables 2020 2019 2020 2019 2020 2019 Major Security Type Corporate Bonds $ - 1 130 59 143 99 Commercial Paper 13 8 155 30 U.S. Government Obligations - - 4 10 13 15 U.S. Government Agency Obligations 17 - Foreign Government Obligations 2 - Asset-backed Securities - - 41 19 $ 13 9 289 99 216 133 Cash and Cash Equivalents and Short-Term Investments have remaining maturities within one year. Investments and Long-Term Receivables have remaining maturities greater than one year through five years. The following table summarizes the amortized cost basis and fair value of investments in debt securities classified as available for sale: Millions of Dollars Amortized Cost Basis Fair Value 2020 2019 2020 2019 Major Security Type Corporate bonds $ 271 159 273 159 Commercial paper 168 38 168 38 U.S. government obligations 17 25 17 25 U.S. government agency obligations 17 - 17 - Foreign government obligations 2 - 2 - Asset-backed securities 41 19 41 19 $ 516 241 518 241 As of December 31, 2020 and December 31, 2019, total unrealized losses for debt securities classified as available for sale with net losses were negligible. Additionally, as of December 31, 2020 and December 31, 2019, investments in these debt securities in an unrealized loss position for which an allowance for credit losses has not been recorded were negligible. For the year ended December 31, 2020, proceeds from sales and redemptions of investments in debt securities classified as available for sale were $ 422 million. Gross realized gains and losses included in earnings from those sales and redemptions were negligible. The cost of securities sold and redeemed is determined using the specific identification method. Credit Risk Financial instruments potentially exposed to concentrations of credit risk consist primarily of cash equivalents, short-term investments, long-term investments in debt securities, OTC derivative contracts and trade receivables. Our cash equivalents and short-term investments are placed in high-quality commercial paper, government money market funds, government debt securities, time deposits with major international banks and financial institutions, and high-quality corporate bonds. Our long-term investments in debt securities are placed in high-quality corporate bonds, U.S. government and government agency obligations, foreign government obligations, and asset-backed securities. The credit risk from our OTC derivative contracts, such as forwards, swaps and options, derives from the counterparty to the transaction. Individual counterparty exposure is managed within predetermined credit limits and includes the use of cash-call margins when appropriate, thereby reducing the risk of significant nonperformance. We also use futures, swaps and option contracts that have a negligible credit risk because these trades are cleared primarily with an exchange clearinghouse and subject to mandatory margin requirements until settled; however, we are exposed to the credit risk of those exchange brokers for receivables arising from daily margin cash calls, as well as for cash deposited to meet initial margin requirements. Our trade receivables result primarily from our petroleum operations and reflect a broad national and international customer base, which limits our exposure to concentrations of credit risk. The majority of these receivables have payment terms of 30 days or less , and we continually monitor this exposure and the creditworthiness of the counterparties. At our option, we may require collateral to limit the exposure to loss including, letters of credit, prepayments and surety bonds, as well as master netting arrangements to mitigate credit risk with counterparties that both buy from and sell to us, as these agreements permit the amounts owed by us or owed to others to be offset against amounts due to us. Certain of our derivative instruments contain provisions that require us to post collateral if the derivative exposure exceeds a threshold amount. We have contracts with fixed threshold amounts and other contracts with variable threshold amounts that are contingent on our credit rating. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically revert to zero if we fall below investment grade. Cash is the primary collateral in all contracts; however, many also permit us to post letters of credit as collateral, such as transactions administered through the New York Mercantile Exchange. The aggregate fair value of all derivative instruments with such credit risk-related contingent features that were in a liability position on December 31, 2020 and December 31, 2019, was $ 25 million and $ 79 million, respectively. For these instruments, no collateral was posted as of December 31, 2020 or December 31, 2019. If our credit rating had been downgraded below investment grade on December 31, 2020, we would have been required to post $ 23 million of additional collateral, either with cash or letters of credit.

Fair Value Measurement	12 Months Ended
Fair Value Measurement	Dec. 31, 2020
Fair Value Measurement [Abstract]
Fair Value Measurement	Note 14—Fair Value Measurement We carry a portion of our assets and liabilities at fair value that are measured at the 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 observable. ● Level 3: Unobservable inputs that are significant to the fair value of assets or liabilities. The classification of an asset or liability is based on the lowest level of input significant to its fair value. Those that are initially classified as Level 3 are subsequently reported as Level 2 when the fair value derived from unobservable inputs is inconsequential to the overall fair value, or if corroborated market data becomes available. Assets and liabilities initially reported as Level 2 are subsequently reported as Level 3 if corroborated market data is no longer available. There were no material transfers into or out of Level 3 during 2020 or 2019. Recurring Fair Value Measurement Financial assets and liabilities reported at fair value on a recurring basis primarily include our investment in Cenovus Energy common shares, our investments in debt securities classified as available for sale, and commodity derivatives. ● Level 1 derivative assets and liabilities primarily represent exchange-traded futures and options that are valued using unadjusted prices available from the underlying exchange. Level 1 also includes our investment in common shares of Cenovus Energy, which is valued using quotes for shares on the NYSE, and our investments in U.S. government obligations classified as available for sale debt securities, which are valued using exchange prices. ● Level 2 derivative assets and liabilities primarily represent OTC swaps, options and forward purchase and sale contracts that are valued using adjusted exchange prices, prices provided by brokers or pricing service companies that are all corroborated by market data. Level 2 also includes our investments in debt securities classified as available for sale including investments in corporate bonds, commercial paper, asset-backed securities, U.S. government agency obligations and foreign government obligations that are valued using pricing provided by brokers or pricing service companies that are corroborated with 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 uses industry standard methodologies that may consider the historical relationships among various commodities, modeled market prices, time value, volatility factors and other relevant economic measures. The use of these inputs results in management’s best estimate of fair value. Level 3 activity was not material for all periods presented. The following table summarizes the fair value hierarchy for gross financial assets and liabilities (i.e., unadjusted where the right of setoff exists for commodity derivatives accounted for at fair value on a recurring basis): Millions of Dollars December 31, 2020 December 31, 2019 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ 1,256 - - 1,256 2,111 - - 2,111 Investments in debt securities 17 501 - 518 25 216 - 241 Commodity derivatives 142 101 12 255 172 114 36 322 Total assets $ 1,415 602 12 2,029 2,308 330 36 2,674 Liabilities Commodity derivatives $ 120 91 9 220 174 115 22 311 Total liabilities $ 120 91 9 220 174 115 22 311 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 setoff exists. Millions of Dollars Amounts Subject to Right of Setoff Gross Amounts Not Gross Net Amounts Subject to Gross Amounts Amounts Cash Net Recognized Right of Setoff Amounts Offset Presented Collateral Amounts December 31, 2020 Assets $ 255 2 253 157 96 10 86 Liabilities 220 1 219 157 62 4 58 December 31, 2019 Assets $ 322 3 319 193 126 4 122 Liabilities 311 4 307 193 114 12 102 At December 31, 2020 and December 31, 2019, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff. Non-Recurring Fair Value Measurement The following table summarizes the fair value hierarchy by major category and date of remeasurement for assets accounted for at fair value on a non-recurring basis: Millions of Dollars Fair Value Measurements Using Fair Value Level 1 Inputs Level 2 Inputs Level 3 Inputs Before-Tax Loss Year ended December 31, 2020 Net PP&E (held for use) March 31, 2020 $ 65 - - 65 522 December 31, 2020 268 - - 268 287 Year ended December 31, 2019 Net PP&E (held for sale) November 30, 2019 $ 194 194 - - 351 December 31, 2019 166 166 - - 28 Equity Method Investments March 31, 2019 171 171 - - 60 May 31, 2019 30 - 30 - 95 Net PP&E (held for use) During 2020, the estimated fair value of certain non-core assets included in our Lower 48 segment declined to amounts below the carrying values. The carrying values were written down to fair value. The fair values were estimated based on internal discounted cash flow models using the following estimated assumptions: estimated future production, an outlook of future prices from a combination of exchanges (short-term) coupled with pricing service companies and our internal outlook (long-term), future operating costs and capital expenditures, and a discount rate believed to be consistent with those used by principal market participants. The range and arithmetic average of significant unobservable inputs used in the Level 3 fair value measurements for significant assets were as follows: Fair Value (Millions of Dollars) Valuation Technique Unobservable Inputs Range (Arithmetic Average) March 31, 2020 Wind River Basin $ 65 Discounted cash flow Natural gas production (MMCFD) 8.4 - 55.2 ( 22.9 ) Natural gas price outlook* ($/MMBTU) $ 2.67 - $ 9.17 ($ 5.68 ) Discount rate** 7.9 % - 9.1 % ( 8.3 %) Henry Hub natural gas price outlook based on a combination of external pricing service companies' outlooks for years 2022-2034; future prices escalated at 2.2 % annually after year 2034. Determined as the weighted average cost of capital of a group of peer companies, adjusted for risks where appropriate. Fair Value (Millions of Dollars) Valuation Technique Unobservable Inputs Range (Arithmetic Average) December 31, 2020 Central Basin Platform $ 244 Discounted cash flow Commodity production (MBOED) 0.5 - 12.7 ( 3.4 ) Commodity price outlook ($/BOE) $ 37.35 - $ 115.29 ($ 73.80 ) Discount rate** 6.8 % - 7.7 % ( 7.4 %) Commodity price outlook based on a combination of external pricing service companies' and our internal outlook for years 2023-2050; future prices escalated at 2.0% annually after year 2050. *Determined as the weighted average cost of capital of a group of peer companies, adjusted for risks where appropriate. Net PP&E (held for sale) Net PP&E held for sale was written down to fair value, less costs to sell. The fair value of the assets were determined by their negotiated selling prices (Level 1). For additional information see Note 4—Asset Acquisitions and Dispositions. Equity Method Investments During 2019, certain equity method investments were determined to have fair values below their carrying amounts, and the impairments were considered to be other than temporary under the guidance of FASB ASC Topic 323. Investments using Level 1 inputs were written down to fair value, less costs to sell, determined by negotiated selling prices. For additional information, see Note 4—Asset Acquisitions and Dispositions and Note 5—Investments, Loans and Long-Term Receivables. An investment using Level 2 inputs was determined to have a fair value below its carrying value, and was written down to fair value. Reported Fair Values of Financial Instruments We used the following methods and assumptions to estimate the fair value of financial instruments: ● Cash and cash equivalents and short-term investments: The carrying amount reported on the balance sheet approximates fair value. For those investments classified as available for sale debt securities, the carrying amount reported on the balance sheet is fair value. ● Accounts and notes receivable (including long-term and related parties): The carrying amount reported on the balance sheet approximates fair value. The valuation technique and methods used to estimate the fair value of the current portion of fixed-rate related party loans is consistent with Loans and advances—related parties. ● Investment in Cenovus Energy: See Note 6—Investment in Cenovus Energy for a discussion of the carrying value and fair value of our investment in Cenovus Energy common shares. ● Investments in debt securities classified as available for sale: The fair value of investments in debt securities categorized as Level 1 in the fair value hierarchy is measured using exchange prices. The fair value of investments in debt securities categorized as Level 2 in the fair value hierarchy is measured using pricing provided by brokers or pricing service companies that are corroborated with market data. See Note 13—Derivatives and Financial Instruments, for additional information. ● Loans and advances—related parties: The carrying amount of floating-rate loans approximates fair value. The fair value of fixed-rate loan activity is measured using market observable data and is categorized as Level 2 in the fair value hierarchy. See Note 5—Investments, Loans and Long-Term Receivables, for additional information. ● Accounts payable (including related parties) and floating-rate debt: The carrying amount of accounts payable and floating-rate debt reported on the balance sheet approximates fair value. ● Fixed-rate debt: The estimated fair value of fixed-rate debt is 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. ● Commercial paper: The carrying amount of our commercial paper instruments approximates fair value and is reported on the balance sheet as short-term debt. See Note 10—Debt, for additional information 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 2020 2019 2020 2019 Financial assets Investment in Cenovus Energy $ 1,256 2,111 1,256 2,111 Commodity derivatives 88 125 88 125 Investments in debt securities 518 241 518 241 Loans and advances—related parties 220 339 220 339 Financial liabilities Total debt, excluding finance leases 14,478 14,175 19,106 18,108 Commodity derivatives 59 106 59 106 Commodity Derivatives At December 31, 2020, commodity derivative assets and liabilities are presented net with $ 10 million in obligations to return cash collateral and $ 4 million of rights to reclaim cash collateral, respectively. At December 31, 2019, commodity derivative assets and liabilities are presented net with $ 4 million in obligations to return cash collateral and $ 12 million of rights to reclaim cash collateral, respectively.

The entire disclosure for the fair value of financial instruments (as defined), including financial assets and financial liabilities (collectively, as defined), and the measurements of those instruments as well as disclosures related to the fair value of non-financial assets and liabilities. Such disclosures about the financial instruments, assets, and liabilities would include: (1) the fair value of the required items together with their carrying amounts (as appropriate); (2) for items for which it is not practicable to estimate fair value, disclosure would include: (a) information pertinent to estimating fair value (including, carrying amount, effective interest rate, and maturity, and (b) the reasons why it is not practicable to estimate fair value; (3) significant concentrations of credit risk including: (a) information about the activity, region, or economic characteristics identifying a concentration, (b) the maximum amount of loss the entity is exposed to based on the gross fair value of the related item, (c) policy for requiring collateral or other security and information as to accessing such collateral or security, and (d) the nature and brief description of such collateral or security; (4) quantitative information about market risks and how such risks are managed; (5) for items measured on both a recurring and nonrecurring basis information regarding the inputs used to develop the fair value measurement; and (6) for items presented in the financial statement for which fair value measurement is elected: (a) information necessary to understand the reasons for the election, (b) discussion of the effect of fair value changes on earnings, (c) a description of [similar groups] items for which the election is made and the relation thereof to the balance sheet, the aggregate carrying value of items included in the balance sheet that are not eligible for the election; (7) all other required (as defined) and desired information.

Equity	12 Months Ended
Equity	Dec. 31, 2020
Equity [Abstract]
Equity	Note 15—Equity Common Stock The changes in our shares of common stock, as categorized in the equity section of the balance sheet, were: Shares 2020 2019 2018 Issued Beginning of year 1,795,652,203 1,791,637,434 1,785,419,175 Distributed under benefit plans 3,192,064 4,014,769 6,218,259 End of year 1,798,844,267 1,795,652,203 1,791,637,434 Held in Treasury Beginning of year 710,783,814 653,288,213 608,312,034 Repurchase of common stock 20,018,275 57,495,601 44,976,179 End of year 730,802,089 710,783,814 653,288,213 Preferred Stock We have authorized 500 million shares of preferred stock, par value $ 0.01 per share, none of which was issued or outstanding at December 31, 2020 or 2019. Noncontrolling Interests In the second quarter of 2020, we completed the divestiture of our subsidiaries that held our Australia-West assets and operations. These assets included the Darwin LNG and Bayu-Darwin Pipeline operating joint ventures in which there was a noncontrolling interest. As a result, as of December 31, 2020, we had no noncontrolling interests. At December 31, 2019, we had $ 69 million of equity outstanding in the same joint ventures. Repurchase of Common Stock In late 2016, we initiated our current share repurchase program, which has a current total program authorization of $ 25 billion of our common stock. Cost of share repurchases were $ 892 million, $ 3,500 million, $ 2,999 million in 2020, 2019 and 2018, respectively. Share repurchases were suspended in the second and third quarters of 2020 in response to the economic downturn. In the fourth quarter of 2020, we resumed share repurchases, repurchasing $ 0.2 billion of shares in October, until suspending further repurchases upon entry into a definitive agreement to acquire Concho. In February 2021, we resumed share repurchases following our Concho acquisition. Share repurchases since inception of our current program totaled 189 million shares at a cost of $ 10,517 million, as of December 31, 2020.

Non Mineral Leases	12 Months Ended
Non Mineral Leases	Dec. 31, 2020
Leases [Abstract]
Non-Mineral Leases	Note 16—Non-Mineral Leases The company primarily leases office buildings and drilling equipment, as well as ocean transport vessels, tugboats, corporate aircraft, and other facilities and equipment. Certain leases include escalation clauses for adjusting rental payments to reflect changes in price indices and other leases include payment provisions that vary based on the nature of usage of the leased asset. Additionally, the company has executed certain leases that provide it with the option to extend or renew the term of the lease, terminate the lease prior to the end of the lease term, or purchase the leased asset as of the end of the lease term. In other cases, the company has executed lease agreements that require it to guarantee the residual value of certain leased office buildings. For additional information about guarantees, see Note 11—Guarantees. There are no significant restrictions imposed on us by the lease agreements with regard to dividends, asset dispositions or borrowing ability. Certain arrangements may contain both lease and non-lease components and we determine if an arrangement is or contains a lease at contract inception. We adopted the provisions of FASB ASU No. 2016-02, “Leases” (ASC Topic 842) and its amendments, beginning January 1, 2019. This ASU superseded the requirements in FASB ASC Topic 840 “Leases” (ASC Topic 840). Only the lease components of these contractual arrangements are subject to the provisions of ASC Topic 842, and any non-lease components are subject to other applicable accounting guidance; however, we have elected to adopt the optional practical expedient not to separate lease components apart from non-lease components for accounting purposes. This policy election has been adopted for each of the company’s leased asset classes existing as of the effective date and subject to the transition provisions of ASC Topic 842 and will be applied to all new or modified leases executed on or after January 1, 2019. For contractual arrangements executed in subsequent periods involving a new leased asset class, the company will determine at contract inception whether it will apply the optional practical expedient to the new leased asset class. Leases are evaluated for classification as operating or finance leases at the commencement date of the lease and right-of-use assets and corresponding liabilities are recognized on our consolidated balance sheet based on the present value of future lease payments relating to the use of the underlying asset during the lease term. Future lease payments include variable lease payments that depend upon an index or rate using the index or rate at the commencement date and probable amounts owed under residual value guarantees. The amount of future lease payments may be increased to include additional payments related to lease extension, termination, and/or purchase options when the company has determined, at or subsequent to lease commencement, generally due to limited asset availability or operating commitments, it is reasonably certain of exercising such options. We use our incremental borrowing rate as the discount rate in determining the present value of future lease payments, unless the interest rate implicit in the lease arrangement is readily determinable. Lease payments that vary subsequent to the commencement date based on future usage levels, the nature of leased asset activities, or certain other contingencies are not included in the measurement of lease right-of-use assets and corresponding liabilities. We have elected not to record assets and liabilities on our consolidated balance sheet for lease arrangements with terms of 12 months or less. We often enter into leasing arrangements acting in the capacity as operator for and/or on behalf of certain oil and gas joint ventures of undivided interests. If the lease arrangement can be legally enforced only against us as operator and there is no separate arrangement to sublease the underlying leased asset to our coventurers, we recognize at lease commencement a right-of-use asset and corresponding lease liability on our consolidated balance sheet on a gross basis. While we record lease costs on a gross basis in our consolidated income statement and statement of cash flows, such costs are offset by the reimbursement we receive from our coventurers for their share of the lease cost as the underlying leased asset is utilized in joint venture activities. As a result, lease cost is presented in our consolidated income statement and statement of cash flows on a proportional basis. If we are a nonoperating coventurer, we recognize a right-of-use asset and corresponding lease liability only if we were a specified contractual party to the lease arrangement and the arrangement could be legally enforced against us. In this circumstance, we would recognize both the right-of-use asset and corresponding lease liability on our consolidated balance sheet on a proportional basis consistent with our undivided interest ownership in the related joint venture. The company has historically recorded certain finance leases executed by investee companies accounted for under the proportionate consolidation method of accounting on its consolidated balance sheet on a proportional basis consistent with its ownership interest in the investee company. In addition, the company has historically recorded finance lease assets and liabilities associated with certain oil and gas joint ventures on a proportional basis pursuant to accounting guidance applicable prior to January 1, 2019. In accordance with the transition provisions of ASC Topic 842, and since we have elected to adopt the package of optional transition-related practical expedients, the historical accounting treatment for these leases has been carried forward and is subject to reconsideration upon the modification or other required reassessment of the arrangements prior to lease term expiration. The following table summarizes the right-of-use assets and lease liabilities for both the operating and finance leases on our consolidated balance sheet as of December 31: Millions of Dollars 2020 2019 Operating Leases Finance Leases Operating Leases Finance Leases Right-of-Use Assets Properties, plants and equipment Gross $ 1,375 1,039 Accumulated DD&A (721) (649) Net PP&E * 654 390 Prepaid expenses and other current assets $ - 40 Other assets 783 896 Lease Liabilities Short-term debt $ 168 87 Other accruals 226 347 Long-term debt * 723 633 Other liabilities and deferred credits 559 585 Total lease liabilities $ 785 891 932 720 * Includes proportionately consolidated finance lease assets of $ 258 million at December 31, 2020 and $ 335 million at December 31, 2019. Includes proportionately consolidated finance lease liabilities of $ 97 million at December 31, 2020 and $ 56 million at December 31, 2019. * Includes proportionately consolidated finance lease liabilities of $ 522 million at December 31, 2020 and $ 579 million at December 31, 2019. The following table summarizes our lease costs for 2020 and 2019: Millions of Dollars 2020 2019 Lease Cost * Operating lease cost $ 321 341 Finance lease cost Amortization of right-of-use assets 163 99 Interest on lease liabilities 34 37 Short-term lease cost 42 77 Total lease cost * $ 560 554 * The amounts presented in the table above have not been adjusted to reflect amounts recovered or reimbursed from oil and gas coventurers. Short-term leases are not recorded on our consolidated balance sheet. * Variable lease cost and sublease income are immaterial for the periods presented and therefore are not included in the table above . The following table summarizes the lease terms and discount rates as of December 31: 2020 2019 Lease Term and Discount Rate Weighted-average term (years) Operating leases 6.11 5.19 Finance leases 7.12 8.70 Weighted-average discount rate (percent) Operating leases 2.78 3.10 Finance leases 4.27 5.53 The following table summarizes other lease information for 2020 and 2019: Millions of Dollars 2020 2019 Other Information * Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 232 203 Operating cash flows from finance leases 11 27 Financing cash flows from finance leases 255 81 Right-of-use assets obtained in exchange for operating lease liabilities $ 250 499 Right-of-use assets obtained in exchange for finance lease liabilities 426 26 The amounts presented in the table above have not been adjusted to reflect amounts recovered or reimbursed from oil and gas coventurers. In addition, pursuant to other applicable accounting guidance, lease payments made in connection with preparing another asset for its intended use are reported in the "Cash Flows From Investing Activities" section of our consolidated statement of cash flows. The following table summarizes future lease payments for operating and finance leases at December 31, 2020: Millions of Dollars Operating Leases Finance Leases Maturity of Lease Liabilities 2021 $ 245 213 2022 155 162 2023 116 148 2024 94 113 2025 55 87 Remaining years 200 320 Total 865 1,043 Less: portion representing imputed interest (80) (152) Total lease liabilities $ 785 891 *Future lease payments for operating and finance leases commencing on or after January 1, 2019, also include payments related to non-lease components in accordance with our election to adopt the optional practical expedient not to separate lease components apart from non-lease components for accounting purposes. In addition, future payments related to operating and finance leases proportionately consolidated by the company have been included in the table on a proportionate basis consistent with our respective ownership interest in the underlying investee company or oil and gas venture. For the year ended December 31, 2018 operating lease rental expense pursuant to ASC Topic 840 was: Millions of Dollars Total rentals $ 253 Less: sublease rentals (16) $ 237

Employee Benefit Plans	12 Months Ended
Employee Benefit Plans	Dec. 31, 2020
Compensation And Retirement Disclosure [Abstract]
Employee Benefit Plans	Note 17—Employee Benefit Plans Pension and Postretirement Plans An analysis of the projected benefit obligations for our pension plans and accumulated benefit obligations for our postretirement health and life insurance plans follows: Millions of Dollars Pension Benefits Other Benefits 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 2,319 3,880 2,136 3,438 216 218 Service cost 85 54 79 69 2 1 Interest cost 66 85 79 97 6 8 Plan participant contributions - 1 - 2 18 20 Plan amendments - 2 - - (30) - Actuarial loss 319 398 278 387 7 27 Benefits paid (241) (151) (253) (147) (49) (59) Curtailment - 2 - (69) - - Recognition of termination benefits - 3 - 1 - - Foreign currency exchange rate change - 129 - 102 - 1 Benefit obligation at December 31 * $ 2,548 4,403 2,319 3,880 170 216 Accumulated benefit obligation portion of above at December 31: $ 2,359 4,095 2,161 3,594 Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 1,591 4,306 1,336 3,358 - - Actual return on plan assets 321 416 273 529 - - Company contributions 99 60 235 464 31 39 Plan participant contributions - 1 - 2 18 20 Benefits paid (241) (151) (253) (147) (49) (59) Foreign currency exchange rate change - 161 - 100 - - Fair value of plan assets at December 31 $ 1,770 4,793 1,591 4,306 - - Funded Status $ (778) 390 (728) 426 (170) (216) Millions of Dollars Pension Benefits Other Benefits 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 746 - 765 - - Current liabilities (56) (11) (21) (6) (39) (42) Noncurrent liabilities (722) (345) (707) (333) (131) (174) Total recognized $ (778) 390 (728) 426 (170) (216) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 2.30 % 1.80 3.25 2.35 2.15 3.10 Rate of compensation increase 4.00 3.10 4.00 3.35 Interest crediting rate for applicable benefits 2.10 - 4.10 - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.05 % 2.35 3.95 2.90 3.10 4.05 Expected return on plan assets 5.80 3.60 5.80 4.10 Rate of compensation increase 4.00 3.35 4.00 3.65 Interest crediting rate for applicable benefits 4.10 - 4.35 - For both U.S. and international pensions, the overall expected long-term rate of return is developed from the expected future return of each asset class, weighted by the expected allocation of pension assets to that asset class. We rely on a variety of independent market forecasts in developing the expected rate of return for each class of assets. The following tables set forth information related to the Company’s pension plans with projected and accumulated benefit obligations in excess of the fair value of the plans’ assets as of December 31, 2020 and 2019: Millions of Dollars Pension Benefits 2020 2019 U.S. Int’l. U.S. Int’l. Pension Plans with Projected Benefit Obligation in Excess of Plan Assets Projected benefit obligation $ 2,548 391 2,319 355 Fair value of plan assets 1,770 35 1,591 44 Pension Plans with Accumulated Benefit Obligation in Excess of Plan Assets Accumulated benefit obligation $ 2,359 338 2,161 299 Fair value of plan assets 1,770 35 1,591 44 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 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial loss $ 467 326 479 227 14 8 Unrecognized prior service credit - - - (2) (182) (183) Millions of Dollars Pension Benefits Other Benefits 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ (83) (120) (79) 51 (7) (27) Amortization of actuarial (gain) loss included in income (loss) 95 21 116 32 1 (2) Net change during the period $ 12 (99) 37 83 (6) (29) Prior service credit (cost) arising during the period $ - (1) - - 30 - Amortization of prior service cost (credit) included in income (loss) - (1) - (2) (31) (33) Net change during the period $ - (2) - (2) (1) (33) Includes settlement (gains) losses recognized in 2020 and 2019. 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 2020 2019 2018 2020 2019 2018 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 85 54 79 69 83 81 2 1 1 Interest cost 66 85 79 97 99 107 6 8 8 Expected return on plan assets (85) (145) (74) (138) (114) (155) - - - Amortization of prior service credit - (1) - (2) - (5) (31) (33) (35) Recognized net actuarial loss (gain) 51 22 54 32 53 31 1 (2) (1) Settlements loss (gain) 44 (1) 62 - 196 - - - - Net periodic benefit cost $ 161 14 200 58 317 59 (22) (26) (27) The components of net periodic benefit cost, other than the service cost component, are included in the “Other expenses” line item on our consolidated income statement. We recognized pension settlement losses of $ 43 million in 2020, $ 62 million in 2019, and $ 196 million in 2018 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. During 2020 and 2019, the actuarial losses related to the benefit obligation for U.S. and international plans were primarily related to a decrease in the discount rates. The sale of two ConocoPhillips U.K. subsidiaries completed during the third quarter of 2019 led to a significant reduction of future services of active employees in certain international pension plans, resulting in a curtailment. In conjunction with the recognition of the curtailment, the fair market values of pension plan assets were updated, the pension benefit obligation was remeasured, and the net pension asset decreased by $ 43 million, resulting in a corresponding decrease to other comprehensive income. This is primarily a result of a decrease in the discount rate from 2.90 percent at December 31, 2018 to 1.80 percent at September 30, 2019 offset by a decrease in the pension benefit obligation from curtailment. 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 7 percent in 2021 that declines to 5 percent by 2028. The measurement of the U.S. post-65 retiree medical accumulated postretirement benefit obligation assumes an ultimate health care cost trend rate of 4 percent achieved in 2021 that increases to 5 percent by 2028. Plan Assets —We follow a policy of broadly diversifying pension plan assets across asset classes and individual holdings. As a result, our plan assets have no significant concentrations of credit risk. Asset classes that are considered appropriate include U.S. equities, non-U.S. equities, U.S. fixed income, non-U.S. fixed income, real estate and private equity investments. Plan fiduciaries may consider and add other asset classes to the investment program from time to time. The target allocations for plan assets are 28 percent equity securities, 68 percent debt securities, 3 percent real estate and 1 percent other. Generally, the plan investments are publicly traded, therefore minimizing liquidity risk in the portfolio. The following is a description of the valuation methodologies used for the pension plan assets. There have been no changes in the methodologies used at December 31, 2020 and 2019. ● Fair values of equity securities and government debt securities categorized in Level 1 are primarily based on quoted market prices in active markets for identical assets and liabilities. ● Fair values of corporate debt securities, agency and mortgage-backed securities and government debt securities categorized in Level 2 are estimated using recently executed transactions and quoted market prices for similar assets and liabilities in active markets and for identical assets and liabilities in markets that are not 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 shares held. ● Time deposits are valued at cost, which approximates fair value. ● Cash is valued at cost, which approximates fair value. Fair values of international cash equivalents categorized in Level 2 are valued using observable yield curves, discounting and interest rates. U.S. cash balances held in the form of short-term fund units that are redeemable at the measurement date are categorized as Level 2. ● Fair values of exchange-traded derivatives classified in Level 1 are based on quoted market prices. For other derivatives classified in Level 2, the values are generally calculated from pricing models with market input parameters from third-party sources. ● Fair values of insurance contracts are valued at the present value of the future benefit payments owed by the insurance company to the plans’ participants. ● Fair values of real estate investments are valued using real estate valuation techniques and other methods that include reference to third-party sources and sales comparables where available. ● A portion of U.S. pension plan assets is 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 accumulated benefit obligation covered by the contract. The participating interest is classified as Level 3 in the fair value hierarchy as the fair value is determined via a combination of quoted market prices, recently executed transactions, and an actuarial present value computation for contract obligations. At December 31, 2020, the participating interest in the annuity contract was valued at $ 94 million and consisted of $ 233 million in debt securities, less $ 139 million for the accumulated benefit obligation covered by the contract. At December 31, 2019, the participating interest in the annuity contract was valued at $ 95 million and consisted of $ 235 million in debt securities, less $ 140 million for the accumulated benefit obligation covered by the contract. The participating interest is not available for meeting general pension benefit obligations in the near term. No future company contributions are required and no new benefits are being accrued under this insurance annuity contract. The fair values of our pension plan assets at December 31, by asset class were as follows: Millions of Dollars U.S. International Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total 2020 Equity securities U.S. $ - 3 5 8 - - - - International 99 - - 99 - - - - Mutual funds 72 - - 72 235 734 - 969 Debt securities Corporate - 1 - 1 - - - - Mutual funds - - - - 455 - - 455 Cash and cash equivalents - - - - 74 - - 74 Derivatives - - - - 6 - - 6 Real estate - - - - - - 142 142 Total in fair value hierarchy $ 171 4 5 180 770 734 142 1,646 Investments measured at net asset value Equity securities Common/collective trusts $ 678 2,962 Debt securities Common/collective trusts 730 67 Cash and cash equivalents 8 - Real estate 79 112 Total** $ 171 4 5 1,675 770 734 142 4,787 In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets. Excludes the participating interest in the insurance annuity contract with a net asset of $ 94 million and net receivables related to security transactions of $ 7 million. The fair values of our pension plan assets at December 31, by asset class were as follows: Millions of Dollars U.S. International Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total 2019 Equity securities U.S. $ 94 - 7 101 435 - - 435 International 98 - - 98 266 - - 266 Mutual funds 93 - - 93 245 267 - 512 Debt securities Government - - - - 1,412 - - 1,412 Corporate - 2 - 2 - - - - Mutual funds - - - - 392 - - 392 Cash and cash equivalents - - - - 98 - - 98 Derivatives - - - - 11 - - 11 Real estate - - - - - - 132 132 Total in fair value hierarchy $ 285 2 7 294 2,859 267 132 3,258 Investments measured at net asset value Equity securities Common/collective trusts $ 457 167 Debt securities Common/collective trusts 637 760 Cash and cash equivalents 25 - Real estate 83 112 Total** $ 285 2 7 1,496 2,859 267 132 4,297 In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets. *Excludes the participating interest in the insurance annuity contract with a net asset of $ 95 million and net receivables related to security transactions of $ 9 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 2021, we expect to contribute approximately $ 265 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $ 75 million to our international qualified and nonqualified pension and postretirement benefit 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. 2021 $ 532 147 25 2022 289 151 21 2023 248 156 18 2024 232 162 16 2025 215 166 14 2026–2030 845 897 53 Severance Accrual The following table summarizes our severance accrual activity for 2020, 2019 and 2018: Millions of Dollars 2020 2019 2018 Balance at January 1 $ 23 48 53 Accruals 14 (1) 70 Benefit payments (13) (24) (73) Foreign currency translation adjustments - - (2) Balance at December 31 $ 24 23 48 Of the remaining balance at December 31, 2020, $ 8 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 17 investment options. 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. Effective January 1, 2019, new employees, rehires, and employees that elected to opt out of Title II are eligible to receive a Company Retirement Contribution (CRC) of 6 percent of eligible pay into their CPSP. After three years of service with the company, the employee is 100 percent vested in any CRC. Company contributions charged to expense for the CPSP and predecessor plans were $ 62 million in 2020, $ 82 million in 2019, and $ 82 million in 2018. We have several defined contribution plans for our international employees, each with its own terms and eligibility depending on location. Total compensation expense recognized for these international plans was approximately $ 25 million in 2020, $ 30 million in 2019, and $ 31 million in 2018. Share-Based Compensation Plans The 2014 Omnibus Stock and Performance Incentive Plan of ConocoPhillips (the Plan) was approved 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 employees 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 represented by awards granted under the prior plans that are forfeited, expire or are cancelled without delivery of shares of common stock or which result in the forfeiture of shares of common stock back to the company 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 units and performance share units to employees and non-employee directors who contribute to the company’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 generally provide accelerated vesting (i.e., a waiver of the remaining period of service required to earn an award) for awards held by employees at the time of their retirement. Some of our share-based awards vest ratably (i.e., portions of the award vest at different times) while some of our awards cliff vest (i.e., all of the award vests at the same time). We recognize expense on a straight-line basis over the service period for the entire award, whether the award was granted with ratable or cliff vesting. Compensation Expense —Total share-based compensation expense recognized in net income (loss) and the associated tax benefit for the years ended December 31 were as follows: Millions of Dollars 2020 2019 2018 Compensation cost $ 159 274 265 Tax benefit 40 71 64 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 fair market value 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. Beginning in 2018, stock option grants were discontinued and replaced with three-year, time-vested restricted stock units which generally will be cash-settled for 2018 and 2019 awards and stock-settled for 2020 awards. The following summarizes our stock option activity for the year ended December 31, 2020: Millions of Dollars Weighted-Average Aggregate Options Exercise Price Intrinsic Value Outstanding at December 31, 2019 18,040,197 $ 54.11 $ 206 Exercised (1,111,805) 38.80 23 Forfeited (5,867) 49.76 Expired or cancelled - Outstanding at December 31, 2020 16,922,525 $ 55.12 $ 22 Vested at December 31, 2020 16,922,525 $ 55.12 $ 22 Exercisable at December 31, 2020 16,922,525 $ 55.12 $ 22 The weighted-average remaining contractual term of outstanding options, vested options and exercisable options at December 31, 2020, were all 3.66 years. The aggregate intrinsic value of options exercised was $ 39 million in 2019 and $ 94 million in 2018. During 2020, we received $ 43 million in cash and realized a tax benefit of $ 9 million from the exercise of options. At December 31, 2020, all outstanding stock options were fully vested and there was no remaining compensation cost to be recorded. Stock Unit Program— Generally, restricted stock units are granted annually under the provisions of the Plan and vest in an aggregate installment on the third anniversary of the grant date. In addition, restricted stock units granted under the Plan for a variable long-term incentive program vest ratably in three equal annual installments beginning on the first anniversary of the grant date. Restricted stock units are also granted ad hoc to attract or retain key personnel, and the terms and conditions under which these restricted stock units vest vary by award . Stock-Settled Upon vesting, these restricted stock units are settled by issuing one share of ConocoPhillips common stock per unit. Units awarded to retirement eligible employees vest six months from the grant date; however, those units are not issued as common stock until the earlier of separation from the company or the end of the regularly scheduled vesting period. Until issued as stock, most recipients of the restricted stock units receive a cash payment of a dividend equivalent that is charged to retained earnings. Executive recipients receive an accrued reinvested dividend equivalent, subject to the terms and conditions of the award, that is charged to retained earnings. The grant date fair market value of these restricted stock units is deemed equal to the average ConocoPhillips stock price on the grant date. The grant date fair market value of units that do not receive a dividend equivalent while unvested is deemed equal to the average ConocoPhillips stock price on the grant date, less the net present value of the dividends that will not be received . The following summarizes our stock-settled stock unit activity for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 6,223,046 $ 55.99 Granted 2,890,840 57.40 Forfeited (127,181) 55.84 Issued (2,554,720) 50.16 $ 143 Outstanding at December 31, 2020 6,431,985 $ 58.94 Not Vested at December 31, 2020 4,230,413 59.01 At December 31, 2020, the remaining unrecognized compensation cost from the unvested stock-settled units was $ 101 million, which will be recognized over a weighted-average period of 1.71 years, the longest period being 2.14 years. The weighted-average grant date fair value of stock unit awards granted during 2019 and 2018 was $ 67.77 and $ 52.45 , respectively. The total fair value of stock units issued during 2019 and 2018 was $ 225 million and $ 154 million, respectively. Cash-Settled Cash settled executive restricted stock units granted in 2018 and 2019 replaced the stock option program. These restricted stock units, subject to elections to defer, 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. Units awarded to retirement eligible employees vest six months from the grant date; however, those units are not settled until the earlier of separation from the company or the end of the regularly scheduled vesting 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 settlement date. Recipients receive an accrued reinvested dividend equivalent that is charged to compensation expense. The accrued reinvested dividend is paid at the time of settlement, subject to the terms and conditions of the award. Beginning with executive restricted stock units granted in 2020 awards will be settled in stock. The following summarizes our cash-settled stock unit activity for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 596,991 $ 64.54 Granted 24,437 41.59 Forfeited (5,622) 40.01 Issued (1,191) 40.20 $ - Outstanding at December 31, 2020 614,615 $ 39.95 Not Vested at December 31, 2020 121,696 39.95 At December 31, 2020, the remaining unrecognized compensation cost from the unvested cash-settled units was $ 1 million, which will be recognized over a weighted-average period of 1 year, the longest period being 1.12 years. The weighted-average grant date fair value of stock unit awards granted during 2019 and 2018 were $ 68.20 and $ 53.68 , respectively. The total fair value of stock units issued during 2019 and 2018 were $ 6 million and $ 1 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 service, and restrictions do not lapse until the employee separates from the company. With respect to awards for performance periods beginning in 2009 through 2012, PSUs do not vest until the earlier of the date the employee becomes eligible for retirement by reaching age 55 with five years of service or five years after the grant date of the award, and restrictions do not lapse until the earlier of the employee’s separation from the company or five years after the grant date (although recipients can elect to defer the lapsing of restrictions until separation). We recognize compensation expense for these awards beginning on the grant date and ending on the date the PSUs are scheduled to vest. Since these awards are authorized three years prior to the grant date, for employees eligible for retirement by or shortly after the grant date, we recognize compensation expense over the period beginning on the date of authorization and ending on the date of grant. Until issued as stock, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to retained earnings. Beginning in 2013, PSUs authorized for future grants will vest, absent employee election to defer, upon settlement following the conclusion of the three-year performance period. We recognize compensation expense over the period beginning on the date of authorization and ending on the conclusion of the performance period. PSUs are settled by issuing one share of ConocoPhillips common stock per unit. The following summarizes our stock-settled Performance Share Program activity for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 2,024,824 $ 50.55 Granted 26,244 58.61 Forfeited - Issued (314,340) 51.15 $ 13 Outstanding at December 31, 2020 1,736,728 $ 50.56 Not Vested at December 31, 2020 3,191 $ 48.61 At December 31, 2020, the remaining unrecognized compensation cost from unvested stock-settled performance share awards was zero . The weighted-average grant date fair value of stock-settled PSUs granted during 2019 and 2018 was $ 68.90 and $ 53.28 , respectively. The total fair value of stock-settled PSUs issued during 2019 and 2018 was $ 25 million and $ 29 million, respectively. Cash-Settled In connection with and immediately following the separation of our Downstream businesses in 2012, grants of new PSUs, subject to a shortened performance period, were authorized. Once granted, these PSUs vest, absent employee election to defer, on the earlier of five years after the grant date of the award or the date the employee becomes eligible for retirement. For employees eligible for retirement by or shortly after the grant date, we recognize compensation expense over the period beginning on the date of authorization and ending on the date of grant. Otherwise, we recognize compensation expense beginning on the grant date and ending on the date the PSUs are scheduled to vest. These PSUs are settled in cash equal to the fair market value of a share of ConocoPhillips common stock per unit on the settlement date and thus are classified as liabilities on the balance sheet. Until settlement occurs, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to compensation expense. Beginning in 2013, PSUs authorized for future grants will vest upon settlement following the conclusion of the three-year performance period. We recognize compensation expense over the period beginning on the date of authorization and ending at the conclusion of the performance period. These PSUs will be settled in cash equal to the 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. For performance periods beginning before 2018, during the performance period, recipients of the PSUs do not receive a quarterly cash payment of a dividend equivalent, but after the performance period ends, until settlement in cash occurs, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to compensation expense. For the performance period beginning in 2018, recipients of the PSUs receive an accrued reinvested dividend equivalent that is charged to compensation expense. The accrued reinvested dividend is paid at the time of settlement, subject to the terms and conditions of the award. The following summarizes our cash-settled Performance Share Program activity for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 609,274 $ 64.54 Granted 1,491,098 58.61 Forfeited - Settled (1,975,843) 58.54 $ 116 Outstanding at December 31, 2020 124,529 $ 39.95 At December 31, 2020, all outstanding cash-settled performance awards were fully vested and there was no remaining compensation cost to be recorded. The weighted-average grant date fair value of cash-settled PSUs granted during 2019 and 2018 was $ 68.90 and $ 53.28 , respectively. The total fair value of cash-settled performance share awards settled during 2019 and 2018 was $ 171 million and $ 22 million, respectively. From inception of the Performance Share Program through 2013, approved PSU awards were granted after the conclusion of performance periods. Beginning in February 2014, initial target PSU awards are issued near the beginning of new performance periods. These initial target PSU awards will terminate at the end of the performance periods and will be settled after the performance periods have ended. Also in 2014, initial target PSU awards were issued for open performance periods that began in prior years. For the open performance period beginning in 2012, the initial target PSU awards terminated at the end of the three-year performance period and were replaced with approved PSU awards. For the open performance period beginning in 2013, the initial target PSU awards terminated at the end of the three-year performance period and were settled after the performance period ended. There is no effect on recognition of compensation expense. Other —In addition to the above active programs, we have outstanding shares of restricted stock and restricted stock units that were either issued as part of our non-employee director compensation program for current and former members of the company’s Board of Directors or as part of an executive compensation program that has been discontinued. Generally, the recipients of the restricted shares or units receive a dividend or dividend equivalent. The following summarizes the aggregate activity of these restricted shares and units for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 991,908 $ 47.24 Granted 77,824 51.46 Cancelled (1,336) 23.09 Issued (98,297) 45.57 $ 6 Outstanding at December 31, 2020 970,099 $ 47.78 At December 31, 2020, all outstanding restricted stock and restricted stock units were fully vested and there was no remaining compensation cost to be recorded. The weighted-average grant date fair value of awards granted during 2019 and 2018 was $ 63.58 and $ 62.01 , respectively. The total fair value of awards issued during 2019 and 2018 was $ 11 million and $ 17 million, respectively.

The entire disclosure for retirement benefits.

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Income Taxes	12 Months Ended
Income Taxes	Dec. 31, 2020
Income Taxes [Abstract]
Income Taxes	Note 18—Income Taxes Components of income tax expense (benefit) were: Millions of Dollars 2020 2019 2018 Income Taxes Federal Current $ 3 18 4 Deferred (625) (113) 545 Foreign Current 350 2,545 3,273 Deferred (70) (323) (166) State and local Current (4) 148 108 Deferred (139) (8) (96) $ (485) 2,267 3,668 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 2020 2019 Deferred Tax Liabilities PP&E and intangibles $ 7,744 8,660 Inventory 64 35 Other 242 234 Total deferred tax liabilities 8,050 8,929 Deferred Tax Assets Benefit plan accruals 540 542 Asset retirement obligations and accrued environmental costs 2,262 2,339 Investments in joint ventures 1,653 1,722 Other financial accruals and deferrals 907 777 Loss and credit carryforwards 8,904 8,968 Other 365 345 Total deferred tax assets 14,631 14,693 Less: valuation allowance (9,965) (10,214) Total deferred tax assets net of valuation allowance 4,666 4,479 Net deferred tax liabilities $ 3,384 4,450 At December 31, 2020, noncurrent assets and liabilities included deferred taxes of $ 363 million and $ 3,747 million, respectively. At December 31, 2019, noncurrent assets and liabilities included deferred taxes of $ 184 million and $ 4,634 million, respectively. At December 31, 2020, the loss and credit carryforward deferred tax assets were primarily related to U.S. foreign tax credit carryforwards of $ 7 billion and various jurisdictions net operating loss and credit carryforwards of $ 1.9 billion. If not utilized, U.S. foreign tax credits and net operating losses will begin to expire in 2021. The following table shows a reconciliation of the beginning and ending deferred tax asset valuation allowance for for 2020, 2019 and 2018: Millions of Dollars 2020 2019 2018 Balance at January 1 $ 10,214 3,040 1,254 Charged to expense (benefit) 460 (225) (26) Other* (709) 7,399 1,812 Balance at December 31 $ 9,965 10,214 3,040 *Represents changes due to originating deferred tax asset that have no impact to our effective tax rate, acquisitions/dispositions/revisions and the effect of translating foreign financial statements. Certain items in the prior year have been reclassed to conform with the current year presentation, with no impacts to beginning and ending balances. Valuation allowances have been established to reduce deferred tax assets to an amount that will, more likely than not, be realized. At December 31, 2020, we have maintained a valuation allowance with respect to substantially all U.S. foreign tax credit carryforwards as well as certain net operating loss carryforwards for various jurisdictions. During 2020, the valuation allowance movement charged to earnings primarily relates to capital losses in Australia and to the fair value measurement of our Cenovus Energy common shares that are not expected to be realized. Other movements are primarily related to valuation allowances on expiring tax attributes. Based on our historical taxable income, expectations for the future, and available tax-planning strategies, management expects deferred tax assets, net of valuation allowances, will primarily be realized as offsets to reversing deferred tax liabilities. On December 2, 2019, the Internal Revenue Service finalized foreign tax credit regulations related to the 2017 Tax Cuts and Jobs Act. Due to the finalization of these regulations, in the fourth quarter of 2019 we recognized $ 151 million of net deferred tax assets. Correspondingly, we recorded $ 6,642 million of existing foreign tax credit carryovers where recognition was previously considered to be remote. Present legislation still makes their realization unlikely and therefore these credits have been offset with a full valuation allowance. At December 31, 2020, unremitted income considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures totaled approximately $ 3,982 million. Deferred income taxes have not been provided on this amount, as we do not plan to initiate any action that would require the payment of income taxes. The estimated amount of additional tax, primarily local withholding tax, that would be payable on this income if distributed is approximately $ 199 million. The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2020, 2019 and 2018: Millions of Dollars 2020 2019 2018 Balance at January 1 $ 1,177 1,081 882 Additions based on tax positions related to the current year 6 9 268 Additions for tax positions of prior years 67 120 43 Reductions for tax positions of prior years (34) (22) (73) Settlements (9) (9) (35) Lapse of statute (1) (2) (4) Balance at December 31 $ 1,206 1,177 1,081 Included in the balance of unrecognized tax benefits for 2020, 2019 and 2018 were $ 1,128 million, $ 1,100 million and $ 1,081 million, respectively, which, if recognized, would impact our effective tax rate. The balance of the unrecognized tax benefits increased in 2019 mainly due to the treatment of our PDVSA settlement. The balance of the unrecognized tax benefits increased in 2018 mainly due to the treatment of distributions from certain foreign subsidiaries. See Note 12—Contingencies and Commitments, for more information on the PDVSA settlement. At December 31, 2020, 2019 and 2018, accrued liabilities for interest and penalties totaled $ 46 million, $ 42 million and $ 45 million, respectively, net of accrued income taxes. Interest and penalties resulted in a reduction to earnings of $ 4 million in 2020, a benefit to earnings of $ 3 million in 2019, and a benefit to earnings of $ 4 million in 2018, respectively. We 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: U.K. (2015), Canada (2014), U.S. (2014) and Norway (2019). Issues in dispute for audited years and audits for subsequent years are ongoing and in various stages of completion in the many jurisdictions in which we operate around the world. Consequently, the balance in unrecognized tax benefits can be expected to fluctuate from period to period. It is reasonably possible such changes could be significant when compared with our total unrecognized tax benefits, but the amount of change is not estimable. The amounts of U.S. and foreign income (loss) before income taxes, with a reconciliation of tax at the federal statutory rate to the provision for income taxes, were: Millions of Dollars Percent of Pre-Tax Income (Loss) 2020 2019 2018 2020 2019 2018 Income (loss) before income taxes United States $ (3,587) 4,704 2,867 114.2 % 49.4 28.7 Foreign 447 4,820 7,106 (14.2) 50.6 71.3 $ (3,140) 9,524 9,973 100.0 % 100.0 100.0 Federal statutory income tax $ (659) 2,000 2,095 21.0 % 21.0 21.0 Non-U.S. effective tax rates 194 1,399 1,766 (6.2) 14.7 17.7 Tax Legislation - - (10) - - (0.1) Australia disposition (349) - - 11.1 - - U.K. disposition - (732) (150) - (7.7) (1.5) Recovery of outside basis (22) (77) (21) 0.7 (0.8) (0.2) Adjustment to tax reserves 18 9 (4) (0.6) 0.1 - Adjustment to valuation allowance 460 (225) (26) (14.6) (2.4) (0.3) State income tax (112) 123 135 3.6 1.3 1.4 Malaysia Deepwater Incentive - (164) - - (1.7) - Enhanced oil recovery credit (6) (27) (99) 0.2 (0.3) (1.0) Other (9) (39) (18) 0.3 (0.4) (0.2) $ (485) 2,267 3,668 15.5 % 23.8 36.8 Our effective tax rate for 2020 was impacted by the disposition of our Australia-West assets as well as the valuation allowance related to the fair value measurement of our Cenovus Energy common shares. The Australia-West disposition generated a before-tax gain of $ 587 million with an associated tax benefit of $ 10 million and resulted in the de-recognition of deferred tax assets resulting in $ 92 million of tax expense. The disposition also generated an Australia capital loss tax benefit of $ 313 million which has been fully offset by a valuation allowance. Due to changes in the fair market value of Cenovus Energy common shares, the valuation allowance was increased by $ 178 million to offset the expected capital loss. Our effective tax rate for 2019 was favorably impacted by the sale of two of our U.K. subsidiaries. The disposition generated a before-tax gain of more than $ 1.7 billion with an associated tax benefit of $ 335 million. The disposition generated a U.S. capital loss of approximately $ 2.1 billion which has generated a U.S. tax benefit of approximately $ 285 million. The remaining U.S. capital loss has been recorded as a deferred tax asset fully offset with a valuation allowance. See Note 4—Asset Acquisitions and Dispositions, for additional information on the disposition. During the third quarter of 2019, we received final partner approval in Malaysia Block G to claim certain deepwater tax credits. As a result, we recorded an income tax benefit of $ 164 million. The decrease in the effective tax rate for 2018 was primarily due to the impact of the Clair Field disposition in the U.K. and our overall income position, partially offset by our change in mix of income among taxing jurisdictions. Our effective tax rate for 2018 was favorably impacted by the sale of a U.K. subsidiary to BP. The subsidiary held 16.5 percent of our 24 percent interest in the BP-operated Clair Field in the U.K. The disposition generated a before-tax gain of $ 715 million with no associated tax cost. See Note 4—Asset Acquisitions and Dispositions, for additional information on the disposition. As a result of the COVID-19 pandemic and the resulting economic uncertainty, many countries in which we operate, including Australia, Canada, Norway and the U.S., have enacted responsive tax legislation. During the second quarter, Norway enacted legislation to accelerate the recovery of capital expenditures and allow immediate monetization of tax losses. As a result, in the second quarter of 2020, we recorded an increase to our net deferred tax liability of $ 120 million and a decrease to our accrued income and other taxes liability of $ 124 million. Legislation in other jurisdictions did not have a material impact to ConocoPhillips.

The entire disclosure for income taxes. Disclosures may include net deferred tax liability or asset recognized in an enterprise's statement of financial position, net change during the year in the total valuation allowance, approximate tax effect of each type of temporary difference and carryforward that gives rise to a significant portion of deferred tax liabilities and deferred tax assets, utilization of a tax carryback, and tax uncertainties information.

Accumulated Other Comprehensive Income	12 Months Ended
Accumulated Other Comprehensive Income	Dec. 31, 2020
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Income	Note 19—Accumulated Other Comprehensive Loss Accumulated other comprehensive loss in the equity section of the balance sheet included: Millions of Dollars Defined Benefit Plans Net Unrealized Loss on Securities Foreign Currency Translation Accumulated Other Comprehensive Loss December 31, 2017 $ (400) (58) (5,060) (5,518) Other comprehensive income (loss) 39 - (642) (603) Cumulative effect of adopting ASU No. 2016-01* - 58 - 58 December 31, 2018 (361) - (5,702) (6,063) Other comprehensive income 51 - 695 746 Cumulative effect of adopting ASU No. 2018-02** (40) - - (40) December 31, 2019 (350) - (5,007) (5,357) Other comprehensive income (loss) (75) 2 212 139 December 31, 2020 $ (425) 2 (4,795) (5,218) We adopted ASU No. 2016-01, "Recognition and Measurement of Financial Assets and Liabilities," beginning January 1, 2018. *We adopted ASU No. 2018-02, "Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income," beginning January 1, 2019. During 2019, we recognized $ 483 million of foreign currency translation adjustments related to the completion of our sale of two ConocoPhillips U.K. subsidiaries. For additional information related to this disposition, see Note 4—Asset Acquisitions and Dispositions. The following table summarizes reclassifications out of accumulated other comprehensive loss during the years ended December 31: Millions of Dollars 2020 2019 Defined Benefit Plans $ 72 88 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 13 23 See Note 17—Employee Benefit Plans, for additional information.

Cash Flow Information	12 Months Ended
Cash Flow Information	Dec. 31, 2020
Cash Flow Information [Abstract]
Cash Flow Information	Note 20—Cash Flow Information Millions of Dollars 2020 2019 2018 Noncash Investing Activities Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations $ (116) 205 395 Increase (decrease) in assets and liabilities acquired in a nonmonetary exchange* Accounts receivable - - (44) Inventories - - 42 Investments and long-term receivables - - 15 PP&E - - 1,907 Other long-term assets - - (9) Accounts payable - - 7 Accrued income and other taxes - - 40 Cash Payments Interest $ 785 810 772 Income taxes 905 2,905 2,976 Net Sales (Purchases) of Investments Short-term investments purchased $ (12,435) (4,902) (1,953) Short-term investments sold 12,015 2,138 3,573 Investments and long-term receivables purchased (325) (146) - Investments and long-term receivables sold 87 - - $ (658) (2,910) 1,620 *See Note 4—Asset Acquisitions and Dispositions. The following items are included in the “Cash Flows from Operating Activities” section of our consolidated cash flows. We collected $ 330 million and $ 430 million in 2019 and 2018, respectively, from PDVSA under a settlement agreement related to an award issued by the ICC Tribunal in 2018. For more information on these settlements, see Note 12—Contingencies and Commitments. We collected $ 262 million from Ecuador in 2018, as installment payments related to an agreement reached with Ecuador in 2017. In 2019, we made a $ 324 million contribution to our U.K. pension plan. We made discretionary payments to our domestic qualified pension plan of $ 120 million in 2018.

Other Financial Information	12 Months Ended
Other Financial Information	Dec. 31, 2020
Other Financial Information [Abstract]
Other Financial Information	Note 21—Other Financial Information Millions of Dollars 2020 2019 2018 Interest and Debt Expense Incurred Debt $ 788 799 838 Other 73 36 67 861 835 905 Capitalized (55) (57) (170) Expensed $ 806 778 735 Other Income (Loss) Interest income $ 100 166 97 Unrealized gains (losses) on Cenovus Energy common shares* (855) 649 (437) Other, net 246 543 513 $ (509) 1,358 173 See Note 6—Investment in Cenovus Energy, for additional information. Research and Development Expenditures —expensed $ 75 82 78 Shipping and Handling Costs $ 857 1,008 1,075 Foreign Currency Transaction (Gains) Losses —after-tax Alaska $ - - - Lower 48 - - - Canada (7) 5 (11) Europe, Middle East and North Africa (15) - (26) Asia Pacific (11) 31 3 Other International 2 1 - Corporate and Other (31) 21 21 $ (62) 58 (13) Millions of Dollars 2020 2019 Properties, Plants and Equipment Proved properties $ 94,312 88,284 Unproved properties 4,141 3,980 * Other 3,653 5,482 Gross properties, plants and equipment 102,106 97,746 Less: Accumulated depreciation, depletion and amortization (62,213) (55,477) * Net properties, plants and equipment $ 39,893 42,269 *Excludes assets classified as held for sale at December 31, 2019. See Note 4 — Asset Acquisitions and Dispositions, for additional information.

Related Party Transactions	12 Months Ended
Related Party Transactions	Dec. 31, 2020
Related Party Transactions [Abstract]
Related Party Transactions	Note 22—Related Party Transactions Our related parties primarily include equity method investments and certain trusts for the benefit of employees. For disclosures on trusts for the benefit of employees, see Note 17 — Employee Benefit Plans. Significant transactions with our equity affiliates were: Millions of Dollars 2020 2019 2018 Operating revenues and other income $ 79 89 98 Purchases - 38 98 Operating expenses and selling, general and administrative expenses 63 65 60 Net interest income* (5) (13) (14) *We paid interest to, or received interest from, various affiliates. See Note 5—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Sales and Other Operating Revenues	12 Months Ended
Sales and Other Operating Revenues	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Revenue from Contract with Customer	Note 23—Sales and Other Operating Revenues Revenue from Contracts with Customers The following table provides further disaggregation of our consolidated sales and other operating revenues: Millions of Dollars 2020 2019 2018 Revenue from contracts with customers $ 13,662 26,106 28,098 Revenue from contracts outside the scope of ASC Topic 606 Physical contracts meeting the definition of a derivative 5,177 6,558 8,218 Financial derivative contracts (55) (97) 101 Consolidated sales and other operating revenues $ 18,784 32,567 36,417 Revenues from contracts outside the scope of ASC Topic 606 relate primarily to physical gas contracts at market prices which qualify as derivatives accounted for under ASC Topic 815, “Derivatives and Hedging,” and for which we have not elected NPNS. There is no significant difference in contractual terms or the policy for recognition of revenue from these contracts and those within the scope of ASC Topic 606. The following disaggregation of revenues is provided in conjunction with Note 24—Segment Disclosures and Related Information: Millions of Dollars 2020 2019 2018 Revenue from Outside the Scope of ASC Topic 606 by Segment Lower 48 $ 3,966 4,989 6,358 Canada 727 691 629 Europe, Middle East and North Africa 484 878 1,231 Physical contracts meeting the definition of a derivative $ 5,177 6,558 8,218 Millions of Dollars 2020 2019 2018 Revenue from Outside the Scope of ASC Topic 606 by Product Crude oil $ 395 804 1,112 Natural gas 4,339 5,313 6,734 Other 443 441 372 Physical contracts meeting the definition of a derivative $ 5,177 6,558 8,218 Practical Expedients Typically, our commodity sales contracts are less than 12 months in duration; however, in certain specific cases may extend longer, which may be out to the end of field life. We have long-term commodity sales contracts which use prevailing market prices at the time of delivery, and under these contracts, the market- based variable consideration for each performance obligation (i.e., delivery of commodity) is allocated to each wholly unsatisfied performance obligation within the contract. Accordingly, we have applied the practical expedient allowed in ASC Topic 606 and do not disclose the aggregate amount of the transaction price allocated to performance obligations or when we expect to recognize revenues that are unsatisfied (or partially unsatisfied) as of the end of the reporting period. Receivables and Contract Liabilities Receivables from Contracts with Customers At December 31, 2020, the “Accounts and notes receivable” line on our consolidated balance sheet included trade receivables of $ 1,827 million compared with $ 2,372 million at December 31, 2019, and included both contracts with customers within the scope of ASC Topic 606 and those that are outside the scope of ASC Topic 606. We typically receive payment within 30 days or less (depending on the terms of the invoice) once delivery is made. Revenues that are outside the scope of ASC Topic 606 relate primarily to physical gas sales contracts at market prices for which we do not elect NPNS and are therefore accounted for as a derivative under ASC Topic 815. There is little distinction in the nature of the customer or credit quality of trade receivables associated with gas sold under contracts for which NPNS has not been elected compared with trade receivables where NPNS has been elected. Contract Liabilities from Contracts with Customers We have entered into contractual arrangements where we license proprietary technology to customers related to the optimization process for operating LNG plants. The agreements typically provide for negotiated payments to be made at stated milestones. The payments are not directly related to our performance under the contract and are recorded as deferred revenue to be recognized as revenue when the customer can utilize and benefit from their right to use the license. Payments are received in installments over the construction period. Millions of Dollars Contract Liabilities At December 31, 2019 $ 80 Contractual payments received 17 At December 31, 2020 $ 97 Amounts Recognized in the Consolidated Balance Sheet at December 31, 2020 Current liabilities $ 56 Noncurrent liabilities 41 $ 97 We expect to recognize the contract liabilities as of December 31, 2020, as revenue during 2021 and 2022. There was no revenue recognized during the year ended December 31, 2020.

The entire disclosure of revenue from contract with customer to transfer good or service and to transfer nonfinancial asset. Includes, but is not limited to, disaggregation of revenue, credit loss recognized from contract with customer, judgment and change in judgment related to contract with customer, and asset recognized from cost incurred to obtain or fulfill contract with customer. Excludes insurance and lease contracts.

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Segment Disclosures and Related Information	12 Months Ended
Segment Disclosures and Related Information	Dec. 31, 2020
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 NGLs on a worldwide basis. We manage our operations through six operating segments, which are primarily defined by geographic region: Alaska; Lower 48; Canada; Europe, Middle East and North Africa; Asia Pacific; and Other International. Corporate and Other represents income and costs not directly associated with an operating segment, such as most interest expense, premiums on early retirement of debt, corporate overhead and certain technology activities, including licensing revenues. Corporate assets include all cash and cash equivalents and short-term investments. We evaluate performance and allocate resources based on net income (loss) attributable to ConocoPhillips. Segment accounting policies are the same as those in Note 1—Accounting Policies. Intersegment sales are at prices that approximate market. Effective with the third quarter of 2020, we restructured our segments to align with changes to our internal organization. The Middle East business was realigned from the Asia Pacific and Middle East segment to the Europe and North Africa segment. The segments have been renamed the Asia Pacific segment and the Europe, Middle East and North Africa segment. We have revised segment information disclosures and segment performance metrics presented within our results of operations for the current and prior comparative periods. Analysis of Results by Operating Segment Millions of Dollars 2020 2019 2018 Sales and Other Operating Revenues Alaska $ 3,408 5,483 5,740 Intersegment eliminations (11) - - Alaska 3,397 5,483 5,740 Lower 48 9,872 15,514 17,029 Intersegment eliminations (51) (46) (40) Lower 48 9,821 15,468 16,989 Canada 1,666 2,910 3,184 Intersegment eliminations (405) (1,141) (1,160) Canada 1,261 1,769 2,024 Europe, Middle East and North Africa 1,919 5,101 6,635 Intersegment eliminations (2) - - Europe, Middle East and North Africa 1,917 5,101 6,635 Asia Pacific 2,363 4,525 4,861 Other International 7 - - Corporate and Other 18 221 168 Consolidated sales and other operating revenues $ 18,784 32,567 36,417 The market for our products is large and diverse, therefore, our sales and other operating revenues are not dependent upon any single customer. Millions of Dollars 2020 2019 2018 Depreciation, Depletion, Amortization and Impairments Alaska $ 996 805 760 Lower 48 3,358 3,224 2,370 Canada 342 232 324 Europe, Middle East and North Africa 775 887 1,041 Asia Pacific 809 1,285 1,382 Other International - - - Corporate and Other 54 62 106 Consolidated depreciation, depletion, amortization and impairments $ 6,334 6,495 5,983 Equity in Earnings of Affiliates Alaska $ (7) 7 6 Lower 48 (11) (159) 1 Canada - - - Europe, Middle East and North Africa 311 470 744 Asia Pacific 137 461 323 Other International 2 - - Corporate and Other - - - Consolidated equity in earnings of affiliates $ 432 779 1,074 Income Tax Provision (Benefit) Alaska $ (256) 472 376 Lower 48 (378) 137 474 Canada (185) (43) (96) Europe, Middle East and North Africa 136 1,425 2,259 Asia Pacific 294 501 728 Other International (20) 8 30 Corporate and Other (76) (233) (103) Consolidated income tax provision (benefit) $ (485) 2,267 3,668 Net Income (Loss) Attributable to ConocoPhillips Alaska $ (719) 1,520 1,814 Lower 48 (1,122) 436 1,747 Canada (326) 279 63 Europe, Middle East and North Africa 448 3,170 2,594 Asia Pacific 962 1,483 1,342 Other International (64) 263 364 Corporate and Other (1,880) 38 (1,667) Consolidated net income (loss) attributable to ConocoPhillips $ (2,701) 7,189 6,257 Millions of Dollars 2020 2019 2018 Investments in and Advances to Affiliates Alaska $ 62 83 86 Lower 48 25 35 378 Canada - - - Europe, Middle East and North Africa 918 1,070 1,311 Asia Pacific 6,705 7,265 7,565 Other International - - - Corporate and Other - - - Consolidated investments in and advances to affiliates $ 7,710 8,453 9,340 Total Assets Alaska $ 14,623 15,453 14,648 Lower 48 11,932 14,425 14,888 Canada 6,863 6,350 5,748 Europe, Middle East and North Africa 8,756 9,269 11,276 Asia Pacific 11,231 13,568 14,758 Other International 226 285 89 Corporate and Other 8,987 11,164 8,573 Consolidated total assets $ 62,618 70,514 69,980 Capital Expenditures and Investments Alaska $ 1,038 1,513 1,298 Lower 48 1,881 3,394 3,184 Canada 651 368 477 Europe, Middle East and North Africa 600 708 877 Asia Pacific 384 584 718 Other International 121 8 6 Corporate and Other 40 61 190 Consolidated capital expenditures and investments $ 4,715 6,636 6,750 Interest Income and Expense Interest income Alaska $ - - - Lower 48 - - - Canada - - - Europe, Middle East and North Africa 5 11 12 Asia Pacific 7 6 5 Other International - - - Corporate and Other 88 149 80 Interest and debt expense Corporate and Other $ 806 778 735 Sales and Other Operating Revenues by Product Crude oil $ 9,736 18,482 19,571 Natural gas 6,427 8,715 10,720 Natural gas liquids 528 814 1,114 Other* 2,093 4,556 5,012 Consolidated sales and other operating revenues by product $ 18,784 32,567 36,417 *Includes LNG and bitumen. Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2020 2019 2018 2020 2019 2018 United States $ 13,230 21,159 22,740 24,034 26,566 26,838 Australia and Timor-Leste 605 1,647 1,798 6,676 7,228 9,301 Canada 1,261 1,769 2,024 6,385 5,769 5,333 China 460 772 836 1,491 1,447 1,380 Indonesia 689 875 886 464 605 669 Libya 155 1,103 1,142 670 668 679 Malaysia 610 1,230 1,346 1,501 1,871 2,327 Norway 1,426 2,349 2,886 5,294 5,258 5,582 United Kingdom 336 1,649 2,606 1 2 1,583 Other foreign countries 12 14 153 1,087 1,308 1,346 Worldwide consolidated $ 18,784 32,567 36,417 47,603 50,722 55,038 (1) Sales and other operating revenues are attributable to countries based on the location of the selling operation. (2) Defined as net PP&E plus equity investments and advances to affiliated companies.

The entire disclosure for reporting segments including data and tables. Reportable segments include those that meet any of the following quantitative thresholds a) it's reported revenue, including sales to external customers and intersegment sales or transfers is 10 percent or more of the combined revenue, internal and external, of all operating segments b) the absolute amount of its reported profit or loss is 10 percent or more of the greater, in absolute amount of 1) the combined reported profit of all operating segments that did not report a loss or 2) the combined reported loss of all operating segments that did report a loss c) its assets are 10 percent or more of the combined assets of all operating segments.

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Reference 10: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 22
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Reference 11: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 42
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e9054-108599

Reference 12: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 15
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Reference 13: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-SubTopic 10
-Section 50
-Paragraph 21
-Subparagraph (b)
-URI http://asc.fasb.org/extlink&oid=120311839&loc=d3e8721-108599

Reference 14: http://www.xbrl.org/2003/role/disclosureRef
-Publisher FASB
-Name Accounting Standards Codification
-Topic 280
-URI http://asc.fasb.org/topic&trid=2134510

New Accounting Standards	12 Months Ended
New Accounting Standards	Dec. 31, 2020
New Accounting Pronouncements and Changes in Accounting Principles [Abstract]
New Accounting Standards [Text Block]	Note 2—Changes in Accounting Principles We adopted the provisions of FASB ASU No. 2016-13, “Measurement of Credit Losses on Financial Instruments,” (ASC Topic 326) and its amendments, beginning January 1, 2020. This ASU, as amended, sets forth the current expected credit loss model, a new forward-looking impairment model for certain financial instruments measured at amortized cost basis based on expected losses rather than incurred losses. This ASU, as amended, which primarily applies to our accounts receivable, also requires credit losses related to available- for-sale debt securities to be recorded through an allowance for credit losses. The adoption of this ASU did not have a material impact to our financial statements. The majority of our receivables are due within 30 days or less. We monitor the credit quality of our counterparties through review of collections, credit ratings, and other analyses. We develop our estimated allowance for credit losses primarily using an aging method and analyses of historical loss rates as well as consideration of current and future conditions that could impact our counterparties’ credit quality and liquidity.

Accounting Policies (Policies)	12 Months Ended
Accounting Policies (Policies)	Dec. 31, 2020
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 have the ability to exert significant influence, the investment is measured at fair value except when the investment does not have a readily determinable fair value. For those exceptions, it will be measured at cost minus impairment, plus or minus observable price changes in orderly transactions for an identical or similar investment of the same issuer. 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, Middle East and North Africa; Asia Pacific; and Other International. For additional information, see Note 24—Segment Disclosures and Related Information. The unrealized (gain) loss on investment in Cenovus Energy included on our consolidated statement of cash flows, previously reflected on the line item “Other” within net cash provided by operating activities, has been reclassified in the comparative periods to conform with the current period’s presentation.
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 loss in common stockholders’ equity. Foreign currency transaction gains and losses are included in current earnings. Some 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 U.S. 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 the sales of crude oil, bitumen, natural gas, LNG, NGLs and other items are recognized at the point in time when the customer obtains control of the asset. In evaluating when a customer has control of the asset, we primarily consider whether the transfer of legal title and physical delivery has occurred, whether the customer has significant risks and rewards of ownership, and whether the customer has accepted delivery and a right to payment exists. These products are typically sold at prevailing market prices. We allocate variable market-based consideration to deliveries (performance obligations) in the current period as that consideration relates specifically to our efforts to transfer control of current period deliveries to the customer and represents the amount we expect to be entitled to in exchange for the related products. Payment is typically due within 30 days or less. 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).
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.
Investment, Policy	Short-Term Investments —Short-term investments include investments in bank time deposits and marketable securities (commercial paper and government obligations) which are carried at cost plus accrued interest and have original maturities of greater than 90 days but within one year or when the remaining maturities are within one year. We also invest in financial instruments classified as available for sale debt securities which are carried at fair value. Those instruments are included in short-term investments when they have remaining maturities within one year as of the balance sheet date. Long-Term Investments in Debt Securities —Long-term investments in debt securities includes financial instruments classified as available for sale debt securities with remaining maturities greater than one year as of the balance sheet date. They are carried at fair value and presented within the “Investments and long-term receivables” line of our consolidated balance sheet.
Inventories	Inventories —We have several valuation methods for our various types of inventories and consistently use the following methods for each type of inventory. The majority of our commodity-related inventories are recorded at cost using the LIFO basis. We measure these inventories at the lower-of-cost-or-market in the aggregate. Any necessary lower-of-cost-or-market write-downs at year end are recorded as permanent adjustments to the LIFO cost basis. LIFO is used to better match current inventory costs with current revenues. Costs include both direct and indirect expenditures incurred in bringing an item or product to its existing condition and location, but not unusual/nonrecurring costs or research and development costs. Materials, supplies and other miscellaneous inventories, such as tubular goods and well equipment, are valued using various methods, including the weighted-average-cost method, and the FIFO method, consistent with industry practice.
Fair Value Measurements	Fair Value Measurements —Assets and liabilities measured at fair value and required to be categorized within the fair value hierarchy are categorized into one of three different levels depending on the observability of the inputs employed in the measurement. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are observable inputs other than quoted prices included within Level 1 for the asset or liability, either directly or indirectly through market-corroborated inputs. Level 3 inputs are unobservable inputs for the asset or liability reflecting significant modifications to observable related market data or our assumptions about pricing by market participants.
Derivative Instruments	Derivative Instruments —Derivative instruments are recorded on the balance sheet at fair value. If the right of offset exists and certain 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 the derivative. Gains and losses from derivatives not accounted for as hedges are recognized immediately in earnings.
Oil and Gas Exploration and Development	Oil and Gas Exploration and Development —Oil and gas exploration and development costs are accounted for using the successful efforts method of accounting. Property Acquisition Costs —Oil and gas leasehold acquisition costs are capitalized and included in the balance sheet caption 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 reclassified to proved properties. Exploratory Costs —Geological and geophysical costs and the costs of carrying and retaining undeveloped properties are expensed as incurred. Exploratory well costs are capitalized, or “suspended,” on the balance sheet pending further evaluation of whether economically recoverable reserves have been found. If economically recoverable reserves are not found, exploratory well costs are expensed as dry holes. If exploratory wells encounter potentially economic quantities of oil and gas, the well costs remain capitalized on the balance sheet as long as sufficient progress assessing the reserves and the economic and operating viability of the project is being made. For complex exploratory discoveries, it is not unusual to have exploratory wells remain suspended on the balance sheet for several years while we perform additional appraisal drilling and seismic work on the potential oil and gas field or while we seek government or co-venturer approval of development plans or seek environmental permitting. Once all required approvals and permits have been obtained, the projects are moved into the development phase, and the oil and gas resources are designated as proved 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 7— Suspended Wells and Exploration Expenses, for additional information on suspended wells. Development Costs —Costs incurred to drill and equip development wells, including unsuccessful development wells, are capitalized. Depletion and Amortization —Leasehold costs of producing properties are depleted using the unit- of-production method based on estimated proved oil and gas reserves. Amortization of intangible development costs is based on the unit-of-production method using estimated proved developed oil and gas reserves. ■ Capitalized Interest —Interest from external borrowings is capitalized on major projects with an expected construction period of one year or longer. Capitalized interest is added to the cost of the underlying asset and is amortized over the useful lives of the assets in the same manner as the underlying assets. ■ Depreciation and Amortization —Depreciation and amortization of PP&E on producing hydrocarbon properties and SAGD facilities and certain pipeline and LNG assets (those which are expected to have a declining utilization pattern), are determined by the unit-of-production method. Depreciation and amortization of all other PP&E are determined by either the individual-unit-straight-line method or the group-straight-line method (for those individual units that are highly integrated with other units). ■ Impairment of Properties, Plants and Equipment —PP&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. If there is an indication the carrying amount of an asset may not be recovered, a recoverability test is performed using management’s assumptions such as for prices, volumes and future development plans. If, upon review, the sum of the undiscounted cash flows before income-taxes is less than the carrying value of the asset group, the carrying value is written down to estimated fair value and reported as an impairment in the period 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 independent of the cash flows of other groups of assets—generally on a field-by-field basis for E&P assets. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates and prices 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 available, 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,
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 manner as the underlying assets.
Depreciation and Amortization	Depreciation and Amortization —Depreciation and amortization of PP&E on producing hydrocarbon properties and SAGD facilities and certain pipeline and LNG assets (those which are expected to have a declining utilization pattern), are determined by the unit-of-production method. Depreciation and amortization of all other PP&E are determined by either the individual-unit-straight-line method or the group-straight-line method (for those individual units that are highly integrated with other units).
Impairment of Properties, Plants and Equipment	Impairment of Properties, Plants and Equipment —PP&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. If there is an indication the carrying amount of an asset may not be recovered, a recoverability test is performed using management’s assumptions such as for prices, volumes and future development plans. If, upon review, the sum of the undiscounted cash flows before income-taxes is less than the carrying value of the asset group, the carrying value is written down to estimated fair value and reported as an impairment in the period 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 independent of the cash flows of other groups of assets—generally on a field-by-field basis for E&P assets. Because there usually is a lack of quoted market prices for long-lived assets, the fair value of impaired assets is typically determined based on the present values of expected future cash flows using discount rates and prices 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 available, or present value of expected future cash flows as previously described. The expected future cash flows used for impairment reviews and related fair value calculations are based on estimated future production volumes, prices and costs, considering all available evidence at the date of review. The impairment review includes cash flows from proved developed and undeveloped reserves, including any development expenditures necessary to achieve that production. Additionally, when probable and possible reserves exist, an appropriate risk-adjusted amount of these reserves may be included in the impairment calculation. ■ Impairment of Investments in Nonconsolidated Entities —Investments in nonconsolidated entities are assessed for impairment whenever changes in the facts and circumstances indicate a loss in value has occurred. When such a condition is judgmentally determined to be other than temporary, the carrying value of the investment is written 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 and prices believed to be consistent with those used by principal market participants, plus market analysis of comparable assets owned by the investee, if appropriate. ■ Maintenance and Repairs —Costs of maintenance and repairs, which are not significant improvements, are expensed when incurred. ■ Property Dispositions —When complete units of depreciable property are sold, the asset cost and related accumulated depreciation are eliminated, with any gain or loss reflected in the “Gain on dispositions” line of our consolidated income statement. When less than complete units of depreciable property are disposed of or retired which do not significantly alter the DD&A rate, 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 long-lived assets are recorded in the period in which the obligation is incurred (typically when the asset is installed at the production location). Fair value is estimated using a present value approach, incorporating assumptions about estimated amounts and timing of settlements and impacts of the use of technologies. 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 depreciated over the useful life of the related asset. Reductions to estimated liabilities for assets that are no longer producing are recorded as a credit to impairment, if the asset had been previously impaired, or as a credit to DD&A, if the asset had not been previously impaired. For additional information, see Note 9—Asset Retirement Obligations and Accrued Environmental Costs. Environmental expenditures are expensed or capitalized, depending upon their future economic benefit. 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 through a business combination, which we record on a discounted basis) when environmental assessments or cleanups are probable and the costs can be reasonably estimated. Recoveries of environmental remediation costs from other parties are recorded as assets when their receipt is probable and estimable. ■ Guarantees —The fair value of a guarantee is determined and recorded as a liability at the time the guarantee is given. The initial liability is subsequently reduced as we are released from exposure under the guarantee. We amortize the guarantee liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of guarantee. In cases where the guarantee term is indefinite, we reverse the liability when we have information indicating the liability is essentially relieved or amortize it over an appropriate time period as the fair value of our guarantee exposure declines over time. We amortize the guarantee liability to the related income statement line item based on the nature of the guarantee. When it becomes probable that we will have to perform on a guarantee, we accrue a separate liability if it is reasonably estimable, based on the facts and circumstances at that time. We reverse the fair value liability only when there is no further exposure under the guarantee. ■ Share-Based Compensation —We recognize share-based compensation expense over the shorter of the service period (i.e., the stated period of time required to 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
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. When such a condition is judgmentally determined to be other than temporary, the carrying value of the investment is written 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 and prices believed to be consistent with those used by principal market participants, plus market analysis of comparable assets owned by the investee, if appropriate.
Maintenance and Repairs	Maintenance and Repairs —Costs of maintenance and repairs, which are not significant improvements, are expensed when incurred.
Property Dispositions	Property Dispositions —When complete units of depreciable property are sold, the asset cost and related accumulated depreciation are eliminated, with any gain or loss reflected in the “Gain on dispositions” line of our consolidated income statement. When less than complete units of depreciable property are disposed of or retired which do not significantly alter the DD&A rate, 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 long-lived assets are recorded in the period in which the obligation is incurred (typically when the asset is installed at the production location). Fair value is estimated using a present value approach, incorporating assumptions about estimated amounts and timing of settlements and impacts of the use of technologies. 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 depreciated over the useful life of the related asset. Reductions to estimated liabilities for assets that are no longer producing are recorded as a credit to impairment, if the asset had been previously impaired, or as a credit to DD&A, if the asset had not been previously impaired. For additional information, see Note 9—Asset Retirement Obligations and Accrued Environmental Costs. Environmental expenditures are expensed or capitalized, depending upon their future economic benefit. 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 through a business combination, which we record on a discounted basis) when environmental assessments or cleanups are probable and the costs can be reasonably estimated. Recoveries of environmental remediation costs from other parties are recorded as assets when their receipt is probable and estimable.
Guarantees	Guarantees —The fair value of a guarantee is determined and recorded as a liability at the time the guarantee is given. The initial liability is subsequently reduced as we are released from exposure under the guarantee. We amortize the guarantee liability over the relevant time period, if one exists, based on the facts and circumstances surrounding each type of guarantee. In cases where the guarantee term is indefinite, we reverse the liability when we have information indicating the liability is essentially relieved or amortize it over an appropriate time period as the fair value of our guarantee exposure declines over time. We amortize the guarantee liability to the related income statement line item based on the nature of the guarantee. When it becomes probable that we will have to perform on a guarantee, we accrue a separate liability if it is reasonably estimable, based on the facts and circumstances at that time. We reverse the fair value liability only when there is no further exposure under the guarantee.
Stock-Based Compensation	Share-Based Compensation —We recognize share-based compensation expense over the shorter of the service period (i.e., the stated period of time required to 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 cumulative translation adjustment considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures. Allowable tax credits are applied currently as reductions of the provision for income taxes. Interest related to unrecognized tax benefits is reflected in interest and debt expense, and penalties related to unrecognized tax benefits are reflected in production and operating expenses. ■ Taxes Collected from Customers and Remitted to Governmental Authorities —Sales and value- added taxes are recorded net. ■ Net Income (Loss) Per Share of Common Stock —Basic net income (loss) per share of common stock is calculated based upon the daily weighted-average number of common shares outstanding during the year. Also, this calculation includes fully vested stock and unit awards that have not yet been issued as common stock, along with an adjustment to net income (loss) for dividend equivalents paid on unvested unit awards that are considered participating securities. Diluted net income per share of common stock includes unvested stock, unit or option awards granted under our compensation plans and vested but unexercised stock options, but only to the extent these instruments dilute net income per share, primarily under the treasury-stock method. Diluted net loss per share, which is calculated the same as basic net loss per share, does not assume conversion or exercise of securities that would have an antidilutive effect. Treasury stock is excluded from the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the participating securities is immaterial.
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 cumulative translation adjustment considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures. Allowable tax credits are applied currently as reductions of the provision for income taxes. Interest related to unrecognized tax benefits is reflected in interest and debt expense, and penalties related to unrecognized tax benefits are reflected in production and operating expenses.
Taxes Collected from Customers and Remitted to Governmental Authorities	Taxes Collected from Customers and Remitted to Governmental Authorities —Sales and value- added taxes are recorded net.
Net Income (Loss) Per Share of Common Stock	Net Income (Loss) Per Share of Common Stock —Basic net income (loss) per share of common stock is calculated based upon the daily weighted-average number of common shares outstanding during the year. Also, this calculation includes fully vested stock and unit awards that have not yet been issued as common stock, along with an adjustment to net income (loss) for dividend equivalents paid on unvested unit awards that are considered 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 only to the extent these instruments dilute net income per share, primarily under the treasury-stock method. Diluted net loss per share, which is calculated the same as basic net loss per share, does not assume conversion or exercise of securities that would have an antidilutive effect. Treasury stock is excluded from the daily weighted-average number of common shares outstanding in both calculations. The earnings per share impact of the participating securities is immaterial.
Shipping and Handling Cost, Policy [Policy Text Block]	Shipping and Handling Costs —We typically incur shipping and handling costs prior to control transferring to the customer and account for these activities as fulfillment costs. Accordingly, we include shipping and handling costs in production and operating expenses for production activities. Transportation costs related to marketing activities are recorded in purchased commodities. Freight costs billed to customers are treated as a component of the transaction price and recorded as a component of revenue when the customer obtains control.
New Accounting Pronouncements, Policy [Policy Text Block]	We adopted the provisions of FASB ASU No. 2016-13, “Measurement of Credit Losses on Financial Instruments,” (ASC Topic 326) and its amendments, beginning January 1, 2020. This ASU, as amended, sets forth the current expected credit loss model, a new forward-looking impairment model for certain financial instruments measured at amortized cost basis based on expected losses rather than incurred losses. This ASU, as amended, which primarily applies to our accounts receivable, also requires credit losses related to available- for-sale debt securities to be recorded through an allowance for credit losses. The adoption of this ASU did not have a material impact to our financial statements. The majority of our receivables are due within 30 days or less. We monitor the credit quality of our counterparties through review of collections, credit ratings, and other analyses. We develop our estimated allowance for credit losses primarily using an aging method and analyses of historical loss rates as well as consideration of current and future conditions that could impact our counterparties’ credit quality and liquidity.

Inventories (Tables)	12 Months Ended
Inventories (Tables)	Dec. 31, 2020
Inventories [Abstract]
Inventories	Note 3—Inventories Inventories at December 31 were: Millions of Dollars 2020 2019 Crude oil and natural gas $ 461 472 Materials and supplies 541 554 $ 1,002 1,026

Investments, Loans and Long-Term Receivables (Tables)	12 Months Ended
Investments, Loans and Long-Term Receivables (Tables)	Dec. 31, 2020
Investments, Loans and Long-Term Receivables and Joint Venture Acquisition Obligation [Abstract]
Components of investments, loans and long-term receivables	Note 5—Investments, Loans and Long-Term Receivables Components of investments, loans and long-term receivables at December 31 were: Millions of Dollars 2020 2019 Equity investments $ 7,596 8,234 Loans and advances—related parties 114 219 Long-term receivables 137 243 Long-term investments in debt securities 217 133 Other investments 67 77 $ 8,131 8,906
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 2020 2019 2018 Revenues $ 7,931 11,310 11,654 Income before income taxes 1,843 3,726 3,660 Net income 1,426 3,085 3,244 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2020 2019 Current assets $ 2,579 3,289 Noncurrent assets 35,257 38,905 Current liabilities 2,110 2,603 Noncurrent liabilities 18,099 22,168

Suspended Wells (Tables)	12 Months Ended
Suspended Wells (Tables)	Dec. 31, 2020
Suspended Wells [Abstract]
Net changes in suspended exploratory well costs	Note 7—Suspended Wells and Exploration Expenses The following table reflects the net changes in suspended exploratory well costs during 2020, 2019 and 2018: Millions of Dollars 2020 2019 2018 Beginning balance at January 1 $ 1,020 856 853 Additions pending the determination of proved reserves 164 239 140 Reclassifications to proved properties (42) (11) (37) Sales of suspended wells (313) (54) (93) Charged to dry hole expense (147) (10) (7) Ending balance at December 31 $ 682 1,020 * 856 *Includes $ 313 million of assets held for sale in Australia at December 31, 2019. For additional details on suspended wells charged to dry hole expense, see the Exploration Expenses section of this Note.
Aging of suspended well cost	The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2020 2019 2018 Exploratory well costs capitalized for a period of one year or less $ 156 206 145 Exploratory well costs capitalized for a period greater than one year 526 814 711 Ending balance $ 682 1,020 * 856 Number of projects with exploratory well costs capitalized for a period greater than one year 22 23 24 *Includes $ 313 million of assets held for sale in Australia at December 31, 2019.
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, 2020: Millions of Dollars Suspended Since Total 2017–2019 2014–2016 2004–2013 NPRA—Alaska (1) 240 190 50 - Surmont—Canada (1) 120 4 31 85 Narwhal Trend—Alaska (1) 52 52 - - PL782S—Norway (1) 22 22 - - WL4-00—Malaysia (1) 17 17 - - NC 98—Libya (2) 13 - 9 4 Other of $10 million or less each (1)(2) 62 26 19 17 Total $ 526 311 109 106 (1)Additional appraisal wells planned. (2)Appraisal drilling complete; costs being incurred to assess development.

Impairments (Tables)	12 Months Ended
Impairments (Tables)	Dec. 31, 2020
Impairment Of Long Lived Assets [Abstract]
Impairment Charges By Segment Before Tax	Note 8—Impairments During 2020, 2019 and 2018, we recognized the following before-tax impairment charges: Millions of Dollars 2020 2019 2018 Alaska $ - - 20 Lower 48 804 402 63 Canada 3 2 9 Europe, Middle East and North Africa 6 1 (79) Asia Pacific - - 14 $ 813 405 27

Asset Retirement Obligations and Accrued Environmental Costs (Tables)	12 Months Ended
	Dec. 31, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations and accrued environmental costs	Note 9—Asset Retirement Obligations and Accrued Environmental Costs Asset retirement obligations and accrued environmental costs at December 31 were: Millions of Dollars 2020 2019 Asset retirement obligations $ 5,573 6,206 Accrued environmental costs 180 171 Total asset retirement obligations and accrued environmental costs 5,753 6,377 Asset retirement obligations and accrued environmental costs due within one year* (323) (1,025) Long-term asset retirement obligations and accrued environmental costs $ 5,430 5,352
Changes in overall asset retirement obligation changed	During 2020 and 2019, our overall ARO changed as follows: Millions of Dollars 2020 2019 Balance at January 1 $ 6,206 7,908 Accretion of discount 248 322 New obligations 262 155 Changes in estimates of existing obligations (307) 50 Spending on existing obligations (116) (229) Property dispositions (771) (1,920) Foreign currency translation 51 (80) Balance at December 31 $ 5,573 6,206

Debt (Tables)	12 Months Ended
Debt (Tables)	Dec. 31, 2020
Debt [Abstract]
Long-term debt	Note 10—Debt Long-term debt at December 31 was: Millions of Dollars 2020 2019 9.125 % Debentures due 2021 $ 123 123 2.4 % Notes due 2022 329 329 7.65 % Debentures due 2023 78 78 3.35 % Notes due 2024 426 426 8.2 % Debentures due 2025 134 134 3.35 % Notes due 2025 199 199 6.875 % Debentures due 2026 67 67 4.95 % Notes due 2026 1,250 1,250 7.8 % Debentures due 2027 203 203 7.375 % Debentures due 2029 92 92 7 % Debentures due 2029 200 200 6.95 % Notes due 2029 1,549 1,549 8.125 % Notes due 2030 390 390 7.2 % Notes due 2031 575 575 7.25 % Notes due 2031 500 500 7.4 % Notes due 2031 500 500 5.9 % Notes due 2032 505 505 4.15 % Notes due 2034 246 246 5.95 % Notes due 2036 500 500 5.951 % Notes due 2037 645 645 5.9 % Notes due 2038 600 600 6.5 % Notes due 2039 2,750 2,750 4.3 % Notes due 2044 750 750 5.95 % Notes due 2046 500 500 7.9 % Debentures due 2047 60 60 Floating rate notes due 2022 at 1.12 % – 2.81 % during 2020 and 2.81 % – 3.58 % during 2019 500 500 Marine Terminal Revenue Refunding Bonds due 2031 at 0.1 % – 7.5 % during 2020 and 1.08 % – 2.45 % during 2019 265 265 Industrial Development Bonds due 2035 at 0.11 % – 7.5 % during 2020 and 1.08 % – 2.45 % during 2019 18 18 Commercial Paper at 0.08 % – 0.23 % during 2020 300 Other 38 17 Debt at face value 14,292 13,971 Finance leases 891 720 Net unamortized premiums, discounts and debt issuance costs 186 204 Total debt 15,369 14,895 Short-term debt (619) (105) Long-term debt $ 14,750 14,790

Derivative and Financial Instruments (Tables)	12 Months Ended
Derivative and Financial Instruments (Tables)	Dec. 31, 2020
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 2020 2019 Assets Prepaid expenses and other current assets $ 229 288 Other assets 26 34 Liabilities Other accruals 202 283 Other liabilities and deferred credits 18 28 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 2020 2019 Assets Prepaid expenses and other current assets $ 2 1 Liabilities Other accruals 16 20 Other liabilities and deferred credits - 8
Income statement location and gain/loss amounts of derivatives	The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars 2020 2019 2018 Sales and other operating revenues $ 19 141 45 Other income (loss) 4 4 7 Purchased commodities 11 (118) (41) 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 2020 2019 2018 Foreign currency transaction (gains) losses $ (40) 16 1
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) 2020 2019 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (20) (5) Basis (10) (23) We had the following net notional position of outstanding foreign currency exchange derivatives: In Millions Notional Currency 2020 2019 Foreign Currency Exchange Derivatives Buy British pound, sell euro GBP - 4 Sell British pound, buy euro GBP 5 - Sell Canadian dollar, buy U.S. dollar CAD 370 1,337
Net carrying amount of held to maturity investments	The following investments are carried on our consolidated balance sheet at cost, plus accrued interest and the table reflects remaining maturities at December 31, 2020 and 2019: Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments Investments and Long- Term Receivables 2020 2019 2020 2019 2020 2019 Cash $ 597 759 Demand Deposits 1,133 1,483 Time Deposits 1 to 90 days 1,225 2,030 2,859 1,395 91 to 180 days 448 465 Within one year 13 - One year through five years 1 - Commercial Paper 1 to 90 days - 413 - 1,069 U.S. Government Obligations 1 to 90 days 23 394 - - $ 2,978 5,079 3,320 2,929 1 -
Debt Securities Carried at Fair Value	The following investments in debt securities classified as available for sale are carried on our consolidated balance sheet at fair value as of December 31, 2020 and 2019: Millions of Dollars Carrying Amount Cash and Cash Equivalents Short-Term Investments Investments and Long- Term Receivables 2020 2019 2020 2019 2020 2019 Major Security Type Corporate Bonds $ - 1 130 59 143 99 Commercial Paper 13 8 155 30 U.S. Government Obligations - - 4 10 13 15 U.S. Government Agency Obligations 17 - Foreign Government Obligations 2 - Asset-backed Securities - - 41 19 $ 13 9 289 99 216 133 Cash and Cash Equivalents and Short-Term Investments have remaining maturities within one year. Investments and Long-Term Receivables have remaining maturities greater than one year through five years.
Schedule of Unrealized Loss on Investments [Table Text Block]	The following table summarizes the amortized cost basis and fair value of investments in debt securities classified as available for sale: Millions of Dollars Amortized Cost Basis Fair Value 2020 2019 2020 2019 Major Security Type Corporate bonds $ 271 159 273 159 Commercial paper 168 38 168 38 U.S. government obligations 17 25 17 25 U.S. government agency obligations 17 - 17 - Foreign government obligations 2 - 2 - Asset-backed securities 41 19 41 19 $ 516 241 518 241

Fair Value Measurement (Tables)	12 Months Ended
Fair Value Measurement (Tables)	Dec. 31, 2020
Fair Value Measurement [Abstract]
Fair value hierarchy for gross financial assets and liabilities	The following table summarizes the fair value hierarchy for gross financial assets and liabilities (i.e., unadjusted where the right of setoff exists for commodity derivatives accounted for at fair value on a recurring basis): Millions of Dollars December 31, 2020 December 31, 2019 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ 1,256 - - 1,256 2,111 - - 2,111 Investments in debt securities 17 501 - 518 25 216 - 241 Commodity derivatives 142 101 12 255 172 114 36 322 Total assets $ 1,415 602 12 2,029 2,308 330 36 2,674 Liabilities Commodity derivatives $ 120 91 9 220 174 115 22 311 Total liabilities $ 120 91 9 220 174 115 22 311
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 setoff exists. Millions of Dollars Amounts Subject to Right of Setoff Gross Amounts Not Gross Net Amounts Subject to Gross Amounts Amounts Cash Net Recognized Right of Setoff Amounts Offset Presented Collateral Amounts December 31, 2020 Assets $ 255 2 253 157 96 10 86 Liabilities 220 1 219 157 62 4 58 December 31, 2019 Assets $ 322 3 319 193 126 4 122 Liabilities 311 4 307 193 114 12 102 At December 31, 2020 and December 31, 2019, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff.
Values of assets, by major category, measured at fair value on a nonrecurring basis	Non-Recurring Fair Value Measurement The following table summarizes the fair value hierarchy by major category and date of remeasurement for assets accounted for at fair value on a non-recurring basis: Millions of Dollars Fair Value Measurements Using Fair Value Level 1 Inputs Level 2 Inputs Level 3 Inputs Before-Tax Loss Year ended December 31, 2020 Net PP&E (held for use) March 31, 2020 $ 65 - - 65 522 December 31, 2020 268 - - 268 287 Year ended December 31, 2019 Net PP&E (held for sale) November 30, 2019 $ 194 194 - - 351 December 31, 2019 166 166 - - 28 Equity Method Investments March 31, 2019 171 171 - - 60 May 31, 2019 30 - 30 - 95
Fair value measurement inputs and valuation techniques	The range and arithmetic average of significant unobservable inputs used in the Level 3 fair value measurements for significant assets were as follows: Fair Value (Millions of Dollars) Valuation Technique Unobservable Inputs Range (Arithmetic Average) March 31, 2020 Wind River Basin $ 65 Discounted cash flow Natural gas production (MMCFD) 8.4 - 55.2 ( 22.9 ) Natural gas price outlook* ($/MMBTU) $ 2.67 - $ 9.17 ($ 5.68 ) Discount rate** 7.9 % - 9.1 % ( 8.3 %) Henry Hub natural gas price outlook based on a combination of external pricing service companies' outlooks for years 2022-2034; future prices escalated at 2.2 % annually after year 2034. Determined as the weighted average cost of capital of a group of peer companies, adjusted for risks where appropriate. Fair Value (Millions of Dollars) Valuation Technique Unobservable Inputs Range (Arithmetic Average) December 31, 2020 Central Basin Platform $ 244 Discounted cash flow Commodity production (MBOED) 0.5 - 12.7 ( 3.4 ) Commodity price outlook ($/BOE) $ 37.35 - $ 115.29 ($ 73.80 ) Discount rate** 6.8 % - 7.7 % ( 7.4 %) Commodity price outlook based on a combination of external pricing service companies' and our internal outlook for years 2023-2050; future prices escalated at 2.0% annually after year 2050. *Determined as the weighted average cost of capital of a group of peer companies, adjusted for risks where appropriate.
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 2020 2019 2020 2019 Financial assets Investment in Cenovus Energy $ 1,256 2,111 1,256 2,111 Commodity derivatives 88 125 88 125 Investments in debt securities 518 241 518 241 Loans and advances—related parties 220 339 220 339 Financial liabilities Total debt, excluding finance leases 14,478 14,175 19,106 18,108 Commodity derivatives 59 106 59 106

Equity (Tables)	12 Months Ended
Equity (Tables)	Dec. 31, 2020
Equity [Abstract]
Changes in shares of common stock	Note 15—Equity Common Stock The changes in our shares of common stock, as categorized in the equity section of the balance sheet, were: Shares 2020 2019 2018 Issued Beginning of year 1,795,652,203 1,791,637,434 1,785,419,175 Distributed under benefit plans 3,192,064 4,014,769 6,218,259 End of year 1,798,844,267 1,795,652,203 1,791,637,434 Held in Treasury Beginning of year 710,783,814 653,288,213 608,312,034 Repurchase of common stock 20,018,275 57,495,601 44,976,179 End of year 730,802,089 710,783,814 653,288,213

Non Mineral Leases (Tables)	12 Months Ended
Non Mineral Leases (Tables)	Dec. 31, 2020
Leases [Abstract]
Lease, Assets And Liabilities [Table Text Block]	The following table summarizes the right-of-use assets and lease liabilities for both the operating and finance leases on our consolidated balance sheet as of December 31: Millions of Dollars 2020 2019 Operating Leases Finance Leases Operating Leases Finance Leases Right-of-Use Assets Properties, plants and equipment Gross $ 1,375 1,039 Accumulated DD&A (721) (649) Net PP&E * 654 390 Prepaid expenses and other current assets $ - 40 Other assets 783 896 Lease Liabilities Short-term debt $ 168 87 Other accruals 226 347 Long-term debt * 723 633 Other liabilities and deferred credits 559 585 Total lease liabilities $ 785 891 932 720 * Includes proportionately consolidated finance lease assets of $ 258 million at December 31, 2020 and $ 335 million at December 31, 2019. Includes proportionately consolidated finance lease liabilities of $ 97 million at December 31, 2020 and $ 56 million at December 31, 2019. * Includes proportionately consolidated finance lease liabilities of $ 522 million at December 31, 2020 and $ 579 million at December 31, 2019.
Lease, Cost [Table Text Block]	The following table summarizes our lease costs for 2020 and 2019: Millions of Dollars 2020 2019 Lease Cost * Operating lease cost $ 321 341 Finance lease cost Amortization of right-of-use assets 163 99 Interest on lease liabilities 34 37 Short-term lease cost 42 77 Total lease cost * $ 560 554 * The amounts presented in the table above have not been adjusted to reflect amounts recovered or reimbursed from oil and gas coventurers. Short-term leases are not recorded on our consolidated balance sheet. * Variable lease cost and sublease income are immaterial for the periods presented and therefore are not included in the table above The following table summarizes the lease terms and discount rates as of December 31: 2020 2019 Lease Term and Discount Rate Weighted-average term (years) Operating leases 6.11 5.19 Finance leases 7.12 8.70 Weighted-average discount rate (percent) Operating leases 2.78 3.10 Finance leases 4.27 5.53 The following table summarizes other lease information for 2020 and 2019: Millions of Dollars 2020 2019 Other Information * Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 232 203 Operating cash flows from finance leases 11 27 Financing cash flows from finance leases 255 81 Right-of-use assets obtained in exchange for operating lease liabilities $ 250 499 Right-of-use assets obtained in exchange for finance lease liabilities 426 26 *The amounts presented in the table above have not been adjusted to reflect amounts recovered or reimbursed from oil and gas coventurers. In addition, pursuant to other applicable accounting guidance, lease payments made in connection with preparing another asset for its intended use are reported in the "Cash Flows From Investing Activities" section of our consolidated statement of cash flows.
Lessee, Operating Lease, Liability, Maturity [Table Text Block]	The following table summarizes future lease payments for operating and finance leases at December 31, 2020: Millions of Dollars Operating Leases Finance Leases Maturity of Lease Liabilities 2021 $ 245 213 2022 155 162 2023 116 148 2024 94 113 2025 55 87 Remaining years 200 320 Total * 865 1,043 Less: portion representing imputed interest (80) (152) Total lease liabilities $ 785 891 *Future lease payments for operating and finance leases commencing on or after January 1, 2019, also include payments related to non-lease components in accordance with our election to adopt the optional practical expedient not to separate lease components apart from non-lease components for accounting purposes. In addition, future payments related to operating and finance leases proportionately consolidated by the company have been included in the table on a proportionate basis consistent with our respective ownership interest in the underlying investee company or oil and gas venture.
Finance Lease, Liability, Maturity [Table Text Block]	The following table summarizes future lease payments for operating and finance leases at December 31, 2020: Millions of Dollars Operating Leases Finance Leases Maturity of Lease Liabilities 2021 $ 245 213 2022 155 162 2023 116 148 2024 94 113 2025 55 87 Remaining years 200 320 Total * 865 1,043 Less: portion representing imputed interest (80) (152) Total lease liabilities $ 785 891 *Future lease payments for operating and finance leases commencing on or after January 1, 2019, also include payments related to non-lease components in accordance with our election to adopt the optional practical expedient not to separate lease components apart from non-lease components for accounting purposes. In addition, future payments related to operating and finance leases proportionately consolidated by the company have been included in the table on a proportionate basis consistent with our respective ownership interest in the underlying investee company or oil and gas venture.
Schedule of Rent Expense [Table Text Block]	For the year ended December 31, 2018 operating lease rental expense pursuant to ASC Topic 840 was: Millions of Dollars Total rentals $ 253 Less: sublease rentals (16) $ 237

Employee Benefit Plans (Tables)	12 Months Ended
Employee Benefit Plans (Tables)	Dec. 31, 2020
Compensation And Retirement Disclosure [Abstract]
Pension and Postretirement Plans	An analysis of the projected benefit obligations for our pension plans and accumulated benefit obligations for our postretirement health and life insurance plans follows: Millions of Dollars Pension Benefits Other Benefits 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 2,319 3,880 2,136 3,438 216 218 Service cost 85 54 79 69 2 1 Interest cost 66 85 79 97 6 8 Plan participant contributions - 1 - 2 18 20 Plan amendments - 2 - - (30) - Actuarial loss 319 398 278 387 7 27 Benefits paid (241) (151) (253) (147) (49) (59) Curtailment - 2 - (69) - - Recognition of termination benefits - 3 - 1 - - Foreign currency exchange rate change - 129 - 102 - 1 Benefit obligation at December 31 * $ 2,548 4,403 2,319 3,880 170 216 *Accumulated benefit obligation portion of above at December 31: $ 2,359 4,095 2,161 3,594 Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 1,591 4,306 1,336 3,358 - - Actual return on plan assets 321 416 273 529 - - Company contributions 99 60 235 464 31 39 Plan participant contributions - 1 - 2 18 20 Benefits paid (241) (151) (253) (147) (49) (59) Foreign currency exchange rate change - 161 - 100 - - Fair value of plan assets at December 31 $ 1,770 4,793 1,591 4,306 - - Funded Status $ (778) 390 (728) 426 (170) (216)
Defined Benefit Plan, Plan with Projected and Accumulated Benefit Obligation in Excess of Plan Assets [Table Text Block]	The following tables set forth information related to the Company’s pension plans with projected and accumulated benefit obligations in excess of the fair value of the plans’ assets as of December 31, 2020 and 2019: Millions of Dollars Pension Benefits 2020 2019 U.S. Int’l. U.S. Int’l. Pension Plans with Projected Benefit Obligation in Excess of Plan Assets Projected benefit obligation $ 2,548 391 2,319 355 Fair value of plan assets 1,770 35 1,591 44 Pension Plans with Accumulated Benefit Obligation in Excess of Plan Assets Accumulated benefit obligation $ 2,359 338 2,161 299 Fair value of plan assets 1,770 35 1,591 44
Amounts Recognized in the Consolidated Balance Sheet	Millions of Dollars Pension Benefits Other Benefits 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 746 - 765 - - Current liabilities (56) (11) (21) (6) (39) (42) Noncurrent liabilities (722) (345) (707) (333) (131) (174) Total recognized $ (778) 390 (728) 426 (170) (216) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 2.30 % 1.80 3.25 2.35 2.15 3.10 Rate of compensation increase 4.00 3.10 4.00 3.35 Interest crediting rate for applicable benefits 2.10 - 4.10 - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.05 % 2.35 3.95 2.90 3.10 4.05 Expected return on plan assets 5.80 3.60 5.80 4.10 Rate of compensation increase 4.00 3.35 4.00 3.65 Interest crediting rate for applicable benefits 4.10 - 4.35 -
Weighted-Average Assumptions Used to Determine Benefit Obligations and Net Periodic Benefit Cost	Millions of Dollars Pension Benefits Other Benefits 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ - 746 - 765 - - Current liabilities (56) (11) (21) (6) (39) (42) Noncurrent liabilities (722) (345) (707) (333) (131) (174) Total recognized $ (778) 390 (728) 426 (170) (216) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 2.30 % 1.80 3.25 2.35 2.15 3.10 Rate of compensation increase 4.00 3.10 4.00 3.35 Interest crediting rate for applicable benefits 2.10 - 4.10 - Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.05 % 2.35 3.95 2.90 3.10 4.05 Expected return on plan assets 5.80 3.60 5.80 4.10 Rate of compensation increase 4.00 3.35 4.00 3.65 Interest crediting rate for applicable benefits 4.10 - 4.35 -
Before tax amounts unrecognized in net periodic postretirement benefit 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 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial loss $ 467 326 479 227 14 8 Unrecognized prior service credit - - - (2) (182) (183)
Sources of change in other comprehensive income	Millions of Dollars Pension Benefits Other Benefits 2020 2019 2020 2019 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ (83) (120) (79) 51 (7) (27) Amortization of actuarial (gain) loss included in income (loss)* 95 21 116 32 1 (2) Net change during the period $ 12 (99) 37 83 (6) (29) Prior service credit (cost) arising during the period $ - (1) - - 30 - Amortization of prior service cost (credit) included in income (loss) - (1) - (2) (31) (33) Net change during the period $ - (2) - (2) (1) (33) *Includes settlement (gains) losses recognized in 2020 and 2019.
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 2020 2019 2018 2020 2019 2018 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 85 54 79 69 83 81 2 1 1 Interest cost 66 85 79 97 99 107 6 8 8 Expected return on plan assets (85) (145) (74) (138) (114) (155) - - - Amortization of prior service credit - (1) - (2) - (5) (31) (33) (35) Recognized net actuarial loss (gain) 51 22 54 32 53 31 1 (2) (1) Settlements loss (gain) 44 (1) 62 - 196 - - - - Net periodic benefit cost $ 161 14 200 58 317 59 (22) (26) (27)
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 2020 Equity securities U.S. $ - 3 5 8 - - - - International 99 - - 99 - - - - Mutual funds 72 - - 72 235 734 - 969 Debt securities Corporate - 1 - 1 - - - - Mutual funds - - - - 455 - - 455 Cash and cash equivalents - - - - 74 - - 74 Derivatives - - - - 6 - - 6 Real estate - - - - - - 142 142 Total in fair value hierarchy $ 171 4 5 180 770 734 142 1,646 Investments measured at net asset value* Equity securities Common/collective trusts $ 678 2,962 Debt securities Common/collective trusts 730 67 Cash and cash equivalents 8 - Real estate 79 112 Total** $ 171 4 5 1,675 770 734 142 4,787 In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets. Excludes the participating interest in the insurance annuity contract with a net asset of $ 94 million and net receivables related to security transactions of $ 7 million. The fair values of our pension plan assets at December 31, by asset class were as follows: Millions of Dollars U.S. International Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total 2019 Equity securities U.S. $ 94 - 7 101 435 - - 435 International 98 - - 98 266 - - 266 Mutual funds 93 - - 93 245 267 - 512 Debt securities Government - - - - 1,412 - - 1,412 Corporate - 2 - 2 - - - - Mutual funds - - - - 392 - - 392 Cash and cash equivalents - - - - 98 - - 98 Derivatives - - - - 11 - - 11 Real estate - - - - - - 132 132 Total in fair value hierarchy $ 285 2 7 294 2,859 267 132 3,258 Investments measured at net asset value Equity securities Common/collective trusts $ 457 167 Debt securities Common/collective trusts 637 760 Cash and cash equivalents 25 - Real estate 83 112 Total** $ 285 2 7 1,496 2,859 267 132 4,297 In accordance with FASB ASC Topic 715, “Compensation—Retirement Benefits,” certain investments that are to be measured at fair value using the net asset value per share (or its equivalent) practical expedient have not been classified in the fair value hierarchy. The fair value amounts presented in this table are intended to permit reconciliation of the fair value hierarchy to the amounts presented in the Change in Fair Value of Plan Assets. *Excludes the participating interest in the insurance annuity contract with a net asset of $ 95 million and net receivables related to security transactions of $ 9 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. 2021 $ 532 147 25 2022 289 151 21 2023 248 156 18 2024 232 162 16 2025 215 166 14 2026–2030 845 897 53
Share-based compensation expense recognized in income and the associated tax benefit	Compensation Expense —Total share-based compensation expense recognized in net income (loss) and the associated tax benefit for the years ended December 31 were as follows: Millions of Dollars 2020 2019 2018 Compensation cost $ 159 274 265 Tax benefit 40 71 64
Summary of stock option activity	The following summarizes our stock option activity for the year ended December 31, 2020: Millions of Dollars Weighted-Average Aggregate Options Exercise Price Intrinsic Value Outstanding at December 31, 2019 18,040,197 $ 54.11 $ 206 Exercised (1,111,805) 38.80 23 Forfeited (5,867) 49.76 Expired or cancelled - Outstanding at December 31, 2020 16,922,525 $ 55.12 $ 22 Vested at December 31, 2020 16,922,525 $ 55.12 $ 22 Exercisable at December 31, 2020 16,922,525 $ 55.12 $ 22
Summary of restricted stock unit activity	The following summarizes our stock-settled stock unit activity for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 6,223,046 $ 55.99 Granted 2,890,840 57.40 Forfeited (127,181) 55.84 Issued (2,554,720) 50.16 $ 143 Outstanding at December 31, 2020 6,431,985 $ 58.94 Not Vested at December 31, 2020 4,230,413 59.01 The following summarizes our cash-settled stock unit activity for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 596,991 $ 64.54 Granted 24,437 41.59 Forfeited (5,622) 40.01 Issued (1,191) 40.20 $ - Outstanding at December 31, 2020 614,615 $ 39.95 Not Vested at December 31, 2020 121,696 39.95
Summary of Performance Share Program activity	The following summarizes our stock-settled Performance Share Program activity for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 2,024,824 $ 50.55 Granted 26,244 58.61 Forfeited - Issued (314,340) 51.15 $ 13 Outstanding at December 31, 2020 1,736,728 $ 50.56 Not Vested at December 31, 2020 3,191 $ 48.61 The following summarizes our cash-settled Performance Share Program activity for the year ended December 31, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 609,274 $ 64.54 Granted 1,491,098 58.61 Forfeited - Settled (1,975,843) 58.54 $ 116 Outstanding at December 31, 2020 124,529 $ 39.95
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, 2020: Weighted-Average Millions of Dollars Stock Units Grant Date Fair Value Total Fair Value Outstanding at December 31, 2019 991,908 $ 47.24 Granted 77,824 51.46 Cancelled (1,336) 23.09 Issued (98,297) 45.57 $ 6 Outstanding at December 31, 2020 970,099 $ 47.78
Severance accrual	The following table summarizes our severance accrual activity for 2020, 2019 and 2018: Millions of Dollars 2020 2019 2018 Balance at January 1 $ 23 48 53 Accruals 14 (1) 70 Benefit payments (13) (24) (73) Foreign currency translation adjustments - - (2) Balance at December 31 $ 24 23 48

Income Taxes (Tables)	12 Months Ended
Income Taxes (Tables)	Dec. 31, 2020
Income Taxes [Abstract]
Income taxes charged to income (loss)	Note 18—Income Taxes Components of income tax expense (benefit) were: Millions of Dollars 2020 2019 2018 Income Taxes Federal Current $ 3 18 4 Deferred (625) (113) 545 Foreign Current 350 2,545 3,273 Deferred (70) (323) (166) State and local Current (4) 148 108 Deferred (139) (8) (96) $ (485) 2,267 3,668
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 2020 2019 Deferred Tax Liabilities PP&E and intangibles $ 7,744 8,660 Inventory 64 35 Other 242 234 Total deferred tax liabilities 8,050 8,929 Deferred Tax Assets Benefit plan accruals 540 542 Asset retirement obligations and accrued environmental costs 2,262 2,339 Investments in joint ventures 1,653 1,722 Other financial accruals and deferrals 907 777 Loss and credit carryforwards 8,904 8,968 Other 365 345 Total deferred tax assets 14,631 14,693 Less: valuation allowance (9,965) (10,214) Total deferred tax assets net of valuation allowance 4,666 4,479 Net deferred tax liabilities $ 3,384 4,450
Reconciliation of deferred tax asset valuation allowance	The following table shows a reconciliation of the beginning and ending deferred tax asset valuation allowance for for 2020, 2019 and 2018: Millions of Dollars 2020 2019 2018 Balance at January 1 $ 10,214 3,040 1,254 Charged to expense (benefit) 460 (225) (26) Other* (709) 7,399 1,812 Balance at December 31 $ 9,965 10,214 3,040 *Represents changes due to originating deferred tax asset that have no impact to our effective tax rate, acquisitions/dispositions/revisions and the effect of translating foreign financial statements. Certain items in the prior year have been reclassed to conform with the current year presentation, with no impacts to beginning and ending balances.
Reconciliation of the beginning and ending unrecognized tax benefits	The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2020, 2019 and 2018: Millions of Dollars 2020 2019 2018 Balance at January 1 $ 1,177 1,081 882 Additions based on tax positions related to the current year 6 9 268 Additions for tax positions of prior years 67 120 43 Reductions for tax positions of prior years (34) (22) (73) Settlements (9) (9) (35) Lapse of statute (1) (2) (4) Balance at December 31 $ 1,206 1,177 1,081
Schedule of Effective Income Tax Rate Reconciliation [Table Text Block]	The amounts of U.S. and foreign income (loss) before income taxes, with a reconciliation of tax at the federal statutory rate to the provision for income taxes, were: Millions of Dollars Percent of Pre-Tax Income (Loss) 2020 2019 2018 2020 2019 2018 Income (loss) before income taxes United States $ (3,587) 4,704 2,867 114.2 % 49.4 28.7 Foreign 447 4,820 7,106 (14.2) 50.6 71.3 $ (3,140) 9,524 9,973 100.0 % 100.0 100.0 Federal statutory income tax $ (659) 2,000 2,095 21.0 % 21.0 21.0 Non-U.S. effective tax rates 194 1,399 1,766 (6.2) 14.7 17.7 Tax Legislation - - (10) - - (0.1) Australia disposition (349) - - 11.1 - - U.K. disposition - (732) (150) - (7.7) (1.5) Recovery of outside basis (22) (77) (21) 0.7 (0.8) (0.2) Adjustment to tax reserves 18 9 (4) (0.6) 0.1 - Adjustment to valuation allowance 460 (225) (26) (14.6) (2.4) (0.3) State income tax (112) 123 135 3.6 1.3 1.4 Malaysia Deepwater Incentive - (164) - - (1.7) - Enhanced oil recovery credit (6) (27) (99) 0.2 (0.3) (1.0) Other (9) (39) (18) 0.3 (0.4) (0.2) $ (485) 2,267 3,668 15.5 % 23.8 36.8

Accumulated Other Comprehensive Income (Tables)	12 Months Ended
Accumulated Other Comprehensive Income (Tables)	Dec. 31, 2020
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated other comprehensive income in the equity section of the balance sheet included	Note 19—Accumulated Other Comprehensive Loss Accumulated other comprehensive loss in the equity section of the balance sheet included: Millions of Dollars Defined Benefit Plans Net Unrealized Loss on Securities Foreign Currency Translation Accumulated Other Comprehensive Loss December 31, 2017 $ (400) (58) (5,060) (5,518) Other comprehensive income (loss) 39 - (642) (603) Cumulative effect of adopting ASU No. 2016-01* - 58 - 58 December 31, 2018 (361) - (5,702) (6,063) Other comprehensive income 51 - 695 746 Cumulative effect of adopting ASU No. 2018-02** (40) - - (40) December 31, 2019 (350) - (5,007) (5,357) Other comprehensive income (loss) (75) 2 212 139 December 31, 2020 $ (425) 2 (4,795) (5,218) We adopted ASU No. 2016-01, "Recognition and Measurement of Financial Assets and Liabilities," beginning January 1, 2018. *We adopted ASU No. 2018-02, "Reclassification of Certain Tax Effects from Accumulated Other Comprehensive Income," beginning January 1, 2019. During 2019, we recognized $ 483 million of foreign currency translation adjustments related to the completion of our sale of two ConocoPhillips U.K. subsidiaries. For additional information related to this disposition, see Note 4—Asset Acquisitions and Dispositions.
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 2020 2019 Defined Benefit Plans $ 72 88 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 13 23 See Note 17—Employee Benefit Plans, for additional information.

Cash Flow Information (Tables)	12 Months Ended
Cash Flow Information (Tables)	Dec. 31, 2020
Cash Flow Information [Abstract]
Cash Flow Information	Note 20—Cash Flow Information Millions of Dollars 2020 2019 2018 Noncash Investing Activities Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations $ (116) 205 395 Increase (decrease) in assets and liabilities acquired in a nonmonetary exchange* Accounts receivable - - (44) Inventories - - 42 Investments and long-term receivables - - 15 PP&E - - 1,907 Other long-term assets - - (9) Accounts payable - - 7 Accrued income and other taxes - - 40 Cash Payments Interest $ 785 810 772 Income taxes 905 2,905 2,976 Net Sales (Purchases) of Investments Short-term investments purchased $ (12,435) (4,902) (1,953) Short-term investments sold 12,015 2,138 3,573 Investments and long-term receivables purchased (325) (146) - Investments and long-term receivables sold 87 - - $ (658) (2,910) 1,620 *See Note 4—Asset Acquisitions and Dispositions.

Other Financial Information (Tables)	12 Months Ended
Other Financial Information (Tables)	Dec. 31, 2020
Other Financial Information [Abstract]
Other Financial Information	Note 21—Other Financial Information Millions of Dollars 2020 2019 2018 Interest and Debt Expense Incurred Debt $ 788 799 838 Other 73 36 67 861 835 905 Capitalized (55) (57) (170) Expensed $ 806 778 735 Other Income (Loss) Interest income $ 100 166 97 Unrealized gains (losses) on Cenovus Energy common shares* (855) 649 (437) Other, net 246 543 513 $ (509) 1,358 173 *See Note 6—Investment in Cenovus Energy, for additional information. Research and Development Expenditures —expensed $ 75 82 78 Shipping and Handling Costs $ 857 1,008 1,075 Foreign Currency Transaction (Gains) Losses —after-tax Alaska $ - - - Lower 48 - - - Canada (7) 5 (11) Europe, Middle East and North Africa (15) - (26) Asia Pacific (11) 31 3 Other International 2 1 - Corporate and Other (31) 21 21 $ (62) 58 (13)
Property, Plant And Equipment [Table Text Block]	Millions of Dollars 2020 2019 Properties, Plants and Equipment Proved properties $ 94,312 88,284 * Unproved properties 4,141 3,980 * Other 3,653 5,482 Gross properties, plants and equipment 102,106 97,746 Less: Accumulated depreciation, depletion and amortization (62,213) (55,477) * Net properties, plants and equipment $ 39,893 42,269 *Excludes assets classified as held for sale at December 31, 2019. See Note 4 — Asset Acquisitions and Dispositions, for additional information.

Related Party Transactions (Tables)	12 Months Ended
Related Party Transactions (Tables)	Dec. 31, 2020
Related Party Transactions [Abstract]
Significant transactions with related parties	Note 22—Related Party Transactions Our related parties primarily include equity method investments and certain trusts for the benefit of employees. For disclosures on trusts for the benefit of employees, see Note 17 — Employee Benefit Plans. Significant transactions with our equity affiliates were: Millions of Dollars 2020 2019 2018 Operating revenues and other income $ 79 89 98 Purchases - 38 98 Operating expenses and selling, general and administrative expenses 63 65 60 Net interest income* (5) (13) (14) *We paid interest to, or received interest from, various affiliates. See Note 5—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.

Sales and Other Operating Revenues (Tables)	12 Months Ended
Sales and Other Operating Revenues (Tables)	Dec. 31, 2020
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue [Table Text Block]	Millions of Dollars 2020 2019 2018 Revenue from contracts with customers $ 13,662 26,106 28,098 Revenue from contracts outside the scope of ASC Topic 606 Physical contracts meeting the definition of a derivative 5,177 6,558 8,218 Financial derivative contracts (55) (97) 101 Consolidated sales and other operating revenues $ 18,784 32,567 36,417 Millions of Dollars 2020 2019 2018 Revenue from Outside the Scope of ASC Topic 606 by Segment Lower 48 $ 3,966 4,989 6,358 Canada 727 691 629 Europe, Middle East and North Africa 484 878 1,231 Physical contracts meeting the definition of a derivative $ 5,177 6,558 8,218 Millions of Dollars 2020 2019 2018 Revenue from Outside the Scope of ASC Topic 606 by Product Crude oil $ 395 804 1,112 Natural gas 4,339 5,313 6,734 Other 443 441 372 Physical contracts meeting the definition of a derivative $ 5,177 6,558 8,218
Contract with Customer, Asset and Liability [Table Text Block]	Millions of Dollars Contract Liabilities At December 31, 2019 $ 80 Contractual payments received 17 At December 31, 2020 $ 97 Amounts Recognized in the Consolidated Balance Sheet at December 31, 2020 Current liabilities $ 56 Noncurrent liabilities 41 $ 97

Segment Disclosures and Related Information (Tables)	12 Months Ended
Segment Disclosures and Related Information (Tables)	Dec. 31, 2020
Segment Disclosures and Related Information [Abstract]
Sales and Other Operating Revenues	Analysis of Results by Operating Segment Millions of Dollars 2020 2019 2018 Sales and Other Operating Revenues Alaska $ 3,408 5,483 5,740 Intersegment eliminations (11) - - Alaska 3,397 5,483 5,740 Lower 48 9,872 15,514 17,029 Intersegment eliminations (51) (46) (40) Lower 48 9,821 15,468 16,989 Canada 1,666 2,910 3,184 Intersegment eliminations (405) (1,141) (1,160) Canada 1,261 1,769 2,024 Europe, Middle East and North Africa 1,919 5,101 6,635 Intersegment eliminations (2) - - Europe, Middle East and North Africa 1,917 5,101 6,635 Asia Pacific 2,363 4,525 4,861 Other International 7 - - Corporate and Other 18 221 168 Consolidated sales and other operating revenues $ 18,784 32,567 36,417 The market for our products is large and diverse, therefore, our sales and other operating revenues are not dependent upon any single customer.
Depreciation, Depletion, Amortization and Impairments	Millions of Dollars 2020 2019 2018 Depreciation, Depletion, Amortization and Impairments Alaska $ 996 805 760 Lower 48 3,358 3,224 2,370 Canada 342 232 324 Europe, Middle East and North Africa 775 887 1,041 Asia Pacific 809 1,285 1,382 Other International - - - Corporate and Other 54 62 106 Consolidated depreciation, depletion, amortization and impairments $ 6,334 6,495 5,983
Equity in Earnings of Affiliates	Equity in Earnings of Affiliates Alaska $ (7) 7 6 Lower 48 (11) (159) 1 Canada - - - Europe, Middle East and North Africa 311 470 744 Asia Pacific 137 461 323 Other International 2 - - Corporate and Other - - - Consolidated equity in earnings of affiliates $ 432 779 1,074
Income Taxes	Income Tax Provision (Benefit) Alaska $ (256) 472 376 Lower 48 (378) 137 474 Canada (185) (43) (96) Europe, Middle East and North Africa 136 1,425 2,259 Asia Pacific 294 501 728 Other International (20) 8 30 Corporate and Other (76) (233) (103) Consolidated income tax provision (benefit) $ (485) 2,267 3,668
Net Income Attributable to ConocoPhillips	Net Income (Loss) Attributable to ConocoPhillips Alaska $ (719) 1,520 1,814 Lower 48 (1,122) 436 1,747 Canada (326) 279 63 Europe, Middle East and North Africa 448 3,170 2,594 Asia Pacific 962 1,483 1,342 Other International (64) 263 364 Corporate and Other (1,880) 38 (1,667) Consolidated net income (loss) attributable to ConocoPhillips $ (2,701) 7,189 6,257
Investments In and Advances To Affiliates	Millions of Dollars 2020 2019 2018 Investments in and Advances to Affiliates Alaska $ 62 83 86 Lower 48 25 35 378 Canada - - - Europe, Middle East and North Africa 918 1,070 1,311 Asia Pacific 6,705 7,265 7,565 Other International - - - Corporate and Other - - - Consolidated investments in and advances to affiliates $ 7,710 8,453 9,340
Total Assets	Total Assets Alaska $ 14,623 15,453 14,648 Lower 48 11,932 14,425 14,888 Canada 6,863 6,350 5,748 Europe, Middle East and North Africa 8,756 9,269 11,276 Asia Pacific 11,231 13,568 14,758 Other International 226 285 89 Corporate and Other 8,987 11,164 8,573 Consolidated total assets $ 62,618 70,514 69,980
Capital Expenditures and Investments	Capital Expenditures and Investments Alaska $ 1,038 1,513 1,298 Lower 48 1,881 3,394 3,184 Canada 651 368 477 Europe, Middle East and North Africa 600 708 877 Asia Pacific 384 584 718 Other International 121 8 6 Corporate and Other 40 61 190 Consolidated capital expenditures and investments $ 4,715 6,636 6,750
Interest Income and Expense	Interest Income and Expense Interest income Alaska $ - - - Lower 48 - - - Canada - - - Europe, Middle East and North Africa 5 11 12 Asia Pacific 7 6 5 Other International - - - Corporate and Other 88 149 80 Interest and debt expense Corporate and Other $ 806 778 735
Geographic Information	Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2020 2019 2018 2020 2019 2018 United States $ 13,230 21,159 22,740 24,034 26,566 26,838 Australia and Timor-Leste 605 1,647 1,798 6,676 7,228 9,301 Canada 1,261 1,769 2,024 6,385 5,769 5,333 China 460 772 836 1,491 1,447 1,380 Indonesia 689 875 886 464 605 669 Libya 155 1,103 1,142 670 668 679 Malaysia 610 1,230 1,346 1,501 1,871 2,327 Norway 1,426 2,349 2,886 5,294 5,258 5,582 United Kingdom 336 1,649 2,606 1 2 1,583 Other foreign countries 12 14 153 1,087 1,308 1,346 Worldwide consolidated $ 18,784 32,567 36,417 47,603 50,722 55,038
Sales and Other Operating Revenues by Product	Sales and Other Operating Revenues by Product Crude oil $ 9,736 18,482 19,571 Natural gas 6,427 8,715 10,720 Natural gas liquids 528 814 1,114 Other* 2,093 4,556 5,012 Consolidated sales and other operating revenues by product $ 18,784 32,567 36,417 *Includes LNG and bitumen.

Acquisition of Cohcho Resources Inc. (Tables)	12 Months Ended
Acquisition of Cohcho Resources Inc. (Tables)	Dec. 31, 2020
Business Combinations [Abstract]
Fair Value of Total Consideration Transferred	Note 25—Acquisition of Concho Resources Inc. On October 18, 2020 , we entered into a definitive agreement to acquire Concho in an all-stock transaction. The transaction closed on January 15, 2021 and as defined under the terms of the transaction agreement, each share of Concho common stock was exchanged at a fixed ratio of 1.46 for shares of ConocoPhillips common stock, for total consideration of $ 13.1 billion. This resulted in issuance of 286 million shares, representing approximately 21 percent of the outstanding shares of ConocoPhillips common stock upon completion of the transaction. We also assumed Concho’s outstanding debt of $ 3.9 billion in aggregate principal amount, recorded at fair value of $ 4.7 billion on the transaction closing date. On December 7, 2020, we launched a debt exchange offer which settled on February 8, 2021, for 98 percent of Concho’s historical notes. The historical notes issued by Concho were exchanged for new notes issued by ConocoPhillips, which are fully and unconditionally guaranteed by ConocoPhillips Company. For further discussion about the debt exchange, see Note 10 – Debt. As of the acquisition date, January 15, 2021, the fair value of consideration transferred is summarized below: Total Consideration Number of shares of Concho common stock issued and outstanding (in thousands)* 194,243 Number of shares of Concho stock awards outstanding (in thousands)* 1,599 Number of shares exchanged 195,842 Exchange ratio 1.46 Additional shares of ConocoPhillips common stock issued as consideration (in thousands) 285,929 Average price per share of ConocoPhillips common stock** $ 45.9025 Total Consideration (Millions) $ 13,125 Outstanding as of January 15, 2021. *Based on the ConocoPhillips average stock price on January 15, 2021. The transaction will be accounted for as a business combination under the acquisition method of accounting. The total purchase price will be allocated to identifiable assets acquired and the liabilities assumed based on their fair values as of the closing date. We are currently in the process of finalizing the initial accounting for this transaction and provisional fair value measurements will be made in the first quarter of 2021. We may adjust the measurements in subsequent periods, up to one year from the acquisition date as we identify additional information to complete the necessary analysis.

Accounting Policies - Textuals (Details)	12 Months Ended
Accounting Policies - Textuals (Details)	Dec. 31, 2020
Accounting Policies [Abstract]
Number of operating segments	6
Revenue, Performance Obligation, Description of Payment Terms	Payment is typically due within 30 days or less.

Change in Accounting Principles (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating Lease, Liability	$ 785
Accumulated Other Comprehensive Income (Loss), Net of Tax	(5,218)	$ (5,357)	$ (6,063)	$ (5,518)
Retained Earnings (Accumulated Deficit)	35,213	39,742
Scenario Previously Reported Member [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
Operating Lease, Liability	$ 785	$ 932
Accounting Standards Update 2016-13 [Member]
New Accounting Pronouncements or Change in Accounting Principle [Line Items]
New Accounting Pronouncement Or Change In Accounting Principle Description	We adopted the provisions of FASB ASU No. 2016-13, “Measurement of Credit Losses on Financial Instruments,” (ASC Topic 326) and its amendments, beginning January 1, 2020. This ASU, as amended, sets forth the current expected credit loss model, a new forward-looking impairment model for certain financial instruments measured at amortized cost basis based on expected losses rather than incurred losses. This ASU, as amended, which primarily applies to our accounts receivable, also requires credit losses related to available-for-sale debt securities to be recorded through an allowance for credit losses. The adoption of this ASU did not have a material impact to our financial statements. The majority of our receivables are due within 30 days or less. We monitor the credit quality of our counterparties through review of collections, credit ratings, and other analyses. We develop our estimated allowance for credit losses primarily using an aging method and analyses of historical loss rates as well as consideration of current and future conditions that could impact our counterparties’ credit quality and liquidity.

Accumulated change in equity from transactions and other events and circumstances from non-owner sources, net of tax effect, at period end. Excludes Net Income (Loss), and accumulated changes in equity from transactions resulting from investments by owners and distributions to owners. Includes foreign currency translation items, certain pension adjustments, unrealized gains and losses on certain investments in debt and equity securities, other than temporary impairment (OTTI) losses related to factors other than credit losses on available-for-sale and held-to-maturity debt securities that an entity does not intend to sell and it is not more likely than not that the entity will be required to sell before recovery of the amortized cost basis, as well as changes in the fair value of derivatives related to the effective portion of a designated cash flow hedge.

Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Inventory, Net [Abstract]
Crude oil and natural gas	$ 461	$ 472
Materials and supplies	541	554
Inventory Net	$ 1,002	$ 1,026

Inventory Disclosure - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2019
Inventory, Net [Abstract]
Inventories valued on the LIFO basis	$ 282		$ 286
Lower of cost or market adjustments		$ 228
Excess of current replacement cost over LIFO cost of inventories	$ 87		$ 155

Assets Acquisitions and Dispositions Textuals (Details) shares in Millions			1 Months Ended								3 Months Ended						12 Months Ended
	Jan. 15, 2021 USD ($) shares	May 27, 2020 USD ($) MBoe	Aug. 31, 2020 USD ($) a	May 31, 2020 USD ($)	Mar. 31, 2020 USD ($)	Feb. 29, 2020 USD ($)	Sep. 30, 2019 USD ($)	Apr. 30, 2019 USD ($)	Jan. 31, 2019 USD ($)	Oct. 31, 2018 USD ($)	Dec. 31, 2019 USD ($)	Jun. 30, 2019 USD ($)	Dec. 31, 2018 USD ($)	Sep. 30, 2018 USD ($)	Jun. 30, 2018 USD ($)	Mar. 31, 2018 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)	Jan. 31, 2021 USD ($)	Dec. 18, 2018 USD ($)	May 17, 2017
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments																	$ 432,000,000	$ 779,000,000	$ 1,074,000,000
Exploration Expense																	1,457,000,000	743,000,000	369,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Equity Method Investments											$ 8,234,000,000						7,596,000,000	8,234,000,000
Business Combinations [Abstract]
Business Combination, Consideration Transferred	$ 13,100,000,000
Business Combination, Share Exchange Ratio	1.46
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt	$ 3,900,000,000
Concho Resources Inc [Member] \| Subsequent Event [Member]
Business Combinations [Abstract]
Business Combination, Consideration Transferred	$ 13,125,000,000
Business Combination, Share Exchange Ratio	1.46
Business Combination, Consideration Transferred, Equity Interests Issued and Issuable, Shares \| shares	286
Long-term Debt	$ 3,900,000,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt	$ 4,700,000,000
Operating Segments [Member]
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments																	432,000,000	779,000,000	1,074,000,000
Corporate, Non-Segment [Member]
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments																	0	0	0
Alaska Segment [Member] \| Operating Segments [Member]
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments																	(7,000,000)	7,000,000	6,000,000
Lower 48 Segment [Member]
Income related items for assets held for sale [Abstract]
Exploration Expense																		141,000,000
Lower 48 Segment [Member] \| Operating Segments [Member]
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments																	(11,000,000)	(159,000,000)	1,000,000
Canada Segment [Member] \| Operating Segments [Member]
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments																	0	0	0
Canada Segment [Member] \| Operating Segments [Member] \| Montney [Member]
Business Combinations [Abstract]
Oil and Gas, Undeveloped Acreage, Net \| a			295,000
Noncontrolling Interest, Ownership Percentage by Parent			100.00%
Canada Segment [Member] \| Operating Segments [Member] \| Additional Montney Acreage [Member]
Business Combinations [Abstract]
Payments To Acquire Businesses, Gross			$ 382,000,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Financial Liabilities																				$ 31,000,000
Oil and Gas, Undeveloped Acreage, Net \| a			140,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Property, Plant, and Equipment			$ 490,000,000
Asset retirement obligations and accrued environmental costs			77,000,000
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt			$ 31,000,000
Asia Pacific and Middle East Segment [Member] \| Operating Segments [Member]
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments																	137,000,000	461,000,000	323,000,000
Asia Pacific [Member]
Income related items for assets held for sale [Abstract]
Exploration Expense																	50,000,000
Europe and North Africa Segment [Member] \| Operating Segments [Member]
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments																	311,000,000	470,000,000	744,000,000
Australia West Assets [Member] \| Asia Pacific [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions				$ 765,000,000
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Net carrying value		$ 200,000,000
Disposition, Cash		500,000,000
Disposition, PP&E		1,300,000,000
Disposition, Other current assets		100,000,000
Asset Retirement Obligation of held for sale or sold		700,000,000
Disposition, deferred tax liabilities		300,000,000
Disposition, other liabilities		$ 200,000,000
Disposition, Before-tax earnings																	(851,000,000)	(372,000,000)	(364,000,000)
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition																	$ 587,000,000
Barossa project [Member] \| Asia Pacific [Member] \| Operating Segments [Member]
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Production \| MBoe		43
Barossa project [Member] \| Asia Pacific [Member] \| Operating Segments [Member] \| Scenario Plan [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions				$ 200,000,000
Caldita Field [Member] \| Asia Pacific and Middle East Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Ownership Percent																	37.50%
Bayu-Undan Field [Member] \| Asia Pacific and Middle East Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Ownership Percent																	56.90%
Niobrara [Member] \| Lower 48 Segment [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions					$ 359,000,000
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Net carrying value					397,000,000
Disposition, PP&E					433,000,000
Asset Retirement Obligation of held for sale or sold					34,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition					$ 38,000,000
Niobrara [Member] \| Lower 48 Segment [Member] \| Operating Segments [Member]
Income related items for assets held for sale [Abstract]
Results Of Operations Income Before Income Taxes																	$ 25,000,000	372,000,000	35,000,000
Impairment of asset held for sale											386,000,000
Golden Pass [Member] \| Lower 48 Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Ownership percentage in equity investment									12.40%
Income related items for assets held for sale [Abstract]
Income (Loss) From Equity Method Investments									$ 60,000,000
U.K. Subsidiaries [Member] \| Operating Segments [Member]
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
After-tax gain (loss) on disposition											2,100,000		$ 900,000					2,100,000	900,000
U.K. Subsidiaries [Member] \| Europe and North Africa Segment [Member] \| Operating Segments [Member] \| Scenario Plan [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions							$ 2,200,000,000	$ 2,675,000,000
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Net carrying value							500,000,000
Disposition, PP&E							1,600,000,000
Working Capital and cash in net carrying value							100,000,000
Amount of deferred taxes in carrying value of asset							300,000,000
Cumulative foreign currency translation adjustments							500,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition																		1,700,000,000
After-tax gain (loss) on disposition											2,100,000,000							2,100,000,000
U.K. Subsidiaries [Member] \| Europe and North Africa Segment [Member] \| Operating Segments [Member] \| Asset Retirement Obligation Costs [Member]
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Asset Retirement Obligation of held for sale or sold							$ 1,800,000,000
Greater Sunrise Fields [Member] \| Asia Pacific and Middle East Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions												$ 350,000,000
Ownership Percent												30.00%
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
After-tax gain (loss) on disposition												$ 52,000,000
Magnolia Field And Platform [Member] \| Lower 48 Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions											16,000,000
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Disposition, PP&E											4,000,000							4,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition											82,000,000
Magnolia Field And Platform [Member] \| Lower 48 Segment [Member] \| Operating Segments [Member] \| Asset Retirement Obligation Costs [Member]
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Asset retirement obligation at disposal											$ 70,000,000							$ 70,000,000
Other properties [Member] \| Lower 48 Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions																$ 112,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition																$ 0
Undeveloped Leasehold Assets [Member] \| Lower 48 Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions													162,000,000	$ 56,000,000	$ 105,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition													140,000,000		$ 0
Barnett [Member] \| Lower 48 Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions										$ 196,000,000
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Net carrying value										201,000,000
Disposition, PP&E										250,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition										5,000,000
Barnett [Member] \| Lower 48 Segment [Member] \| Operating Segments [Member] \| Asset Retirement Obligation Costs [Member]
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Asset retirement obligation at disposal										$ 49,000,000
Income related items for assets held for sale [Abstract]
Results Of Operations Income Before Income Taxes																			(59,000,000)
U.K. subsidiary holding Clair field \| Europe and North Africa Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions													253,000,000
Ownership Percent																					16.50%
Ownership percentage retained																					7.50%
Ownership percentage in equity investment																					24.00%
Fair Value Assets Disposed Of																					$ 1,743,000,000
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Net carrying value																					1,028,000,000
Disposition, PP&E																					1,553,000,000
Disposition, deferred tax liabilities																					485,000,000
Income related items for assets held for sale [Abstract]
Results Of Operations Income Before Income Taxes																			$ 748,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition													$ 715,000,000
U.K. subsidiary holding Clair field \| Europe and North Africa Segment [Member] \| Operating Segments [Member] \| Asset Retirement Obligation Costs [Member]
Disposal Group, Including Discontinued Operation, Assets, Current [Abstract]
Asset retirement obligation at disposal																					$ 59,000,000
Clair Field [Member] \| Europe and North Africa Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Ownership Percent																					24.00%
Greater Kuparuk Area [Member] \| Alaska Segment [Member] \| Operating Segments [Member]
Asset Held For Sale Transaction Detail [Abstract]
Ownership Percent																					39.20%
Ownership percentage retained																					38.00%
Foster Creek Christina Lake (FCCL) [Member]
Asset Held For Sale Transaction Detail [Abstract]
Ownership percentage in equity investment																						50.00%
Waddell Ranch [Member] \| Lower 48 Segment [Member]
Asset Held For Sale Transaction Detail [Abstract]
Proceeds from asset dispositions						$ 184,000,000
Gain (Loss) on Disposition of Oil and Gas Property [Abstract]
Before-tax gain (loss) on disposition						$ 0

Aquisitons (Details) - USD ($)	1 Months Ended	3 Months Ended	12 Months Ended
Aquisitons (Details) - USD ($)	May 31, 2018	Dec. 31, 2018	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 18, 2018
Business Combinations [Abstract]
Property, Plant and Equipment, Net			$ 39,893,000,000	$ 42,269,000,000
Capitalized Costs, Unproved Properties			4,141,000,000	3,980,000,000
Capitalized Costs Proved Properties			94,312,000,000	88,284,000,000
Inventories Acquired			0	0	$ 42,000,000
Investments and long-term receivables			8,017,000,000	8,687,000,000
Asset Retirement Obligation		$ 7,908,000,000	$ 5,573,000,000	$ 6,206,000,000	$ 7,908,000,000
Kuparuk Assets [Member] \| Alaska Segment [Member] \| Operating Segments [Member]
Business Acquisition [Line Items]
Costs Incurred, Acquisition of Oil and Gas Properties, Total	$ 386,000,000	1,490,000,000
Percent Acquired	22.00%
Fair Value of Assets Acquired		1,743,000,000
Business Combinations [Abstract]
Capitalized Costs, Unproved Properties	$ 114,000,000
Capitalized Costs Proved Properties	297,000,000					$ 1,900,000,000
Inventories Acquired	20,000,000	$ 42,000,000
Investments and long-term receivables	14,000,000					15,000,000
Net Working Capital						(100,000,000)
Kuparuk Assets [Member] \| Alaska Segment [Member] \| Operating Segments [Member] \| Asset Retirement Obligation Costs [Member]
Business Combinations [Abstract]
Asset Retirement Obligation	$ 59,000,000					$ 374,000,000

Investments, Loans and LT Receivables Components (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Summary of Investment Holdings [Line Items]
Equity investments	$ 7,596	$ 8,234
Loans and advances-related parties	114	219
Long-term receivables	137	243
Other investments	67	77
Total	8,131	8,906
Other Long-term Investments [Member]
Summary of Investment Holdings [Line Items]
Investments in long-term debt securities	$ 217	$ 133

Investments, Loans and LT Receivables - Financial Info (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Equity Method Investment, Summarized Financial Information [Line Items]
Total Revenues and Other Income	$ 19,256	$ 36,670	$ 38,727
Net income (loss)	(2,655)	7,257	6,305
Total Current Assets	12,066	16,913
Total Current Liabilities	5,366	7,043
Affiliated Companies [Member]
Equity Method Investment, Summarized Financial Information [Line Items]
Total Revenues and Other Income	7,931	11,310	11,654
Income (loss) before income taxes	1,843	3,726	3,660
Net income (loss)	1,426	3,085	$ 3,244
Total Current Assets	2,579	3,289
Noncurrent assets	35,257	38,905
Total Current Liabilities	2,110	2,603
Noncurrent liabilities	$ 18,099	$ 22,168

Sum of the carrying amounts as of the balance sheet date of all assets that are expected to be realized in cash, sold, or consumed within one year (or the normal operating cycle, if longer). Assets are probable future economic benefits obtained or controlled by an entity as a result of past transactions or events.

Sum of the carrying amounts as of the balance sheet date of all assets that are expected to be realized in cash, sold or consumed after one year or beyond the normal operating cycle, if longer.

Amount after tax of income (loss) from continuing operations including portion attributable to the noncontrolling interest.

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Total obligations incurred as part of normal operations that are expected to be paid during the following twelve months or within one business cycle, if longer.

Amount of obligation due after one year or beyond the normal operating cycle, if longer.

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The consolidated profit or loss for the period, net of income taxes, including the portion attributable to the noncontrolling interest.

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Amount of revenue recognized from goods sold, services rendered, insurance premiums, or other activities that constitute an earning process. Includes, but is not limited to, investment and interest income before deduction of interest expense when recognized as a component of revenue, and sales and trading gain (loss).

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Schedule of Available-for-sale Securities [Line Items]

Investments, Loans and LT Receivables Textuals (Details) - USD ($) $ in Millions	1 Months Ended	3 Months Ended		12 Months Ended
	Sep. 30, 2018	Sep. 30, 2019	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2012
Equity Method Investment, Summarized Financial Information [Line Items]
Retained Earning Equity Method				$ 41
Equity Method Investment Dividends				1,076	$ 1,378	$ 1,226
Letters of Credit [Abstract]
Book value of equity method investment				7,596	8,234
Income (Loss) From Equity Method Investments				$ 432	779	1,074
Australia Pacific LNG [Member]
Equity Method Investment, Summarized Financial Information [Line Items]
Ownership percentage in equity investment				37.50%
Equity method investments, fair value				$ 6,560
Letters of Credit [Abstract]
Total amount under revolving credit facilities							$ 8,500
Line of Credit Facility, Frequency of Payments				bi-annual
Balance Outstanding On Credit Facility				$ 6,200
Long Term Debt Refinanced Amount			$ 3,200
Equity Method Investment, Other than Temporary Impairment				112
Book value of equity method investment				6,672
Historical cost basis				6,242
Difference between estimated value and book value of equity method investment				430
Amortizable portion of the basis difference in PPE				$ 41	$ 36	$ 44
Australia Pacific LNG [Member] \| Export-Import Bank of US [Member]
Letters of Credit [Abstract]
Total amount under revolving credit facilities							2,900
Australia Pacific LNG [Member] \| Export-Import Bank of China [Member]
Letters of Credit [Abstract]
Total amount under revolving credit facilities							2,700
Early Repayment of Senior Debt	$ 1,400		1,000
Line of Credit Facility, Frequency of Payments				bi-annual
Australia Pacific LNG [Member] \| U S Private Placement Bond [Member]
Letters of Credit [Abstract]
Total amount under revolving credit facilities	$ 1,400
Australia Pacific LNG [Member] \| Australian and International Commercial Bank Syndicate [Member]
Letters of Credit [Abstract]
Total amount under revolving credit facilities							$ 2,900
Early Repayment of Senior Debt			$ 2,200
Australia Pacific LNG [Member] \| Commerical Banks [Member]
Letters of Credit [Abstract]
Line of Credit Facility, Frequency of Payments		bi-annual
Long Term Debt Refinanced Amount		$ 2,600
Australia Pacific LNG [Member] \| U S Private Placement Bond Two [Member]
Letters of Credit [Abstract]
Total amount under revolving credit facilities		$ 600
Line of Credit Facility, Frequency of Payments		bi-annual
Australia Pacific LNG [Member] \| Origin Energy [Member]
Equity Method Investment, Summarized Financial Information [Line Items]
Ownership percentage in equity investment				37.50%
Australia Pacific LNG [Member] \| Sinopec [Member]
Equity Method Investment, Summarized Financial Information [Line Items]
Ownership percentage in equity investment				25.00%
QG3
Equity Method Investment, Summarized Financial Information [Line Items]
Ownership percentage in equity investment				30.00%
Letters of Credit [Abstract]
Total amount under revolving credit facilities				$ 4,000
Line of Credit Facility, Frequency of Payments				Semi-annual
Book value of equity method investment				$ 742
Loans to related parties				220
QG3 \| Credit Agencies [Member]
Letters of Credit [Abstract]
Total amount under revolving credit facilities				1,300
QG3 \| Commerical Banks [Member]
Letters of Credit [Abstract]
Total amount under revolving credit facilities				1,500
QG3 \| ConocoPhillips [Member]
Letters of Credit [Abstract]
Total amount under revolving credit facilities				$ 1,200
QG3 \| Mitsui & Co, Ltd. [Member]
Equity Method Investment, Summarized Financial Information [Line Items]
Ownership percentage in equity investment				1.50%
QG3 \| Qatar Petroleum [Member]
Equity Method Investment, Summarized Financial Information [Line Items]
Ownership percentage in equity investment				68.50%
QG3 \| Other Affiliates [Member]
Letters of Credit [Abstract]
Loans to related parties				$ 220
Golden Pass [Member]
Equity Method Investment, Summarized Financial Information [Line Items]
Ownership percentage in equity investment				12.40%

Investment in Cenovus Energy (Details) - USD ($)

3 Months Ended

5 Months Ended

12 Months Ended

Dec. 31, 2018

May 17, 2017

Dec. 31, 2020

Dec. 31, 2019

Dec. 31, 2018

Jan. 04, 2021

Investment in Cenovus Energy

$ 1,256,000,000

$ 2,111,000,000

Unrealized (gain) loss on investment in Cenovus Energy

(855,000,000)

649,000,000

$ (437,000,000)

Unrealized Gain (Loss) on Securities, before tax

^[1]

$ (855,000,000)

649,000,000

$ (437,000,000)

Foster Creek Christina Lake (FCCL) [Member]

Schedule of Available-for-sale Securities [Line Items]

Ownership percentage in equity investment

50.00%

Common Stock [Member] | Cenovus Energy [Member]

Schedule of Available-for-sale Securities [Line Items]

Shares Exchanged for Assets Held for Sale

208,000,000

Investment Owned, Common Stock, percent of Issued and Outstanding

16.90%

10.00%

Investment in Cenovus Energy

$ 1,960,000,000

Investment In Equity Security Fair Value

$ 1,260,000,000

2,110,000,000

Cenovus Energy common share price

$ 9.41

$ 6.04

Unrealized Gain (Loss) on Securities, before tax

$ (437,000,000)

$ 649,000,000

[1]	*See Note 6—Investment in Cenovus Energy, for additional information.

Suspended Wells Net Changes in Well Costs (Details) - USD ($)

12 Months Ended

Dec. 31, 2020

Dec. 31, 2019

Dec. 31, 2018

Net changes in suspended Exploratory well costs

Beginning balance

$ 1,020,000,000

^[1]

$ 856,000,000

$ 853,000,000

Additions pending the determination of proved reserves

164,000,000

239,000,000

140,000,000

Reclassifications to proved properties

(42,000,000)

(11,000,000)

(37,000,000)

Sales of suspended wells

(313,000,000)

(54,000,000)

(93,000,000)

Charged to dry hole expense

(147,000,000)

(10,000,000)

(7,000,000)

Ending balance

$ 682,000,000

$ 1,020,000,000

^[1]

$ 856,000,000

[1]	*Includes $ 313 million of assets held for sale in Australia at December 31, 2019.

Suspended Wells Changes in Well Costs Narrative (Details) - USD ($)

Dec. 31, 2020

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Capitalized Exploratory Well Costs

$ 682,000,000

$ 1,020,000,000

^[1]

$ 856,000,000

$ 853,000,000

AUSTRALIA

Capitalized Exploratory Well Costs

$ 313,000,000

[1]	*Includes $ 313 million of assets held for sale in Australia at December 31, 2019.

Suspended Wells - Aging of suspended well balances (Details)

Dec. 31, 2020

USD ($)

Dec. 31, 2019

USD ($)

Dec. 31, 2018

USD ($)

Dec. 31, 2017

USD ($)

Aging of suspended well cost

Exploratory well costs capitalized for a period of one year or less

$ 156,000,000

$ 206,000,000

$ 145,000,000

Exploratory well costs capitalized for a period greater than one year

526,000,000

814,000,000

711,000,000

Ending balance

$ 682,000,000

$ 1,020,000,000

^[1]

$ 856,000,000

$ 853,000,000

Number of projects that have exploratory well costs that have been capitalized for a period greater than one year

[1]	*Includes $ 313 million of assets held for sale in Australia at December 31, 2019.

Suspended Wells-Exploration Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	$ 1,457	$ 743	$ 369
Lower 48 Segment [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		141
Lower 48 Segment [Member] \| Central Louisiana Austin Chalk [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense		$ 111
Lower 48 Segment [Member] \| Alaska North Slope Gas [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	828
Other International Segment [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	84
Asia Pacific [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense	$ 50

Impairments (Details) - USD ($) $ in Millions	12 Months Ended
Impairments (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 813	$ 405	$ 27
Alaska Segment [Member] \| Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	0	0	20
Lower 48 Segment [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	813
Lower 48 Segment [Member] \| Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	804	402	63
Canada Segment [Member] \| Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	3	2	9
Europe, Middle East, And North Africa [Member] \| Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	6	1	(79)
Asia Pacific [Member] \| Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 0	$ 0	$ 14

Impairments Narratives (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
Impairments Narratives (Details) - USD ($) $ in Millions	Dec. 31, 2020	Mar. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges			$ 813	$ 405	$ 27
Exploration Expense			1,457	743	369
Alaska Segment [Member] \| Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges			0	0	20
Alaska Segment [Member] \| Cancelled Project [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges					20
Lower 48 Segment [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges			813
Exploration Expense				141
Lower 48 Segment [Member] \| Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges			804	402	63
Lower 48 Segment [Member] \| Niobrara [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges				402
Lower 48 Segment [Member] \| Central Louisiana Austin Chalk [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense				111
Lower 48 Segment [Member] \| Barnett [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges					63
Lower 48 Segment [Member] \| Wind River Basin [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges	$ 287	$ 523
Canada Segment [Member] \| Operating Segments [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges			3	$ 2	9
Europe and North Africa Segment [Member] \| Certain Projects In Europe And NorthAfrica [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Asset Impairment Charges					$ (79)
Other International Segment [Member]
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Exploration Expense			$ 84

Asset Retirement Obligations and Accrued Environmental Costs (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Environmental Liabilities [Line Items]
Asset retirement obligations	$ 5,573	$ 6,206	$ 7,908
Accrued environmental costs	180	171
Total asset retirement obligations and accrued environmental costs	5,753	6,377
Asset retirement obligations and accrued environmental costs due within one year	323	1,025
Long-term asset retirement obligations and accrued environmental costs	$ 5,430	5,352
Other accruals
Environmental Liabilities [Line Items]
Asset retirement obligations and accrued environmental costs due within one year		$ (741)

Asset Retirement Obligations and Accrued Environmental Costs - Change in Asset Retirement Obligations (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Changes in overall asset retirement obligation changed
Balance at January 1	$ 6,206	$ 7,908
Accretion of discount	248	322
New obligations	262	155
Changes in estimates of existing obligations	(307)	50
Spending on existing obligations	(116)	(229)
Property dispositions	(771)	(1,920)
Foreign currency translation	51	(80)
Balance at December 31	$ 5,573	$ 6,206

Asset Retirement Obligations and Accrued Environmental Costs - Textuals (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Environmental Liabilities [Line Items]
Accrued environmental costs	$ 180	$ 171
Accrued Enviornmental Costs Discounted	$ 106
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 2021	$ 23
Accrued environmental costs, undiscounted due 2022	17
Accrued environmental costs, undiscounted due 2023	18
Accrued environmental costs, undiscounted due 2024	3
Accrued environmental costs, undiscounted due 2025	2
Accrued environmental costs, undiscounted due after 2026	103
Cleanup Remediation Activities [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	116	112
Corporate and Other Environmental Liabilities [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	48	47
Federal Comprehensive Environmental Response Compensation and Liability Act or Similar State Laws [Member]
Environmental Liabilities [Line Items]
Accrued environmental costs	$ 16	$ 12

Debt (Details) - USD ($)
$ in Millions

Dec. 31, 2020

Dec. 31, 2019

Finance Lease Obligations

$ 14,292

$ 13,971

891

720

Net unamortized premiums and discounts

186

204

Total debt

15,369

14,895

Short-term debt

(619)

(105)

Long-term debt

14,750

14,790

Variable rate debt bonds [Member]

9.125% Debentures [Member] | Due 2021 [Member] | Unsecured Debt (Debentures) [Member]

283

$ 123

123

8.20% Debentures [Member] | Due 2025 [Member] | Unsecured Debt (Debentures) [Member]

9.125%

$ 134

134

8.125% Notes [Member] | Due 2030 [Member] | Notes Payable To Banks [Member]

8.20%

$ 390

390

7.9% Debentures [Member] | Due 2047 [Member] | Notes Payable To Banks [Member]

8.125%

$ 60

7.8% Debentures [Member] | Due 2027 [Member] | Unsecured Debt (Debentures) [Member]

7.90%

$ 203

203

7.65% Debentures [Member] | Due 2023 [Member] | Unsecured Debt (Debentures) [Member]

7.80%

$ 78

7.40% Notes [Member] | Due 2031 [Member] | Notes Payable To Banks [Member]

7.65%

$ 500

500

7.375% Debentures [Member] | Due 2029 [Member] | Unsecured Debt (Debentures) [Member]

7.40%

$ 92

7.25% Notes [Member] | Due 2031 [Member] | Notes Payable To Banks [Member]

7.375%

$ 500

500

7.20% Notes [Member] | Due 2031 [Member] | Notes Payable To Banks [Member]

7.25%

$ 575

575

7% Debentures [Member] | Due 2029 [Member] | Unsecured Debt (Debentures) [Member]

7.20%

$ 200

200

6.95% Notes [Member] | Due 2029 [Member] | Notes Payable To Banks [Member]

7.00%

$ 1,549

1,549

6.875% Debentures [Member] | Due 2026 [Member] | Unsecured Debt (Debentures) [Member]

6.95%

$ 67

6.50% Notes [Member] | Due 2039 [Member] | Notes Payable To Banks [Member]

6.875%

$ 2,750

2,750

5.951% Notes [Member] | Due 2037 [Member] | Notes Payable To Banks [Member]

6.50%

$ 645

645

5.95% Notes [Member] | Due 2036 [Member] | Notes Payable To Banks [Member]

5.951%

$ 500

500

5.95% Notes [Member] | Due 2046 [Member] | Notes Payable To Banks [Member]

5.95%

$ 500

500

5.90% Notes [Member] | Due 2032 [Member] | Notes Payable To Banks [Member]

5.95%

$ 505

505

5.90% Notes [Member] | Due 2038 [Member] | Notes Payable To Banks [Member]

5.90%

$ 600

600

4.95% Notes [Member] | Due 2026 [Member] | Notes Payable To Banks [Member]

5.90%

$ 1,250

1,250

4.3% Notes [Member] | Due 2044 [Member] | Notes Payable To Banks [Member]

4.95%

$ 750

750

4.15% Notes [Member] | Due 2034 [Member] | Notes Payable To Banks [Member]

4.30%

$ 246

246

3.35% Notes [Member] | Due 2024 [Member] | Notes Payable To Banks [Member]

4.15%

$ 426

426

3.35% Notes [Member] | Due 2025 [Member] | Notes Payable To Banks [Member]

3.35%

$ 199

199

2.4% Notes [Member] | Due 2022 [Member] | Notes Payable To Banks [Member]

3.35%

$ 329

329

Floating rate note due 2018 [Member] | Due 2018 [Member] | Floating Rate Notes [Member]

2.40%

Floating Rate Notes Due 2022 [Member] | Floating Rate Notes [Member] | Minimum [Member]

$ 500

Floating Rate Notes Due 2022 [Member] | Floating Rate Notes [Member] | Maximum [Member]

1.12%

2.81%

Marine Terminal Revenue Refunding Bonds [Member] | Variable rate debt bonds [Member] | Minimum [Member]

2.81%

3.58%

Marine Terminal Revenue Refunding Bonds [Member] | Variable rate debt bonds [Member] | Maximum [Member]

0.10%

^[1]

1.08%

Marine Terminal Revenue Refunding Bonds [Member] | Due 2031 [Member] | Variable rate debt bonds [Member]

7.50%

2.45%

Commercial Paper due 2020 [Member] | Due 2020 [Member] | Commercial Paper, Variable Rate [Member]

$ 18

Commercial Paper due 2020 [Member] | Due 2020 [Member] | Commercial Paper, Variable Rate [Member] | Minimum [Member]

$ 300

Commercial Paper due 2020 [Member] | Due 2020 [Member] | Commercial Paper, Variable Rate [Member] | Maximum [Member]

8.00%

Industrial Development Bonds Due One [Member] | Variable rate debt bonds [Member]

23.00%

Industrial Development Bonds Due One [Member] | Variable rate debt bonds [Member] | Minimum [Member]

$ 265

Industrial Development Bonds Due One [Member] | Variable rate debt bonds [Member] | Maximum [Member]

0.11%

1.08%

Other Debt [Member] | Unsecured Debt (Debentures) [Member]

7.50%

2.45%

Trading Activity, Gains and Losses, Net [Line Items]

$ 38

$ 17

[1]	<div>Plans for which ConocoPhillips is not the primary obligor—primarily those administered by equity affiliates.</div>

Debt Narratives (Details) - USD ($)	12 Months Ended
Debt Narratives (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Feb. 04, 2021	Jan. 15, 2021	Sep. 30, 2020
Debt (Textual) [Abstract]
Maturities of long-term borrowings in 2021	$ 619,000,000
Maturities of long-term borrowings in 2022	1,001,000,000
Maturities of long-term borrowings in 2023	259,000,000
Maturities of long-term borrowings in 2024	579,000,000
Maturities of long-term borrowings in 2025	465,000,000
Short-term Debt [Line Items]
Letters of Credit Outstanding, Amount	249,000,000
Debt Instrument [Line Items]
Debt Instrument, Face Amount	14,292,000,000	$ 13,971,000,000
Repayment of Debt	254,000,000	80,000,000	$ 4,995,000,000
Subsequent Event [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt					$ 3,900,000,000
Revolving Credit Facility [Member]
Short-term Debt [Line Items]
Total amount under revolving credit facilities	6,000,000,000.0
Commercial paper program	$ 6,000,000,000.0
Maturity period of commercial paper (in days)	P90D
Minimum limit of debt for cross default provision	$ 200,000,000
Letters of Credit Outstanding, Amount	0	0
Commercial paper outstanding		0
Line of Credit Facility, Remaining Borrowing Capacity	5,700,000,000
Letter Of Credit [Member]
Short-term Debt [Line Items]
Letters of credit capacity	500,000,000
Letters of Credit Outstanding, Amount		0
Subsequent Event [Member] \| Concho Resources Inc [Member]
Subsequent Event [Line Items]
Business Combination, Recognized Identifiable Assets Acquired and Liabilities Assumed, Noncurrent Liabilities, Long-term Debt					$ 4,700,000,000
Notes offered in exchange				$ 3,900,000,000
Percent of notes offered tendered and exchanged for new debt				98.00%
Tendered and exchanged notes for new debt				$ 3,800,000,000
Unsecured Debt (Debentures) [Member] \| Due 2021 [Member] \| 9.125% Debentures [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	123,000,000	123,000,000
Unsecured Debt (Debentures) [Member] \| Due 2023 [Member] \| 7.65% Debentures [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	78,000,000	78,000,000
Unsecured Debt (Debentures) [Member] \| Due 2025 [Member] \| 8.20% Debentures [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	134,000,000	134,000,000
Unsecured Debt (Debentures) [Member] \| Due 2027 [Member] \| 7.8% Debentures [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	203,000,000	203,000,000
Floating Rate Notes [Member] \| Due 2018 [Member] \| Floating rate note due 2018 [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	500,000,000	500,000,000
Variable rate debt bonds [Member]
Debt Instrument [Line Items]
Debt Instrument, Face Amount	283,000,000	283,000,000
ConocoPhilips Commerical Paper Program [Member] \| Commercial Paper [Member]
Short-term Debt [Line Items]
Letters of Credit Outstanding, Amount	$ 300,000,000	$ 0				$ 300,000,000

Guarantees Textual (Details) $ in Millions	12 Months Ended
Guarantees Textual (Details) $ in Millions	Dec. 31, 2020 USD ($)
Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Equity Interest Of Others	37.50%
Continued development [Member] \| Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 130
Terms of Guarantees Outstanding	16 to 25 years or the life of the venture
Guarantor Obligations, Current Carrying Value	$ 7
Other Guarantees [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 730
Terms of Guarantees Outstanding	P6Y
Guarantor Obligations, Current Carrying Value	$ 11
Indemnification [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Current Carrying Value	50
Guarantee existing sales agreement of natural gas delivery \| Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 770
Terms of Guarantees Outstanding	1 to 21 years
Max potential future payments-reckless breach [Member] \| Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 1,400
Finance Reserve Guarantee [Member] \| Australia Pacific LNG [Member]
Guarantor Obligations [Line Items]
Guarantor Obligations, Maximum Exposure, Undiscounted	$ 170
Terms of Guarantees Outstanding	P10Y
Guarantor Obligations, Current Carrying Value	$ 14

Contingencies and Commitments (Details) - USD ($) $ in Millions	1 Months Ended				3 Months Ended	12 Months Ended
	Jul. 31, 2020	Aug. 31, 2019	Mar. 31, 2019	Apr. 30, 2018	Sep. 30, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Aug. 29, 2019
Loss Contingencies [Line Items]
Letters of Credit Outstanding, Amount						$ 249.0
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						7.0
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Second Year						7.0
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Third Year						7.0
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Fourth Year						7.0
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due in Fifth Year						7.0
Payments under Long-Term Throughput Agreements And Take-or-Pay Agreements, Due after Fifth Year						51.0
Total payments under Long-Term Throughput Agreements and Take-or-Pay Agreements						$ 25.0	$ 25.0	$ 39.0
Burlington Resources Inc Vs The Republic Of Ecuador [Member]
Loss Contingencies [Line Items]
Cash Proceeds from Legal Settlements								262.0
ConocoPhillips Vs Petroleos de Venezuela SA [Member]
Loss Contingencies [Line Items]
Cash Proceeds from Legal Settlements							$ 330.0	$ 430.0
ConocoPhillips Vs Petroleos de Venezuela SA [Member] \| Venezuela
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party			$ 8,700.0
Litigation Settlement Amount Awarded From Other Party Revised									$ 8,500.0
Litigation Award Reduction									$ 227.0
Loss Contingency Settlement Agreement Terms						under their agreements in connection with the expropriation of the projects and other pre-expropriation fiscal measures. In August 2018, ConocoPhillips entered into a settlement with PDVSA to recover the full amount of this ICC award, plus interest through the payment period, including initial payments totaling approximately $500 million within a period of 90 days from the time of signing of the settlement agreement. The balance of the settlement is to be paid quarterly over a period of four and a half years.
ConocoPhillips Versus Petroleos De Venezuela 2 [Member] \| Venezuela
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party				$ 2,000.0
Cash Proceeds from Legal Settlements						$ 754.0
Conoco Phillips Versus Petroleos DeVenezuela 3 [Member] \| Venezuela
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party		$ 33.0
Several Louisiana parishes and the State of Louisiana against oil and gas companies [Member] \| The Louisiana Land And Exploration Company LLC [Member]
Loss Contingencies [Line Items]
Litigation Settlement, Amount Awarded from Other Party	$ 90.0
Cash Proceeds from Legal Settlements					$ 90.0

Derivative and Financial Instruments - Commodity Balance Sheet (Details) - Commodity Contract [Member] - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	$ 229	$ 288
Other assets [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative assets	26	34
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	202	283
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	$ 18	$ 28

Derivative and Financial Instruments - Commodity GainLoss (Details) - Commodity Contract [Member] - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Sales and other operating revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ 19,000,000	$ 141,000,000	$ 45,000,000
Other Income [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	4,000,000	4,000,000	7,000,000
Purchased commodities [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ 11,000,000	$ (118,000,000)	$ (41,000,000)

Derivative and Financial Instruments - Commodity Notional (Details) - Commodity Contract [Member] - Short [Member] - Bcfe Bcfe in Billions	Dec. 31, 2020	Dec. 31, 2019
Natural gas and power, Fixed price [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	(20)	(5)
Natural gas and power, Basis [Member]
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	(10)	(23)

Derivative and Financial Instruments - FX Balance Sheet (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Prepaid expenses and other current assets [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative assets	$ 2	$ 1
Other accruals [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative liabilities	16	20
Other liabilities and deferred credits [Member]
Derivatives, Fair Value [Line Items]
Foreign currency exchange derivative liabilities	$ 0	$ 8

Derivative and Financial Instruments - FX Derivative (Details)	12 Months Ended
	Dec. 31, 2020
Derivative and Financial Instruments [Abstract]
Description of Foreign Currency Derivative Instruments Not Designated as Hedging Instruments Activities	At December 31, 2020, we had outstanding foreign currency exchange forward contracts to sell $0.45 billion CAD at $0.748 CAD against the U.S. dollar. At December 31, 2019, we had outstanding foreign currency exchange forward contracts to sell $1.35 billion CAD at $0.748 CAD against the U.S. dollar

Derivative and Financial Instruments - FX GainLoss (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Foreign currency transaction (gains) losses [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Foreign currency transaction (gains) losses	$ (40)	$ 16	$ 1

Derivative and Financial Instruments - FX Notional (Details)
£ in Millions, $ in Millions, $ in Millions

12 Months Ended

Dec. 31, 2020

CAD ($)

Dec. 31, 2020

GBP (£)

Dec. 31, 2020

USD ($)

Dec. 31, 2019

CAD ($)

Dec. 31, 2019

GBP (£)

Dec. 31, 2019

USD ($)

Description of Foreign Currency Derivative Instruments Not Designated as Hedging Instruments Activities

At December 31, 2020, we had outstanding foreign currency exchange forward contracts to sell $0.45 billion CAD at $0.748 CAD against the U.S. dollar. At December 31, 2019, we had outstanding foreign currency exchange forward contracts to sell $1.35 billion CAD at $0.748 CAD against the U.S. dollar

Sell U.S. dollar, buy British pound. | Not Designated as Hedging Instrument [Member]

Trading Activity, Gains and Losses, Net [Line Items]

Net notional position of foreign currency exchange derivatives

$ 0

Sell British pound, buy other currencies [Member] | Not Designated as Hedging Instrument [Member]

Trading Activity, Gains and Losses, Net [Line Items]

Net notional position of foreign currency exchange derivatives | £

^[1]

£ 0

Buy British Pound Sell Euro [Member] | Not Designated as Hedging Instrument [Member]

Trading Activity, Gains and Losses, Net [Line Items]

Net notional position of foreign currency exchange derivatives | £

£ 0

£ 4

Sell British Pound, Buy Euro [Member] | Not Designated as Hedging Instrument [Member]

Trading Activity, Gains and Losses, Net [Line Items]

Net notional position of foreign currency exchange derivatives

$ 5

$ 0

Sell Canadian dollar, buy U.S. dollar [Member] | Not Designated as Hedging Instrument [Member]

Trading Activity, Gains and Losses, Net [Line Items]

Net notional position of foreign currency exchange derivatives

$ 370

$ 1,337

[1]	<div>0</div>

Derivative and Financial Instruments - Financial Instruments Cost (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents, carried at cost plus accrued interest	$ 2,978	$ 5,079
Short-term investments carried at cost plus accrued interest	3,320	2,929
Investments and long-term receivables carried at cost plus accrued interest	1	0
Cash [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents, carried at cost plus accrued interest	597	759
Demand Deposits [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents, carried at cost plus accrued interest	1,133	1,483
Bank Time Deposits [Member] \| Remaining maturities 1 To 90 Days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents, carried at cost plus accrued interest	1,225	2,030
Short-term investments carried at cost plus accrued interest	2,859	1,395
Bank Time Deposits [Member] \| Remaining maturities from 91 to 180 days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Short-term investments carried at cost plus accrued interest	448	465
Bank Time Deposits [Member] \| Remaining maturities within one year [Member]
Schedule of Held-to-maturity Securities [Line Items]
Short-term investments carried at cost plus accrued interest	13	0
Bank Time Deposits [Member] \| Remaining maturities greater than one year through five years [Member]
Schedule of Held-to-maturity Securities [Line Items]
Investments and long-term receivables carried at cost plus accrued interest	1	0
Commercial Paper [Member] \| Remaining maturities 1 To 90 Days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents, carried at cost plus accrued interest	0	413
Short-term investments carried at cost plus accrued interest	0	1,069
US Government Debt Securities [Member] \| Remaining maturities 1 To 90 Days [Member]
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents, carried at cost plus accrued interest	23	394
Short-term investments carried at cost plus accrued interest	$ 0	$ 0

Derivative and Financial Instruments - Financial Instruments Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Remaining maturities within one year [Member]
Schedule of Available-for-sale Securities [Line Items]
Cash and Cash Equivalents, carried at fair value	$ 13	$ 9
Short Term Investments At Fair Value	289	99
Remaining maturities greater than one year through five years [Member]
Schedule of Available-for-sale Securities [Line Items]
Investments and Long Term Receivable Carried At Fair Value	216	133
Corporate Debt [Member] \| Remaining maturities within one year [Member]
Schedule of Available-for-sale Securities [Line Items]
Cash and Cash Equivalents, carried at fair value	0	1
Short Term Investments At Fair Value	130	59
Corporate Debt [Member] \| Remaining maturities greater than one year through five years [Member]
Schedule of Available-for-sale Securities [Line Items]
Investments and Long Term Receivable Carried At Fair Value	143	99
Commercial Paper [Member] \| Remaining maturities within one year [Member]
Schedule of Available-for-sale Securities [Line Items]
Cash and Cash Equivalents, carried at fair value	13	8
Short Term Investments At Fair Value	155	30
US Government Debt Securities [Member] \| Remaining maturities within one year [Member]
Schedule of Available-for-sale Securities [Line Items]
Cash and Cash Equivalents, carried at fair value	0	0
Short Term Investments At Fair Value	4	10
US Government Debt Securities [Member] \| Remaining maturities greater than one year through five years [Member]
Schedule of Available-for-sale Securities [Line Items]
Investments and Long Term Receivable Carried At Fair Value	13	15
US Government Agencies Obligations [Member] \| Remaining maturities greater than one year through five years [Member]
Schedule of Available-for-sale Securities [Line Items]
Investments and Long Term Receivable Carried At Fair Value	17	0
Foreign Government Debt [Member] \| Remaining maturities greater than one year through five years [Member]
Schedule of Available-for-sale Securities [Line Items]
Investments and Long Term Receivable Carried At Fair Value	2	0
Asset-backed Securities [Member] \| Remaining maturities within one year [Member]
Schedule of Available-for-sale Securities [Line Items]
Short Term Investments At Fair Value	0	0
Asset-backed Securities [Member] \| Remaining maturities greater than one year through five years [Member]
Schedule of Available-for-sale Securities [Line Items]
Investments and Long Term Receivable Carried At Fair Value	$ 41	$ 19

Derivative and Financial Instruments - Cost Basis to Fair Value (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost Basis	$ 516	$ 241
Investments, Fair Value Disclosure	518	241
Proceeds from sales and redemptions of investments in debt securities classified as available for sale	422
Corporate Debt [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost Basis	271	159
Investments, Fair Value Disclosure	273	159
Commercial Paper [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost Basis	168	38
Investments, Fair Value Disclosure	168	38
US Government Debt Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost Basis	17	25
Investments, Fair Value Disclosure	17	25
US Government Agencies Obligations [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost Basis	17	0
Investments, Fair Value Disclosure	17	0
Foreign Government Debt [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost Basis	2	0
Investments, Fair Value Disclosure	2	0
Asset-backed Securities [Member]
Schedule of Available-for-sale Securities [Line Items]
Amortized Cost Basis	41	19
Investments, Fair Value Disclosure	$ 41	$ 19

Derivative and Financial Instruments - Credit Risk (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Schedule of Credit Risk [Line Items]
Collateral was posted for derivative instruments in a liability position	$ 0	$ 0
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Credit Derivative, Recourse Provisions	Certain of our derivative instruments contain provisions that require us to post collateral if the derivative exposure exceeds a threshold amount. We have contracts with fixed threshold amounts and other contracts with variable threshold amounts that are contingent on our credit rating. The variable threshold amounts typically decline for lower credit ratings, while both the variable and fixed threshold amounts typically revert to zero if we fall below investment grade. Cash is the primary collateral in all contracts; however, many also permit us to post letters of credit as collateral, such as transactions administered through the New York Mercantile Exchange.
In event of lowered credit rating [Member]
Schedule of Credit Risk [Line Items]
Derivative, Net Liability Position, Aggregate Fair Value	$ 25	$ 79
In event of downgrade below investment grade [Member]
Schedule of Credit Risk [Line Items]
Additional Collateral, Aggregate Fair Value	$ 23
Trade receivables [Member] \| Maximum [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Credit Derivative, Term	30 days

Fair Value Measurement - FV Hierarchy (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Commodity derivative asset, gross	$ 255,000,000	$ 322,000,000
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy		2,111,000,000
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	1,256,000,000	2,111,000,000
Available for sale debt securities at fair value	518,000,000	241,000,000
Commodity derivative asset, gross	255,000,000	322,000,000
Total assets	2,029,000,000	2,674,000,000
Commodity derivative liability, gross	220,000,000	311,000,000
Total liabilities	220,000,000	311,000,000
Fair Value, Measurements, Recurring [Member] \| Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	1,256,000,000	2,111,000,000
Available for sale debt securities at fair value	17,000,000	25,000,000
Commodity derivative asset, gross	142,000,000	172,000,000
Total assets	1,415,000,000	2,308,000,000
Commodity derivative liability, gross	120,000,000	174,000,000
Total liabilities	120,000,000	174,000,000
Fair Value, Measurements, Recurring [Member] \| Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	0
Available for sale debt securities at fair value	501,000,000	216,000,000
Commodity derivative asset, gross	101,000,000	114,000,000
Total assets	602,000,000	330,000,000
Commodity derivative liability, gross	91,000,000	115,000,000
Total liabilities	91,000,000	115,000,000
Fair Value, Measurements, Recurring [Member] \| Fair Value Inputs Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	0
Available for sale debt securities at fair value	0	0
Commodity derivative asset, gross	12,000,000	36,000,000
Total assets	12,000,000	36,000,000
Commodity derivative liability, gross	9,000,000	22,000,000
Total liabilities	$ 9,000,000	$ 22,000,000

Fair Value Measurement - FV of Commodity Derivatives (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Offsetting Derivative Assets [Abstract]
Assets - gross amounts recognized	$ 255	$ 322
Assets - amounts without right of setoff	2	3
Assets - gross amounts	253	319
Assets - gross amounts offset	157	193
Assets - net amounts presented	96	126
Assets - cash collateral	10	4
Assets - net amounts	86	122
Offsetting Derivative Liabilities [Abstract]
Liabilities - gross amounts recognized	220	311
Liabilities - amounts without right of setoff	1	4
Liabilities - gross amounts recognized	219	307
Liabilities - gross amounts offset	157	193
Liabilities - net amounts presented	62	114
Liabilities - cash collateral	4	12
Commodity derivatives, liability	$ 58	$ 102

Fair Value Measurement - Nonrecurring (Details) - Fair Value, Measurements, Nonrecurring [Member] - USD ($) $ in Millions	1 Months Ended		3 Months Ended		12 Months Ended
	Nov. 30, 2019	May 31, 2019	Mar. 31, 2020	Mar. 31, 2019	Dec. 31, 2020	Dec. 31, 2019
Fair Value, Disclosure Item Amounts [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value- Net PP&E (held for sale)	$ 194		$ 65		$ 268	$ 166
Before-Tax Loss - Net PP&E (held for sale)	351		522		287	28
Fair Value - Cost and Equity Method Investments		$ 30		$ 171
Before-Tax Loss - Cost and Equity method investments		95		60
Fair Value, Inputs, Level 1 [Member] \| Fair Value, Disclosure Item Amounts [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value- Net PP&E (held for sale)	194		0		0	166
Fair Value, Inputs, Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Cost and Equity Method Investments		0		171
Fair Value, Inputs, Level 2 [Member] \| Fair Value, Disclosure Item Amounts [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value- Net PP&E (held for sale)	0		0		0	0
Fair Value, Inputs, Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Cost and Equity Method Investments		30		0
Fair Value Inputs Level 3 [Member] \| Fair Value, Disclosure Item Amounts [Domain]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value- Net PP&E (held for sale)	$ 0		$ 65		$ 268	$ 0
Fair Value Inputs Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Cost and Equity Method Investments		$ 0		$ 0

Fair Value Measurement - Inputs and Valuation Techniques (Details) - Fair Value Inputs Level 3 [Member] - Lower 48 [Member] - Fair Value, Measurements, Nonrecurring [Member] $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2020 USD ($) $ / MMBTU MMcf	Dec. 31, 2020 USD ($) $ / MMBTU MMcf
Wind River Basin [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Assets, Fair Value Disclosure \| $	$ 65
Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Assets, Fair Value Disclosure \| $		$ 244
Measurement Input, Commodity Future Price [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
The future price annual increase (decrease) after year 2034, determined the Henry Hub natural gas price outlook based on external pricing service companies' outlooks for years 2022-2034.		2.20%
Measurement Input, Commodity Future Price [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
The future price annual increase (decrease) after year 2034, determined the Henry Hub natural gas price outlook based on external pricing service companies' outlooks for years 2022-2034.		2.00%
Minimum [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas production \| MMcf	8.4
Minimum [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas production \| MMcf		0.5
Minimum [Member] \| Measurement Input Discount Rate [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Discount Rate	7.90%
Minimum [Member] \| Measurement Input Discount Rate [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Discount Rate		6.80%
Minimum [Member] \| Measurement Input, Commodity Future Price [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas price outlook \| $ / MMBTU	2.67
Minimum [Member] \| Measurement Input, Commodity Future Price [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas price outlook \| $ / MMBTU		37.35
Maximum [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas production \| MMcf	55.2
Maximum [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas production \| MMcf		12.7
Maximum [Member] \| Measurement Input Discount Rate [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Discount Rate	9.10%
Maximum [Member] \| Measurement Input Discount Rate [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Discount Rate		7.70%
Maximum [Member] \| Measurement Input, Commodity Future Price [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas price outlook \| $ / MMBTU	9.17
Maximum [Member] \| Measurement Input, Commodity Future Price [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas price outlook \| $ / MMBTU		115.29
Arithmetic Average [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas production \| MMcf	22.9
Arithmetic Average [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas production \| MMcf		3.4
Arithmetic Average [Member] \| Measurement Input Discount Rate [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Discount Rate	8.30%
Arithmetic Average [Member] \| Measurement Input Discount Rate [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Discount Rate		7.40%
Arithmetic Average [Member] \| Measurement Input, Commodity Future Price [Member] \| Wind River Basin [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas price outlook \| $ / MMBTU	5.68
Arithmetic Average [Member] \| Measurement Input, Commodity Future Price [Member] \| Central Basin Platform [Member] \| Valuation Technique Discounted Cash Flow [Member]
Fair Value Measurements, Recurring and Nonrecurring, Valuation Techniques [Line Items]
Natural gas price outlook \| $ / MMBTU		73.80

Fair Value Measurement - Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 18, 2018
Financial Assets
Investment in Cenovus Energy	$ 1,256	$ 2,111
Derivative Asset, Fair Value, Amount Offset Against Collateral	96	126
Carrying Amount [Member]
Financial Assets
Investment in Cenovus Energy	1,256	2,111
Available for sale debt securities at fair value	518		$ 241
Total loans and advances - related parties	220	339
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term Debt	14,478	14,175
Carrying Amount [Member] \| Commodity Contract [Member]
Financial Assets
Derivative Asset, Fair Value, Amount Offset Against Collateral	88	125
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Commodity derivatives	59	106
Fair Value [Member]
Financial Assets
Investment in Cenovus Energy	1,256	2,111
Available for sale debt securities at fair value	518	241
Total loans and advances - related parties	220	339
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Long-term Debt	19,106	18,108
Fair Value [Member] \| Commodity Contract [Member]
Financial Assets
Derivative Asset, Fair Value, Amount Offset Against Collateral	88	125
Financial Instruments, Financial Liabilities, Balance Sheet Groupings [Abstract]
Commodity derivatives	$ 59	$ 106

Fair Value Measurement - Textuals (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Derivative and Financial Instruments [Abstract]
Obligations to return cash collateral	$ 10	$ 4
Rights to reclaim cash collateral	$ 4	$ 12

Equity - changes in shares of common stock (Details) - shares	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Changes in shares of common stock
Beginning Balance, Common Stock	1,795,652,203	1,791,637,434	1,785,419,175
Treasury Stock, Shares, Beginning Balance	710,783,814	653,288,213	608,312,034
Repurchase of common stock	20,018,275	57,495,601	44,976,179
Distributed under benefit plans	3,192,064	4,014,769	6,218,259
Ending Balance, Common Stock	1,798,844,267	1,795,652,203	1,791,637,434
Treasury Stock, Shares, Ending Balance	730,802,089	710,783,814	653,288,213

Equity - Textuals (Details) - USD ($) $ / shares in Units, $ in Millions	1 Months Ended	12 Months Ended			37 Months Ended
	Oct. 31, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2019	Dec. 31, 2016
Equity [Abstract]
Preferred Stock, Authorized		500,000,000
Preferred Stock, Par or Stated Value Per Share		$ 0.01
Preferred Stock, Shares Issued		0
Preferred Stock, Shares Outstanding		0
Stockholders' Equity Attributable to Noncontrolling Interest		$ 0	$ 69		$ 69
Treasury Stock, Shares, Acquired					189
Treasury Stock Value Acquired Cost Method	$ 200	$ 892	$ 3,500	$ 2,999	$ 10,517
Stock Repurchase Program Authorized						$ 25,000

Total of all stockholders' equity (deficit) items, net of receivables from officers, directors, owners, and affiliates of the entity which is directly or indirectly attributable to that ownership interest in subsidiary equity which is not attributable to the parent (that is, noncontrolling interest, previously referred to as minority interest).

Operating Lease Liabilities, Payments Due [Abstract]

Non Mineral Leases - Intro (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Finance Lease Obligations	$ 891	$ 720
Operating Lease, Liability	$ 785
Co Venturer Member
Lease, Practical Expedients, Package [true false]	true
Lease Practical Expedient Lessor Single Lease Component	true

Non-Mineral Leases - Balance Sheet (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Gross	$ 102,106,000,000	$ 97,746,000,000
Accumulated DD&A	(62,213,000,000)	(55,477,000,000)
Properties, plants and equipment, net	39,893,000,000	42,269,000,000
Short-term debt	619,000,000	105,000,000
Long-term debt	14,750,000,000	14,790,000,000
Finance Lease, Liability Total	891,000,000
Prepaid expenses and other current assets	454,000,000	2,259,000,000
Other assets (leases)	2,528,000,000	2,426,000,000
Other Liabilities, Current	1,121,000,000	2,045,000,000
Operating Lease, Liability	$ 785,000,000
Operating Lease Liability Statement Of Financial Position Extensible List	us-gaap:OtherLiabilities
Previously Reported [Member]
Gross	$ 1,375,000,000	1,039,000,000
Accumulated DD&A	(721,000,000)	(649,000,000)
Properties, plants and equipment, net	654,000,000	390,000,000
Short-term debt	168,000,000	87,000,000
Long-term debt	723,000,000	633,000,000
Finance Lease, Liability Total	891,000,000	720,000,000
Prepaid expenses and other current assets	0	40,000,000
Other assets (leases)	783,000,000	896,000,000
Other Liabilities, Current	226,000,000	347,000,000
Deferred Credits and Other Liabilities, non current	559,000,000	585,000,000
Operating Lease, Liability	$ 785,000,000	$ 932,000,000

Non-Mineral Leases - Balance Sheet Liabilities (Details) $ in Millions	Dec. 31, 2020 USD ($)
Finance Lease, Liability Total	$ 891
Operating Lease, Liability	$ 785

Non-Mineral Leases - Other Info (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Leases [Abstract]
Operating lease cost	$ 321	$ 341
Amortization of right-of-use assets	163	99
Interest on lease liabilities	34	37
Short-term Lease Cost	42	77
Lease Cost Total	$ 560	$ 554
Weighted-average term (years) - Operating Leases	6 years 1 month 9 days	5 years 2 months 8 days
Weighted-average term (years) - Finance Leases	7 years 1 month 13 days	8 years 8 months 12 days
Weighted Average Discount Rate (Percent) - Operating Leases	2.78%	3.10%
Weighted Average Discount Rate (Percent) - Finance Leases	4.27%	5.53%
Cash Flow, Operating Activities, Lessee [Abstract]
Operating cash flows from operating leases	$ 232	$ 203
Operating cash flows from finance leases	11	27
Financing cash flows from finance leases	255	81
Right-of-Use Asset Obtained in Exchange for Operating Lease Liability	250	499
Right-of-Use Asset Obtained in Exchange for Finance Lease Liability	$ 426	$ 26

Non-Mineral Leases - Maturities (Details)
$ in Millions

Dec. 31, 2020

USD ($)

$ 245

155

116

200

Lessee, Operating Lease, Liability, Payments, Due, Total

865

^[1]

Finance Lease Liabilities, Payments, Due [Abstract]

213

162

148

113

320

Finance Lease Liability, Payments, Due, Total

$ 1,043

^[1]

[1]

*Future lease payments for operating and finance leases commencing on or

after January 1, 2019, also include payments related to non-lease

components in accordance with our election to adopt the optional practical

expedient not to separate lease components apart from non-lease

components for accounting purposes.

In addition, future payments related to operating and finance leases proportionately consolidated by the

company have been included in the table on a proportionate basis consistent

with our respective ownership interest in the underlying investee

company or oil and gas venture.

Non-Mineral Leases - Maturities under 840 (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Capital lease obligations Under 840 [Abstract]
Finance Lease Obligations, Total	$ 891	$ 720

Non-Mineral Leases - Total Lease Liabilities (Details)
$ in Millions

Dec. 31, 2020

USD ($)

Operating Lease Liabilities Gross Difference Amount [Abstract]

Operating Lease, Liability

$ 785

Interest on operating lease liabilities

(80)

Lessee, Operating Lease, Liability, Payments, Due, Total

$ 865

^[1]

Operating Lease Liability Statement Of Financial Position Extensible List

us-gaap:OtherLiabilities

Finance Lease Liabilities, Gross Difference, Amount [Abstract]

Finance Lease, Liability Total

$ 891

Interest on Finance lease liabilities

(152)

Finance Lease Liability, Payments, Due, Total

$ 1,043

^[1]

[1]

*Future lease payments for operating and finance leases commencing on or

after January 1, 2019, also include payments related to non-lease

components in accordance with our election to adopt the optional practical

expedient not to separate lease components apart from non-lease

components for accounting purposes.

In addition, future payments related to operating and finance leases proportionately consolidated by the

company have been included in the table on a proportionate basis consistent

with our respective ownership interest in the underlying investee

company or oil and gas venture.

Non-Mineral Leases - Operating Lease Rentals (Details) $ in Millions	12 Months Ended
	Dec. 31, 2018 USD ($)
Operating lease rental expense
Operating Leases, Rent Expense, Minimum Rentals	$ 253
Less sublease rentals	(16)
Operating Leases, Rent Expense, Total	$ 237

Non-Mineral Leases - End Notes (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment, Net	$ 39,893,000,000	$ 42,269,000,000
Property plant equipment \| Co Venturer Member
Property, Plant and Equipment, Net	258,000,000	335,000,000
Short term debt \| Co Venturer Member
Finance Lease, Liability, Current	97,000,000	56,000,000
Long-term Debt Member \| Co Venturer Member
Finance Lease, Liability, Noncurrent	$ 522,000,000	$ 579,000,000

Employee Benefit Plans - Change in Benefit Obligations and Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Pension Plans Defined Benefit [Member] \| US
Change in Benefit Obligation
Benefit obligation at January 1	$ 2,319	$ 2,136
Service cost	85	79	$ 83
Interest cost	66	79	99
Plan participant contributions	0	0
Plan amendments	0	0
Actuarial (gain) loss	319	278
Benefits paid	(241)	(253)
Curtailment	0	0
Recognition of termination benefits	0	0
Foreign currency exchange rate change	0	0
Benefit obligation at December 31	2,548	2,319	2,136
Change in Fair Value of Plan Assets
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	1,591	1,336
Actual return on plan assets	321	273
Company contributions	99	235
Plan participant contributions	0	0
Defined Benefit Plan Plan Assets Benefits Paid	(241)	(253)
Foreign currency exchange rate change	0	0
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	1,770	1,591	1,336
Funded Status	(778)	(728)
Pension Plans Defined Benefit [Member] \| Foreign Pension Plans, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	3,880	3,438
Service cost	54	69	81
Interest cost	85	97	107
Plan participant contributions	1	2
Plan amendments	2	0
Actuarial (gain) loss	398	387
Benefits paid	(151)	(147)
Curtailment	2	(69)
Recognition of termination benefits	3	1
Foreign currency exchange rate change	129	102
Benefit obligation at December 31	4,403	3,880	3,438
Change in Fair Value of Plan Assets
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	4,306	3,358
Actual return on plan assets	416	529
Company contributions	60	464
Plan participant contributions	1	2
Defined Benefit Plan Plan Assets Benefits Paid	(151)	(147)
Foreign currency exchange rate change	161	100
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	4,793	4,306	3,358
Funded Status	390	426
Other Postretirement Benefit Plans, Defined Benefit [Member]
Change in Benefit Obligation
Benefit obligation at January 1	216	218
Service cost	2	1	1
Interest cost	6	8	8
Plan participant contributions	18	20
Plan amendments	(30)	0
Actuarial (gain) loss	7	27
Benefits paid	(49)	(59)
Curtailment	0	0
Recognition of termination benefits	0	0
Foreign currency exchange rate change	0	1
Benefit obligation at December 31	170	216	218
Change in Fair Value of Plan Assets
Defined Benefit Plan, Fair Value of Plan Assets, Beginning Balance	0	0
Actual return on plan assets	0	0
Company contributions	31	39
Plan participant contributions	18	20
Defined Benefit Plan Plan Assets Benefits Paid	(49)	(59)
Foreign currency exchange rate change	0	0
Defined Benefit Plan, Fair Value of Plan Assets, Ending Balance	0	0	$ 0
Funded Status	$ (170)	$ (216)

Employee Benefit Plans - Change in Benefit Obligations (Parenthetical) (Details) - Pension Plans Defined Benefit [Member] - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
US
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 2,359	$ 2,161
Foreign Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 4,095	$ 3,594

Employee Benefit Plans - Projected and Accumulated Benefit Obligations in Excess of Fair Value (Details) - Pension Plans Defined Benefit [Member] - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
US
Compensation And Retirement Disclosure [Abstract]
Accumulated benefit obligation	$ 2,359	$ 2,161
Fair values of pension plan assets	1,770	1,591	$ 1,336
Defined Benefit Plan Plans With Benefit Obligations In Excess Of Plan Assets [Abstract]
Projected benefit obligation	2,548	2,319
Fair value of plan assets	1,770	1,591
Defined Benefit Plan Pension Plans With Accumulated Benefit Obligations In Excess Of Plan Assets [Abstract]
Accumulated benefit obligation	2,359	2,161
Fair value of plan assets	1,770	1,591
Foreign Plan [Member]
Compensation And Retirement Disclosure [Abstract]
Accumulated benefit obligation	4,095	3,594
Fair values of pension plan assets	4,793	4,306	$ 3,358
Defined Benefit Plan Plans With Benefit Obligations In Excess Of Plan Assets [Abstract]
Projected benefit obligation	391	355
Fair value of plan assets	35	44
Defined Benefit Plan Pension Plans With Accumulated Benefit Obligations In Excess Of Plan Assets [Abstract]
Accumulated benefit obligation	338	299
Fair value of plan assets	$ 35	$ 44

Employee Benefit Plans - Amounts recognized in Balance Sheet And Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent liabilities	$ (1,697)	$ (1,781)
Pension Plans Defined Benefit [Member] \| US
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent assets	0	0
Current liabilities	(56)	(21)
Noncurrent liabilities	(722)	(707)
Total recognized	$ (778)	$ (728)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	2.30%	3.25%
Rate of compensation increase	4.00%	4.00%
Interest crediting rate for applicable benefits	2.10%	4.10%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	3.05%	3.95%
Expected return on plan assets	5.80%	5.80%
Rate of compensation increase	4.00%	4.00%
Interest crediting rate for applicable benefits	4.10%	4.35%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 467	$ 479
Unrecognized prior service cost (credit)	0	0
Pension Plans Defined Benefit [Member] \| Foreign Pension Plans, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent assets	746	765
Current liabilities	(11)	(6)
Noncurrent liabilities	(345)	(333)
Total recognized	$ 390	$ 426
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	1.80%	2.35%
Rate of compensation increase	3.10%	3.35%
Interest crediting rate for applicable benefits	0.00%	0.00%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	2.35%	2.90%
Expected return on plan assets	3.60%	4.10%
Rate of compensation increase	3.35%	3.65%
Interest crediting rate for applicable benefits	0.00%	0.00%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 326	$ 227
Unrecognized prior service cost (credit)	0	(2)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Amounts Recognized in the Consolidated Balance Sheet
Noncurrent assets	0	0
Current liabilities	(39)	(42)
Noncurrent liabilities	(131)	(174)
Total recognized	$ (170)	$ (216)
Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31
Discount rate	2.15%	3.10%
Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31
Discount rate	3.10%	4.05%
Before-tax amounts unrecognized in net periodic postretirement benefit cost
Unrecognized net actuarial loss (gain)	$ 14	$ 8
Unrecognized prior service cost (credit)	$ (182)	$ (183)

Employee Benefit Plans - Sources of Change in Other Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Sources of change in other comprehensive income (loss)
Net actuarial loss arising during the period	$ (210)	$ (55)	$ (150)
Amortization of (gain) loss included in income	117	146	279
Net actuarial gain, Before-tax	(93)	91	129
Prior service (cost) credit arising during the period	29	0	(7)
Amortization of prior service cost (credit) included in net loss	(32)	(35)	(40)
Net change during the period	(3)	(35)	$ (47)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Sources of change in other comprehensive income (loss)
Net actuarial loss arising during the period	(7)	(27)
Amortization of (gain) loss included in income	1	(2)
Net actuarial gain, Before-tax	(6)	(29)
Prior service (cost) credit arising during the period	30	0
Amortization of prior service cost (credit) included in net loss	(31)	(33)
Net change during the period	(1)	(33)
Pension Plans Defined Benefit [Member] \| US
Sources of change in other comprehensive income (loss)
Net actuarial loss arising during the period	(83)	(79)
Amortization of (gain) loss included in income	95	116
Net actuarial gain, Before-tax	12	37
Prior service (cost) credit arising during the period	0	0
Amortization of prior service cost (credit) included in net loss	0	0
Net change during the period	0	0
Pension Plans Defined Benefit [Member] \| Foreign Plan [Member]
Sources of change in other comprehensive income (loss)
Net actuarial loss arising during the period	(120)	51
Amortization of (gain) loss included in income	21	32
Net actuarial gain, Before-tax	(99)	83
Prior service (cost) credit arising during the period	(1)	0
Amortization of prior service cost (credit) included in net loss	(1)	(2)
Net change during the period	$ (2)	$ (2)

Employee Benefit Plans - Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Pension Plans Defined Benefit [Member] \| US
Net periodic benefit cost of all defined benefit plans
Service cost	$ 85	$ 79	$ 83
Interest cost	66	79	99
Expected return on plan assets	(85)	(74)	(114)
Amortization of prior service cost (credit)	0	0	0
Recognized net actuarial loss (gain)	51	54	53
Pension settlement losses	44	62	196
Net periodic benefit cost	161	200	317
Pension Plans Defined Benefit [Member] \| Foreign Plan [Member]
Net periodic benefit cost of all defined benefit plans
Service cost	54	69	81
Interest cost	85	97	107
Expected return on plan assets	(145)	(138)	(155)
Amortization of prior service cost (credit)	(1)	(2)	(5)
Recognized net actuarial loss (gain)	22	32	31
Pension settlement losses	(1)	0	0
Net periodic benefit cost	14	58	59
Other Postretirement Benefit Plans, Defined Benefit [Member]
Net periodic benefit cost of all defined benefit plans
Service cost	2	1	1
Interest cost	6	8	8
Expected return on plan assets	0	0	0
Amortization of prior service cost (credit)	(31)	(33)	(35)
Recognized net actuarial loss (gain)	1	(2)	(1)
Pension settlement losses	0	0	0
Net periodic benefit cost	$ (22)	$ (26)	$ (27)

Employee Benefit Plans - Benefit Cost Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Sep. 30, 2019	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Percent Amortized Of Unamortized Balance For Net Actuarial Gain And Losses		10.00%
Other Comprehensive Income (Loss), Defined Benefit Plans		$ 75	$ (51)	$ (39)
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension settlement losses		$ 0	$ 0	0
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate		2.15%	3.10%
US \| Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension settlement losses		$ (44)	$ (62)	(196)
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate		2.30%	3.25%
US \| Other Postretirement Benefit Plans, Defined Benefit [Member] \| Pre Sixty Five Retiree[Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year		7.00%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate		5.00%
US \| Other Postretirement Benefit Plans, Defined Benefit [Member] \| Post Sixty Five Retiree [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Health Care Cost Trend Rate Assumed for Next Fiscal Year		4.00%
Defined Benefit Plan, Ultimate Health Care Cost Trend Rate		5.00%
US \| Qualified Plan [Member] \| Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension settlement losses		$ (43)	$ (62)	(196)
Foreign Plan [Member] \| Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Pension settlement losses		$ 1	$ 0	$ 0
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate		1.80%	2.35%
Foreign Plan [Member] \| Qualified Plan [Member] \| Pension Plans Defined Benefit [Member] \| Certain United Kingdom Assets [Member]
Defined Benefit Plan Disclosure [Line Items]
Change In Defined Benefit Assets	$ 43
Defined Benefit Plan, Assumptions Used Calculating Benefit Obligation, Discount Rate	1.80%			2.90%

Employee Benefit Plans - Plan Asset Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Pension Plans Defined Benefit [Member] \| US
Defined Benefit Plan Disclosure [Line Items]
Accumulated benefit obligation	$ 2,359	$ 2,161
Defined Benefit Plan, Actual Return on Plan Assets	321	273
Insurance Contract Rights And Obligations Fair Value Option [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value Of Participating Interest In Annuity Contract	94	95
Insurance Contract Rights And Obligations Fair Value Option [Member] \| Fair Value Inputs Level 3 [Member] \| Pension Plans Defined Benefit [Member] \| US
Defined Benefit Plan Disclosure [Line Items]
Fair Value Of Participating Interest In Annuity Contract	94	95
Accumulated benefit obligation	$ 139	140
Defined Benefit Plan, Equity Securities [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets	28.00%
Defined Benefit Plan, Debt Security [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets	68.00%
Defined Benefit Plan, Debt Security [Member] \| Insurance Contract Rights And Obligations Fair Value Option [Member] \| Fair Value Inputs Level 3 [Member] \| Pension Plans Defined Benefit [Member] \| US
Defined Benefit Plan Disclosure [Line Items]
Fair Value Of Participating Interest In Annuity Contract	$ 233	$ 235
Defined Benefit Plan, Real Estate [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets	3.00%
Other Investments [Member]
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets	1.00%

Employee Benefit Plans - Fair values of pension plan assets (Parenthetical) (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019
Defined Benefit Plan Disclosure [Line Items]
Net payables related to security transactions	$ 7	$ 9
Insurance Contract Rights And Obligations Fair Value Option [Member]
Defined Benefit Plan Disclosure [Line Items]
Fair Value Of Participating Interest In Annuity Contract	$ 94	$ 95

Employee Benefit Plans - Funding Policy (Details) $ in Millions	Dec. 31, 2020 USD ($)
Foreign Plan [Member] \| Retirement Plan Tax Status [Domain]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	$ 75

Employee Benefit Plans - Benefit payments (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:
Compensation cost	$ 159	$ 274	$ 265
Tax benefit	40	$ 71	$ 64
Pension Plans Defined Benefit [Member] \| US
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:
2021	532
2022	289
2023	248
2024	232
2025	215
2026-2030	845
Pension Plans Defined Benefit [Member] \| Foreign Pension Plans, Defined Benefit [Member]
Benefit payments excluding the participating annuity contract and which reflect expected future service, as appropriate, are expected to be paid:
2021	147
2022	151
2023	156
2024	162
2025	166
2026-2030	897
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:
2021	25
2022	21
2023	18
2024	16
2025	14
2026-2030	$ 53

Employee Benefit Plans - Severances (Details) - Employee Severance [Member] - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Supplemental Unemployment Benefits [Line Items]
Balance at December 31, 2018	$ 23	$ 48	$ 53
Accruals	14	(1)	70
Benefit payments	(13)	(24)	(73)
Defined Benefit Plan, Foreign Currency Exchange Rate Changes, Benefit Obligation	0	0	(2)
Balance at December 31, 2019	24	$ 23	$ 48
Short term supplemental unemployment benefits [Member]
Supplemental Unemployment Benefits [Line Items]
Balance at December 31, 2019	$ 8

Employee Benefit Plans - Other Plan Narrative (Details) $ in Millions	12 Months Ended
	Dec. 31, 2020 USD ($) shares	Dec. 31, 2019 USD ($)	Dec. 31, 2018 USD ($)
Share-based Compensation Plan
Defined Benefit Plan Disclosure [Line Items]
Share Based Compensation Plan, number of shares authorized	79,000,000
Other Postretirement Benefit Plans, Defined Benefit [Member] \| Share-based Compensation Plan
Defined Benefit Plan Disclosure [Line Items]
Deferred Compensation Arrangement with Individual, Maximum Contractual Term	10 years
US
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan Maximum Annual Contributions Per Employee Percent	75.00%
Number Of Investment Funds In Which Employee Can Contribute [Member]	(17)
Defined Contribution Plan, Employer Matching Contribution, Percent	1.00%
Defined Contribution Plan Employer Matching Contribution Percent Of Match	6.00%
Employer Matching Discretionary Contribution Percent	6.00%
Company contributions charged to expense for defined contribution plan \| $	$ 62	$ 82	$ 82
US \| cop_IncentiveStockOptionsMember [Member]
Defined Benefit Plan Disclosure [Line Items]
Share Based Compensation Plan, number of shares authorized	40,000,000
US \| Company Retirement Contribution (CRC)
Defined Benefit Plan Disclosure [Line Items]
Defined Contribution Plan Employer Matching Contribution Percent Of Match	6.00%
Defined Contribution Plan Employers Vesting Period	3 years
Defined contribution plan employers vesting percent	100.00%
US \| Share-based Compensation Plan
Defined Benefit Plan Disclosure [Line Items]
Share Based Compensation Plan, number of shares authorized	79,000,000
Foreign Plan [Member]
Defined Benefit Plan Disclosure [Line Items]
Company contributions charged to expense for defined contribution plan \| $	$ 25	$ 30	$ 31

Employee Benefit Plans - Stock option activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Summary of Stock Options Activity
Weighted-Average Exercise Price at the beginning of year	$ 54.11
Weighted-Average Exercise Price, exercised	38.80
Weighted-Average Exercise Price, forfeited	49.76
Weighted-Average Exercise Price at the end of year	55.12	$ 54.11
Weighted-Average Exercise Price, Vested	55.12
Weighted-Average Exercise Price, Exercisable	$ 55.12
Aggregate Intrinsic Value, outstanding at the beginning of the year	$ 206
Aggregate Intrinsic Value, exercised	23
Aggregate Intrinsic Value, outstanding at the end of the year	22	$ 206
Aggregate Intrinsic Value, vested	22
Aggregate Intrinsic Value, exercisable	$ 22
Stock option, Outstanding at the beginning of year	18,040,197
Stock option, exercised	(1,111,805)
Stock option, forfeited	(5,867)
Stock option, expired or cancelled	0
Stock options, Outstanding at the end of year	16,922,525	18,040,197
Stock option, Vested	16,922,525
Stock option, Exercisable at End of Year	16,922,525
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Aggregate Intrinsic Value, exercised	$ 23
Employee Stock Option [Member] \| 2014 Omnibus Stock And Performance Incentive Plan Of ConocoPhillips [Member]
Summary of Stock Options Activity
Aggregate Intrinsic Value, exercised		$ 39	$ 94
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Weighted-average remaining contractual term of outstanding options	3 years 7 months 28 days
Aggregate Intrinsic Value, exercised		$ 39	$ 94
Cash received from exercise of stock options	$ 43
Tax benefit from exercise of options	$ 9

Employee Benefit Plans - Stock unit activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Summary of stock unit activity
Share-based Compensation Arrangement by Share-based Payment Award, Options, Vested and Expected to Vest, Exercisable, Number	16,922,525
RSU Stock Settled [Member]
Summary of stock unit activity
Stock Units, Outstanding Beginning of year	6,223,046
Stock Units, Granted	2,890,840
Stock Units, Forfeited / Cancelled	(127,181)
Stock Units, Issued	(2,554,720)
Stock Units, Outstanding End of year	6,431,985	6,223,046
Not Vested at End of Year	4,230,413
Weighted-Average Grant-Date Fair Value, beginning of year	$ 55.99
Weighted-Average Grant-Date Fair Value, Granted	57.40	$ 67.77	$ 52.45
Weighted-Average Grant-Date Fair Value, Forfeited / Cancelled	55.84
Weighted-Average Grant-Date Fair Value, Issued	50.16
Weighted-Average Grant-Date Fair Value, ending of year	58.94	$ 55.99
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 59.01
Total Fair Value, Issued	$ 143	$ 225	$ 154
Employee Benefit Plans Additional (Textual) [Abstract]
Unrecognized compensation cost from stock options	$ 101
Weighted average period of recognition of unvested options, in months	1 year 8 months 15 days
Longest weighted-average period of recognition of unvested options, in months	2 years 1 month 20 days
Total Fair Value, Issued	$ 143	$ 225	$ 154
RSU Cash Settled [Member]
Summary of stock unit activity
Stock Units, Outstanding Beginning of year	596,991
Stock Units, Granted	24,437
Stock Units, Forfeited / Cancelled	(5,622)
Stock Units, Issued	(1,191)
Stock Units, Outstanding End of year	614,615	596,991
Not Vested at End of Year	121,696
Weighted-Average Grant-Date Fair Value, beginning of year	$ 64.54
Weighted-Average Grant-Date Fair Value, Granted	41.59	$ 68.20	$ 53.68
Weighted-Average Grant-Date Fair Value, Forfeited / Cancelled	40.01
Weighted-Average Grant-Date Fair Value, Issued	40.20
Weighted-Average Grant-Date Fair Value, ending of year	39.95	$ 64.54
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 39.95
Total Fair Value, Issued	$ 0	$ 6	$ 1
Employee Benefit Plans Additional (Textual) [Abstract]
Unrecognized compensation cost from stock options	$ 1
Weighted average period of recognition of unvested options, in months	1 year
Longest weighted-average period of recognition of unvested options, in months	1 year 1 month 13 days
Total Fair Value, Issued	$ 0	$ 6	$ 1

Employee Benefit Plans - Performance share activity (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
PSU Stock Settled [Member]
Summary of Performance Share Program activity
Stock Units, Outstanding Beginning of year	2,024,824
Stock Units, Granted	26,244
Stock Units, Forfeited / Cancelled	0
Stock Units, Issued	(314,340)
Stock Units, Outstanding End of year	1,736,728	2,024,824
Not Vested at End of Year	3,191
Weighted-Average Grant-Date Fair Value, beginning of year	$ 50.55
Weighted-Average Grant-Date Fair Value, Granted	58.61	$ 68.90	$ 53.28
Weighted-Average Grant-Date Fair Value, Issued	51.15
Weighted-Average Grant-Date Fair Value, ending of year	50.56	$ 50.55
Weighted-Average Grant-Date Fair Value Not Vested, ending of year	$ 48.61
Total Fair Value, Issued	$ 13,000,000	$ 25,000,000	$ 29,000,000
Employee Benefit Plans Additional (Textual) [Abstract]
Unrecognized compensation cost from stock options	0
Total Fair Value, Issued	$ 13,000,000	$ 25,000,000	$ 29,000,000
PSU Cash Settled [Member]
Summary of Performance Share Program activity
Stock Units, Outstanding Beginning of year	609,274
Stock Units, Granted	1,491,098
Stock Units, Forfeited / Cancelled	0
Stock Units, Issued	(1,975,843)
Stock Units, Outstanding End of year	124,529	609,274
Weighted-Average Grant-Date Fair Value, beginning of year	$ 64.54
Weighted-Average Grant-Date Fair Value, Granted	58.61	$ 68.90	$ 53.28
Weighted-Average Grant-Date Fair Value, Issued	58.54
Weighted-Average Grant-Date Fair Value, ending of year	$ 39.95	$ 64.54
Total Fair Value, Issued	$ 116,000,000	$ 171,000,000	$ 22,000,000
Employee Benefit Plans Additional (Textual) [Abstract]
Unrecognized compensation cost from stock options	0
Total Fair Value, Issued	$ 116,000,000	$ 171,000,000	$ 22,000,000

Employee Benefit Plans - Restricted shares and units (Details) - Restricted Stock Units (RSUs) [Member] - Discontinued Operations [Member] - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Summary of aggregate activity of restricted shares and units
Stock Units, Outstanding Beginning of year	991,908
Stock Units, Granted	77,824
Stock Units, Forfeited / Cancelled	(1,336)
Stock Units, Issued	(98,297)
Stock Units, Outstanding End of year	970,099	991,908
Weighted-Average Grant-Date Fair Value, beginning of year	$ 47.24
Weighted-Average Grant-Date Fair Value, Granted	51.46	$ 63.58	$ 62.01
Weighted-Average Grant-Date Fair Value, Forfeited / Cancelled	23.09
Weighted-Average Grant-Date Fair Value, Issued	45.57
Weighted-Average Grant-Date Fair Value, ending of year	$ 47.78	$ 47.24
Total Fair Value, Issued	$ 6,000,000	$ 11,000,000	$ 17,000,000
Employee Benefit Plans Additional (Textual) [Abstract]
Unrecognized compensation cost from stock options	0
Total Fair Value, Issued	$ 6,000,000	$ 11,000,000	$ 17,000,000

Employee Benefits Plans (Textual) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plan Disclosure [Line Items]
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	$ (29)	$ 0	$ 7
Other Postretirement Benefit Plans, Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements	0	0	0
Defined Benefit Plan Special Termination Benefits	0	0
Defined Benefit Plan, Actual Return on Plan Assets	0	0
Defined Benefit Plan, Plan Amendments	(30)	0
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	(30)	0
US
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Estimated Future Employer Contributions in Next Fiscal Year	265
US \| Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements	(44)	(62)	(196)
Defined Benefit Plan Special Termination Benefits	0	0
Defined Benefit Plan, Actual Return on Plan Assets	321	273
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Accumulated Benefit Obligation	2,359	2,161
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets	1,770	1,591
Defined Benefit Plan, Plan Amendments	0	0
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	0	0
US \| Qualified Plan [Member] \| Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements	(43)	(62)	(196)
Foreign Plan [Member] \| Pension Plans Defined Benefit [Member]
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Recognized Net Gain (Loss) Due to Settlements	1	0	$ 0
Defined Benefit Plan Special Termination Benefits	3	1
Defined Benefit Plan, Actual Return on Plan Assets	416	529
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Accumulated Benefit Obligation	338	299
Defined Benefit Plan, Plan with Accumulated Benefit Obligation in Excess of Plan Assets, Plan Assets	35	44
Defined Benefit Plan, Plan Amendments	2	0
Other Comprehensive Income, Defined Benefit Plan, Net Prior Service Cost (Credit) Arising During Period, before Tax	$ 1	$ 0

Employee Benefits Plans (Textual 1) (Details) - Share-based Compensation Plan	12 Months Ended
	Dec. 31, 2020
Employee Stock Option [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Stock Options Terms of Award	Stock options granted under the provisions of the Plan and prior plans permit purchase of our common stock at exercise prices equivalent to the average fair market value 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. Beginning in 2018, stock option grants were discontinued and replaced with three-year, time-vested restricted stock units which generally will be cash-settled
Restricted Stock Units (RSUs) [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Stock Options Terms of Award	Generally, restricted stock units are granted annually under the provisions of the Plan and vest in an aggregate installment on the third anniversary of the grant date. In addition, restricted stock units granted under the Plan for a variable long-term incentive program vest ratably in three equal annual installments beginning on the first anniversary of the grant date. Restricted stock units are also granted ad hoc to attract or retain key personnel, and the terms and conditions under which these restricted stock units vest vary by award
RSU Stock Settled [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Stock Options Terms of Award	Upon vesting, these restricted stock units are settled by issuing one share of ConocoPhillips common stock per unit. Units awarded to retirement eligible employees vest six months from the grant date; however, those units are not issued as common stock until the earlier of separation from the company or the end of the regularly scheduled vesting period. Until issued as stock, most recipients of the restricted stock units receive a cash payment of a dividend equivalent that is charged to retained earnings. Executive recipients receive an accrued reinvested dividend equivalent, subject to the terms and conditions of the award, that is charged to retained earnings. The grant date fair market value of these restricted stock units is deemed equal to the average ConocoPhillips stock price on the grant date. The grant date fair market value of units that do not receive a dividend equivalent while unvested is deemed equal to the average ConocoPhillips stock price on the grant date, less the net present value of the dividends that will not be received
RSU Cash Settled [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Stock Options Terms of Award	Cash settled executive restricted stock units granted in 2018 and 2019 replaced the stock option program. These restricted stock units, subject to elections to defer, 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. Units awarded to retirement eligible employees vest six months from the grant date; however, those units are not settled until the earlier of separation from the company or the end of the regularly scheduled vesting 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 settlement date. Recipients receive an accrued reinvested dividend equivalent that is charged to compensation expense. The accrued reinvested dividend is paid at the time of settlement, subject to the terms and conditions of the award. Beginning with executive restricted stock units granted in 2020 awards will be settled in stock.
PSU Stock Settled [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Stock Options Terms of Award	For performance periods beginning before 2009, PSUs do not vest until the employee becomes eligible for retirement by reaching age 55 with five years of service, and restrictions do not lapse until the employee separates from the company. With respect to awards for performance periods beginning in 2009 through 2012, PSUs do not vest until the earlier of the date the employee becomes eligible for retirement by reaching age 55 with five years of service or five years after the grant date of the award, and restrictions do not lapse until the earlier of the employee’s separation from the company or five years after the grant date (although recipients can elect to defer the lapsing of restrictions until separation). We recognize compensation expense for these awards beginning on the grant date and ending on the date the PSUs are scheduled to vest. Since these awards are authorized three years prior to the grant date, for employees eligible for retirement by or shortly after the grant date, we recognize compensation expense over the period beginning on the date of authorization and ending on the date of grant. Until issued as stock, recipients of the PSUs receive a quarterly cash payment of a dividend equivalent that is charged to retained earnings. Beginning in 2013, PSUs authorized for future grants will vest, absent employee election to defer, upon settlement following the conclusion of the three-year performance period. We recognize compensation expense over the period beginning on the date of authorization and ending on the conclusion of the performance period. PSUs are settled by issuing one share of ConocoPhillips common stock per unit.
PSU Cash Settled [Member]
Employee Benefit Plans Additional (Textual) [Abstract]
Stock Options Terms of Award	Beginning in February 2014, initial target PSU awards are issued near the beginning of new performance periods. These initial target PSU awards will terminate at the end of the performance periods and will be settled after the performance periods have ended. Also in 2014, initial target PSU awards were issued for open performance periods that began in prior years. For the open performance period beginning in 2012, the initial target PSU awards terminated at the end of the three-year performance period and were replaced with approved PSU awards. For the open performance period beginning in 2013, the initial target PSU awards terminated at the end of the three-year performance period and were settled after the performance period ended.

Income Taxes - Components of provision (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Federal
Current	$ 3	$ 18	$ 4
Deferred	(625)	(113)	545
Foreign
Current	350	2,545	3,273
Deferred	(70)	(323)	(166)
State and local
Current	(4)	148	108
Deferred	(139)	(8)	(96)
Total provision (benefit) for income taxes	$ (485)	$ 2,267	$ 3,668

Income Taxes - Components of deferred tax liabilties and assets (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 02, 2019	Dec. 31, 2018	Dec. 31, 2017
Deferred Tax Liabilities
Properties, plants and equipment, and intangibles	$ 7,744	$ 8,660
Inventory	64	35
Other	242	234
Total deferred tax liabilities	8,050	8,929
Deferred Tax Assets
Benefit plan accruals	540	542
Asset retirement obligations and accrued environmental costs	2,262	2,339
Investments in joint ventures (Asset)	1,653	1,722
Other financial accruals and deferrals	907	777
Loss and credit carryforwards	8,904	8,968
Other	365	345
Total deferred tax assets	14,631	14,693
Less valuation allowance	(9,965)	(10,214)		$ (3,040)	$ (1,254)
Net deferred tax assets	4,666	4,479	$ 151
Total deferred tax liabilities	$ 3,384	$ 4,450

Income Taxes - Carryforwards (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 02, 2019
Income Taxes [Abstract]
U.S. foreign tax credits	$ 7,000		$ 6,642
Total loss and credit carryforwards	$ 8,904	$ 8,968

Income Taxes - Reconciliation of Deferred Tax Asset Valuation Allowance (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Taxes [Abstract]
Beginning balance	$ 10,214	$ 3,040	$ 1,254
Deferred Tax Asset, Valuation Allowance, Charged To Expense	460	(225)	(26)
Deferred Tax Assets, Valuation Allowance, Other	(709)	7,399	1,812
Ending balance	$ 9,965	$ 10,214	$ 3,040

Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Reconciliation of the beginning and ending unrecognized tax benefits
Unrecognized Tax Benefits, Balance at January 1	$ 1,177	$ 1,081	$ 882
Additions based on tax positions related to the current year	6	9	268
Additions for tax positions of prior years	67	120	43
Reductions for tax positions of prior years	(34)	(22)	(73)
Settlements	(9)	(9)	(35)
Lapse of statute	(1)	(2)	(4)
Unrecognized Tax Benefits, Balance at December 31	$ 1,206	$ 1,177	$ 1,081

Income Taxes - U.S. and foreign income (loss) from continuing operations before income taxes (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Income Taxes [Abstract]
Income (loss) before taxes - United States	$ (3,587)	$ 4,704	$ 2,867
Income Loss Before Income Taxes Foreign	447	4,820	7,106
Income (loss) before income taxes	(3,140)	9,524	9,973
Federal statutory income tax	(659)	2,000	2,095
Non-U.S. effective tax rates	194	1,399	1,766
Tax Legislation	0	0	(10)
Australia disposition	(349)	0	0
U.K. disposition	0	(732)	(150)
Recovery of outside basis	(22)	(77)	(21)
Adjustment to tax reserves, amount	18	9	(4)
Adjustment to valuation allowances	460	(225)	(26)
State income tax	(112)	123	135
Enhanded oil recovery credit	(6)	(27)	(99)
Malaysia Deepwater TaxCredits Incentive	0	(164)	0
Other	(9)	(39)	(18)
Total provision (benefit) for income taxes	$ (485)	$ 2,267	$ 3,668
Income (loss) before income taxes, United States, Percentage	114.20%	49.40%	28.70%
Income (loss) before income taxes, foreign, percentage	(14.20%)	50.60%	71.30%
Income (Loss) Before Income Taxes In Percent	100.00%	100.00%	100.00%
Federal statutory rate percentage	21.00%	21.00%	21.00%
Tax legislation, percentage	0.00%	0.00%	(0.10%)
Canada disposition, percentage	11.10%	0.00%	0.00%
U.K. disposition, percentage	0.00%	(7.70%)	(1.50%)
Recovery of outside basis, percentage	0.70%	(0.80%)	(0.20%)
Adjustment to valuation allowances	(14.60%)	(2.40%)	(0.30%)
State income tax, percentage	3.60%	1.30%	1.40%
Enhanced oil recovery, percentage	0.20%	(0.30%)	(1.00%)
Other, percentage	0.30%	(0.40%)	(0.20%)
Adjustment to tax reserves, percentage	(0.60%)	0.10%	0.00%
Effective Income Tax Rate, Continuing Operations, percetage	15.50%	23.80%	36.80%
Malaysia Deepwater Tax Credits Incentive, Percentage	0.00%	(1.70%)	0.00%
Non US effective tax rates percentage	(6.20%)	14.70%	17.70%

Income Taxes - Textuals (Details) - USD ($) $ in Millions	3 Months Ended			12 Months Ended
Income Taxes - Textuals (Details) - USD ($) $ in Millions	Dec. 31, 2020	Sep. 30, 2020	Jun. 30, 2020	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018	Dec. 02, 2019
Income Tax Examination [Line Items]
Deferred taxes Included in long-term liabilities	$ 3,747			$ 3,747	$ 4,634
Increase (decrease) in valuation allowance	6,642
Deferred Tax Assets Net	4,666			4,666	4,479		$ 151
U.S. foreign tax credits	7,000			7,000			$ 6,642
Undistributed Earnings of Foreign Subsidiaries	3,982			3,982
Estimated Tax Payable On Undistributed Unremitted Foreign Income				199
Unrecognized tax benefits that if recognized, would affect effective tax rate	1,128			1,128	1,100	$ 1,081
Accrued liabilities for interest and penalties	46			46	42	45
Interest and penalties (benefiting) charging earnings				(4)	3	4
Tax Legislation				0	0	(10)
Adjustment to valuation allowances				460	(225)	(26)
Income Tax Expense (Benefit)				(485)	2,267	3,668
Income Tax Loss (Benefit) related to U.K. disposition				0	(732)	(150)
Malaysia Deepwater Tax Credits Incentive				0	164	$ 0
Reversal of deferred tax assets			$ 120
Decrease to our accrued income and other taxes liability			$ 124
BPs Kuparuk Assets [Member] \| ConocoPhillips [Member]
Income Tax Examination [Line Items]
Percent Sold						24.00%
Noncurrent Asset
Income Tax Examination [Line Items]
Deferred taxes Included in long-term assets	363			363	184
Noncurrent Liabilities
Income Tax Examination [Line Items]
Deferred taxes Included in long-term liabilities	3,747			3,747	4,634
Clair Field [Member]
Income Tax Examination [Line Items]
Gain (Loss) on Sale of Oil and Gas Property				1,700	$ 715
Income Tax Expense (Benefit)				(335)
Income Tax Loss (Benefit) related to U.K. disposition				285
Malaysia Deepwater Tax Credits Incentive		$ 164
Capital Loss Carryforward	2,100			2,100
Clair Field [Member] \| BPs Kuparuk Assets [Member] \| ConocoPhillips [Member]
Income Tax Examination [Line Items]
Percent Sold						16.50%
Certain Jurisdictions Outside Of Domestic [Member]
Income Tax Examination [Line Items]
U.S. foreign tax credits	$ 1,900			1,900
Australia-West [Member]
Income Tax Examination [Line Items]
Increase (decrease) in valuation allowance				178
Gain (Loss) on Sale of Oil and Gas Property				313
Gain on disposition				587
Income Tax Expense (Benefit)				(10)
Reversal of deferred tax assets				$ (92)

Accumulated Other Comprehensive Income (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Defined Benefit Plans, Beginning Balance	$ (350)	$ (361)	$ (400)
Other Comprehensive Income (Loss), Defined Benefit Plans	(75)	51	39
Defined Benefit Plans, Ending Balance	(425)	(350)	(361)
Net Unrealized Gain on Securities, Beginning Balance	0	0	(58)
Unrealized loss on securities, net of tax	2	0	0
Net Unrealized Gain on Securities, Ending Balance	2	0	0
Foreign Currency Translation, Beginning Balance	(5,007)	(5,702)	(5,060)
Other comprehensive income (loss), Foreign Currency Translation	212	695	(642)
Foreign Currency Translation, Ending Balance	(4,795)	(5,007)	(5,702)
Accumulated Other Comprehensive Income (loss), Beginning Balance	(5,357)	(6,063)	(5,518)
Other comprehensive income (loss), net of tax	139	746	(603)
Accumulated Other Comprehensive Income (loss), Ending Balance	$ (5,218)	(5,357)	(6,063)
ASU 2016-01 Accounting for Cenovus Shares [Member] \| Restatement Adjustment [Member]
Other comprehensive income (loss), net of tax			$ 58
ASU 2018-02 [Member]
Other Comprehensive Income (Loss), Defined Benefit Plans		(40)
Other comprehensive income (loss), net of tax		$ (40)

Accumulated Other Comprehensive Income Textual (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Other comprehensive income (loss), Foreign Currency Translation	$ 212	$ 695	$ (642)
U.K. Subsidiaries [Member]
Other comprehensive income (loss), Foreign Currency Translation		$ 483

Accumulated Other Comprehensive Income - Reclassifications out of other comprehensive income (loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Other Comprehensive (Income) Loss Reclassification Adjustment From AOCI Pension And Other Postretirement Benefit Plans, Net Of Tax	$ 72	$ 88
Other Comprehensive (Income) Loss Reclassification Adjustment From AOCI Pension And Other Postretirement Benefit Plans, Tax	$ 13	$ 23

Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
Cash Flow Information (Details) - USD ($) $ in Millions	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Cash Flow, Noncash Investing and Financing Activities Disclosure [Abstract]
Increase in PP&E related to increase in asset retirement obligations	$ (116)	$ 205	$ 395
Interest Paid, Net	785	810	772
Income Taxes Paid, Net	905	2,905	2,976
Payments for (Proceeds from) Short-term Investments [Abstract]
Short-term investments purchased	(12,435)	(4,902)	(1,953)
Short-term investments sold	12,015	2,138	3,573
Long-term investments purchased	(325)	(146)	0
Investments and long-term receivables sold	87	0	0
Net Sales (Purchases) of Investments	658	2,910	(1,620)
Nonmonetary Transactions [Abstract]
Accounts receivable Acquired	0	0	(44)
Inventories Acquired	0	0	42
Investments Acquired	0	0	15
PPE Acquired	0	0	1,907
Other Long Term Assets Acquired	0	0	(9)
Accounts Payable	0	0	7
Accrued income and other taxes	$ 0	$ 0	$ 40

Cash Flow Information - Parenthetical (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Cash Flow Information [Abstract]
Discretionary payment to domestic qualified pension plan.	$ 324	$ 120
ConocoPhillips Vs Petroleos de Venezuela SA [Member]
Loss Contingencies [Line Items]
Cash Proceeds from Legal Settlements	$ 330	430
Burlington Resources Inc Vs The Republic Of Ecuador [Member]
Loss Contingencies [Line Items]
Cash Proceeds from Legal Settlements		$ 262

Other Financial Information (Details) - USD ($)

12 Months Ended

Dec. 31, 2020

Dec. 31, 2019

Dec. 31, 2018

Segment Reporting Information [Line Items]

Production and Operating Expenses

$ 4,344,000,000

$ 5,322,000,000

$ 5,213,000,000

(62,000,000)

58,000,000

(13,000,000)

Incurred

Debt

788,000,000

799,000,000

838,000,000

Interest Costs Incurred, Total

73,000,000

36,000,000

67,000,000

861,000,000

835,000,000

905,000,000

Capitalized

(55,000,000)

(57,000,000)

(170,000,000)

Expensed

806,000,000

778,000,000

735,000,000

Unrealized Gain (Loss) on Securities, before tax

100,000,000

166,000,000

97,000,000

^[1]

(855,000,000)

649,000,000

(437,000,000)

Other, net

246,000,000

543,000,000

513,000,000

Other Nonoperating Income (Expense)

(509,000,000)

1,358,000,000

173,000,000

Research and Development Expenditures - expensed

75,000,000

82,000,000

78,000,000

Shipping and Handling [Member]

Segment Reporting Information [Line Items]

Production and Operating Expenses

857,000,000

1,008,000,000

1,075,000,000

Corporate, Non-Segment [Member]

(31,000,000)

21,000,000

Incurred

Expensed

806,000,000

778,000,000

735,000,000

Alaska Segment [Member] | Operating Segments [Member]

88,000,000

149,000,000

80,000,000

Lower 48 Segment [Member] | Operating Segments [Member]

Canada Segment [Member] | Operating Segments [Member]

(7,000,000)

5,000,000

(11,000,000)

Europe and North Africa Segment [Member] | Operating Segments [Member]

Europe, Middle East, And North Africa [Member] | Operating Segments [Member]

5,000,000

11,000,000

12,000,000

Asia Pacific and Middle East Segment [Member] | Operating Segments [Member]

(15,000,000)

(26,000,000)

Asia Pacific [Member] | Operating Segments [Member]

7,000,000

6,000,000

5,000,000

Other International Segment [Member] | Operating Segments [Member]

(11,000,000)

31,000,000

3,000,000

2,000,000

1,000,000

Operating revenues and other income

$ 0

[1]	*See Note 6—Investment in Cenovus Energy, for additional information.

Other Financial Information - Property, Plant and Equipment (Details) - USD ($)	Dec. 31, 2020	Dec. 31, 2019
Properties, Plants And Equipment
Proved properties	$ 94,312,000,000	$ 88,284,000,000
Unproved properties	4,141,000,000	3,980,000,000
Other	3,653,000,000	5,482,000,000
Gross properties, plants and equipment	102,106,000,000	97,746,000,000
Accumulated depreciation	(62,213,000,000)	(55,477,000,000)
Property, Plant and Equipment, Net	$ 39,893,000,000	$ 42,269,000,000

Related Party Transactions (Details) - Affiliated Entity [Member] - USD ($)
$ in Millions

12 Months Ended

Dec. 31, 2020

Dec. 31, 2019

Dec. 31, 2018

$ 79

$ 89

$ 98

Purchases

Operating expenses and selling, general and administrative expenses

Net interest (income) expense *

^[1]

$ (5)

$ (13)

$ (14)

[1]	<div>*We paid interest to, or received interest from, various affiliates. See Note 6—Investments, Loans and Long-Term Receivables, for additional information on loans to affiliated companies.</div>

Sales and Other Operating Revenue - Transitional Arrangements (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Sales and Other Operating Revenue	$ 18,784,000,000	$ 32,567,000,000	$ 36,417,000,000
Contract with Customer, Timing of Satisfaction of Performance Obligation and Payment	We have entered into contractual arrangements where we license proprietary technology to customers related to the optimization process for operating LNG plants. The agreements typically provide for negotiated payments to be made at stated milestones. The payments are not directly related to our performance under the contract and are recorded as deferred revenue to be recognized as revenue when the customer can utilize and benefit from their right to use the license. Payments are received in installments over the construction period.
Accounting Standards Update 2014-09 [Member]
Sales and Other Operating Revenue	$ 13,662,000,000	$ 26,106,000,000	$ 28,098,000,000

Amount, excluding tax collected from customer, of revenue from satisfaction of performance obligation by transferring promised good or service to customer. Tax collected from customer is tax assessed by governmental authority that is both imposed on and concurrent with specific revenue-producing transaction, including, but not limited to, sales, use, value added and excise.

Reference 1: http://www.xbrl.org/2003/role/disclosureRef
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Sales and Other Operating Revenue - Practical Expedients (Details)	12 Months Ended
	Dec. 31, 2020
Revenue, Practical Expedient [Abstract]
Revenue, Practical Expedient, Initial Application and Transition, Nondisclosure of Transaction Price Allocation to Remaining Performance Obligation [true/false]	true
Revenue, Practical Expedient, Remaining Performance Obligation, Description	We have long-term commodity sales contracts which use prevailing market prices at the time of delivery, and under these contracts, the market-based variable consideration for each performance obligation (i.e., delivery of commodity) is allocated to each wholly unsatisfied performance obligation within the contract.

Sales and Other Operating Revenue - Revenue from Contracts With Customers (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Revenue from contracts with customers	$ 18,784,000,000	$ 32,567,000,000	$ 36,417,000,000
Revenue, Performance Obligation, Description of Payment Terms	Payment is typically due within 30 days or less.
Physical gas contracts [Member]
Revenue from contracts with customers	$ 5,177,000,000	6,558,000,000	8,218,000,000
Physical gas contracts [Member] \| Commodity [Member]
Revenue from contracts with customers	5,177,000,000	6,558,000,000	8,218,000,000
Crude oil product line [Member]
Revenue from contracts with customers	395,000,000	804,000,000	1,112,000,000
Natural Gas Product Line [Member]
Revenue from contracts with customers	4,339,000,000	5,313,000,000	6,734,000,000
Other Products [Member]
Revenue from contracts with customers	443,000,000	441,000,000	372,000,000
Financial Derivative Contracts [Member]
Revenue from contracts with customers	(55,000,000)	(97,000,000)	101,000,000
Lower 48 Segment [Member]
Revenue from contracts with customers	9,872,000,000	15,514,000,000	17,029,000,000
Lower 48 Segment [Member] \| Physical gas contracts [Member]
Revenue from contracts with customers	3,966,000,000	4,989,000,000	6,358,000,000
Canada Segment [Member]
Revenue from contracts with customers	1,666,000,000	2,910,000,000	3,184,000,000
Canada Segment [Member] \| Physical gas contracts [Member]
Revenue from contracts with customers	727,000,000	691,000,000	629,000,000
Europe and North Africa Segment [Member] \| Physical gas contracts [Member]
Revenue from contracts with customers	484,000,000	878,000,000	1,231,000,000
Europe, Middle East, And North Africa [Member]
Revenue from contracts with customers	1,917,000,000	5,101,000,000	6,635,000,000
Accounting Standards Update 2014-09 [Member]
Revenue from contracts with customers	$ 13,662,000,000	$ 26,106,000,000	$ 28,098,000,000

Sales and Other Operating Revenue - Receivables and Contract Liabilities (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019
Accounts Receivable, Net	$ 1,827	$ 2,372
Revenue, Performance Obligation, Description of Payment Terms	Payment is typically due within 30 days or less.
Revenue, Performance Obligation, Description of Timing	We typically receive payment within 30 days or less (depending on the terms of the invoice) once delivery is made.
Contract with Customer, Timing of Satisfaction of Performance Obligation and Payment	We have entered into contractual arrangements where we license proprietary technology to customers related to the optimization process for operating LNG plants. The agreements typically provide for negotiated payments to be made at stated milestones. The payments are not directly related to our performance under the contract and are recorded as deferred revenue to be recognized as revenue when the customer can utilize and benefit from their right to use the license. Payments are received in installments over the construction period.
Contract with Customer, Liability [Abstract]
Contract with Customer, Liability Beginning Balance	$ 80
Contract with Customer, Liability, Cash Received	17
Contract with Customer, Liability Ending Balance	$ 97
Change in Contract with Customer, Liability [Abstract]
Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Explanation	We expect to recognize the contract liabilities as of December 31, 2020, as revenue during 2021 and 2022.
Current liabilities	$ 56
Noncurrent liabilities	$ 41

Segment Disclosures - Analysis of Results by Operating Segment (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	$ 18,784,000,000	$ 32,567,000,000	$ 36,417,000,000
Corporate, Non-Segment [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	18,000,000	221,000,000	168,000,000
Alaska Segment [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	3,408,000,000	5,483,000,000	5,740,000,000
Alaska Segment [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	3,397,000,000	5,483,000,000	5,740,000,000
Alaska Segment [Member] \| Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	(11,000,000)	0	0
Lower 48 Segment [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	9,872,000,000	15,514,000,000	17,029,000,000
Lower 48 Segment [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	9,821,000,000	15,468,000,000	16,989,000,000
Lower 48 Segment [Member] \| Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	(51,000,000)	(46,000,000)	(40,000,000)
Canada Segment [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	1,666,000,000	2,910,000,000	3,184,000,000
Canada Segment [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	1,261,000,000	1,769,000,000	2,024,000,000
Canada Segment [Member] \| Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	(405,000,000)	(1,141,000,000)	(1,160,000,000)
Europe and North Africa Segment [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	1,919,000,000	5,101,000,000	6,635,000,000
Europe, Middle East, And North Africa [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	1,917,000,000	5,101,000,000	6,635,000,000
Europe, Middle East, And North Africa [Member] \| Intersegment Elimination [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	(2,000,000)	0	0
Asia Pacific and Middle East [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	2,363,000,000	4,525,000,000	4,861,000,000
Other International Segment [Member] \| Operating Segments [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	$ 7,000,000	$ 0	$ 0

Segment Disclosures - Depreciation, Equity Earnings, Income Tax (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	$ 6,334,000,000	$ 6,495,000,000	$ 5,983,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	432,000,000	779,000,000	1,074,000,000
Income Taxes
Total provision (benefit) for income taxes	(485,000,000)	2,267,000,000	3,668,000,000
Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	6,334,000,000	6,495,000,000	5,983,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	432,000,000	779,000,000	1,074,000,000
Corporate, Non-Segment [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	54,000,000	62,000,000	106,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	0	0	0
Income Taxes
Total provision (benefit) for income taxes	(76,000,000)	(233,000,000)	(103,000,000)
Alaska Segment [Member] \| Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	996,000,000	805,000,000	760,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	(7,000,000)	7,000,000	6,000,000
Income Taxes
Total provision (benefit) for income taxes	(256,000,000)	472,000,000	376,000,000
Lower 48 Segment [Member] \| Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	3,358,000,000	3,224,000,000	2,370,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	(11,000,000)	(159,000,000)	1,000,000
Income Taxes
Total provision (benefit) for income taxes	(378,000,000)	137,000,000	474,000,000
Canada Segment [Member] \| Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	342,000,000	232,000,000	324,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	0	0	0
Income Taxes
Total provision (benefit) for income taxes	(185,000,000)	(43,000,000)	(96,000,000)
Europe and North Africa Segment [Member] \| Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	775,000,000	887,000,000	1,041,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	311,000,000	470,000,000	744,000,000
Income Taxes
Total provision (benefit) for income taxes	136,000,000	1,425,000,000	2,259,000,000
Asia Pacific and Middle East Segment [Member] \| Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	809,000,000	1,285,000,000	1,382,000,000
Equity in Earnings of Affiliates
Equity in earnings of affiliates	137,000,000	461,000,000	323,000,000
Income Taxes
Total provision (benefit) for income taxes	294,000,000	501,000,000	728,000,000
Other International Segment [Member] \| Operating Segments [Member]
Depreciation, Depletion, Amortization, and Impairments
DD&A and Impairments	0	0	0
Equity in Earnings of Affiliates
Equity in earnings of affiliates	2,000,000	0	0
Income Taxes
Total provision (benefit) for income taxes	$ (20,000,000)	$ 8,000,000	$ 30,000,000

Segment Disclosures - Net Income (Loss), Investments, Total Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	$ (2,701)	$ 7,189	$ 6,257
Investments In and Advances To Affiliates
Investments in and advances to affiliates	7,710	8,453	9,340
Total Assets
Total assets	62,618	70,514	69,980
Corporate, Non-Segment [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	(1,880)	38	(1,667)
Investments In and Advances To Affiliates
Investments in and advances to affiliates	0	0	0
Total Assets
Total assets	8,987	11,164	8,573
Alaska Segment [Member] \| Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	(719)	1,520	1,814
Investments In and Advances To Affiliates
Investments in and advances to affiliates	62	83	86
Total Assets
Total assets	14,623	15,453	14,648
Lower 48 Segment [Member] \| Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	(1,122)	436	1,747
Investments In and Advances To Affiliates
Investments in and advances to affiliates	25	35	378
Total Assets
Total assets	11,932	14,425	14,888
Canada Segment [Member] \| Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	(326)	279	63
Investments In and Advances To Affiliates
Investments in and advances to affiliates	0	0	0
Total Assets
Total assets	6,863	6,350	5,748
Europe and North Africa Segment [Member] \| Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	448	3,170	2,594
Investments In and Advances To Affiliates
Investments in and advances to affiliates	918	1,070	1,311
Total Assets
Total assets	8,756	9,269	11,276
Asia Pacific and Middle East Segment [Member] \| Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	962	1,483	1,342
Investments In and Advances To Affiliates
Investments in and advances to affiliates	6,705	7,265	7,565
Total Assets
Total assets	11,231	13,568	14,758
Other International Segment [Member] \| Operating Segments [Member]
Net Income (Loss) Attributable to ConocoPhillips
Net income (loss) attributable to ConocoPhillips	(64)	263	364
Investments In and Advances To Affiliates
Investments in and advances to affiliates	0	0	0
Total Assets
Total assets	$ 226	$ 285	$ 89

Segment Disclosures - Capital Expenditures and Interest (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Capital Expenditures and Investments
Consolidated capital expenditures and investments	$ 4,715	$ 6,636	$ 6,750
Interest Income and Expense
Interest income	100	166	97
Interest and debt expense	806	778	735
Corporate, Non-Segment [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	40	61	190
Interest Income and Expense
Interest income	88	149	80
Interest and debt expense	806	778	735
Alaska Segment [Member] \| Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	1,038	1,513	1,298
Interest Income and Expense
Interest income	0	0	0
Lower 48 Segment [Member] \| Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	1,881	3,394	3,184
Interest Income and Expense
Interest income	0	0	0
Canada Segment [Member] \| Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	651	368	477
Interest Income and Expense
Interest income	0	0	0
Europe and North Africa Segment [Member] \| Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	600	708	877
Interest Income and Expense
Interest income	5	11	12
Asia Pacific and Middle East Segment [Member] \| Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	384	584	718
Interest Income and Expense
Interest income	7	6	5
Other International Segment [Member] \| Operating Segments [Member]
Capital Expenditures and Investments
Consolidated capital expenditures and investments	121	8	6
Interest Income and Expense
Interest income	$ 0	$ 0	$ 0

Segment Disclosures - Sales by Product (Details) - USD ($)	12 Months Ended
	Dec. 31, 2020	Dec. 31, 2019	Dec. 31, 2018
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	$ 18,784,000,000	$ 32,567,000,000	$ 36,417,000,000
Natural Gas [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	6,427,000,000	8,715,000,000	10,720,000,000
Natural Gas Liquids [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	528,000,000	814,000,000	1,114,000,000
Crude Oil [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	9,736,000,000	18,482,000,000	19,571,000,000
Other Products [Member]
Segment Reporting Information [Line Items]
Sales and Other Operating Revenue	$ 2,093,000,000	$ 4,556,000,000	$ 5,012,000,000

Segment Disclosures - Geographic Information (Details) - USD ($)

12 Months Ended

Dec. 31, 2020

Dec. 31, 2019

Dec. 31, 2018

$ 18,784,000,000

$ 32,567,000,000

$ 36,417,000,000

^[1]

47,603,000,000

50,722,000,000

55,038,000,000

13,230,000,000

21,159,000,000

22,740,000,000

Australia and Timor-Leste

^[1]

24,034,000,000

^[2]

26,566,000,000

26,838,000,000

605,000,000

1,647,000,000

1,798,000,000

^[1]

6,676,000,000

^[3]

7,228,000,000

9,301,000,000

Canada [Member]

1,261,000,000

1,769,000,000

2,024,000,000

^[1]

6,385,000,000

5,769,000,000

5,333,000,000

CHINA

460,000,000

772,000,000

836,000,000

^[1]

1,491,000,000

1,447,000,000

1,380,000,000

INDONESIA

689,000,000

875,000,000

886,000,000

^[1]

464,000,000

605,000,000

669,000,000

Libya

155,000,000

1,103,000,000

1,142,000,000

^[1]

670,000,000

668,000,000

679,000,000

MALAYSIA

610,000,000

1,230,000,000

1,346,000,000

^[1]

1,501,000,000

1,871,000,000

2,327,000,000

NORWAY

1,426,000,000

2,349,000,000

2,886,000,000

^[1]

5,294,000,000

5,258,000,000

5,582,000,000

UNITED KINGDOM

336,000,000

1,649,000,000

2,606,000,000

Segment Geographical Groups of Countries Other [Member]

^[1]

1,000,000

2,000,000

1,583,000,000

12,000,000

14,000,000

153,000,000