ConocoPhillips (COP) 10-K 16 Feb 23 2022 FY Annual report Financial data

Cover

Cover - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2022	Jan. 31, 2023	Jun. 30, 2022
Entity Listings [Line Items]
Document Type	10-K
Document Annual Report	true
Document Period End Date	Dec. 31, 2022
Document Transition Report	false
Entity File Number	001-32395
Entity Registrant Name	ConocoPhillips
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	01-0562944
Entity Address, Address Line One	925 N. Eldridge Parkway
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77079
City Area Code	281
Local Phone Number	293-1000
Entity Well-known Seasoned Issuer	Yes
Entity Voluntary Filers	No
Entity Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
ICFR Auditor Attestation Flag	true
Entity Shell Company	false
Entity Public Float			$ 114.2
Entity Common Stock, Shares Outstanding		1,218,776,494
Documents Incorporated by Reference	Documents incorporated by reference: Portions of the Proxy Statement for the Annual Meeting of Stockholders to be held on May 16, 2023 (Part III)
Amendment Flag	false
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	FY
Entity Central Index Key	0001163165
Current Fiscal Year End Date	--12-31
Common Stock, $.01 Par Value
Entity Listings [Line Items]
Title of 12(b) Security	Common Stock, $.01 Par Value
Trading Symbol	COP
Security Exchange Name	NYSE
7% Debentures due 2029
Entity Listings [Line Items]
Title of 12(b) Security	7% Debentures due 2029
Trading Symbol	CUSIP—718507BK1
Security Exchange Name	NYSE

Audit Information

Audit Information	12 Months Ended
	Dec. 31, 2022
Audit Information [Abstract]
Auditor Name	Ernst & Young LLP
Auditor Location	Houston, Texas
Auditor Firm ID	42

Consolidated Income Statement

Consolidated Income Statement - USD ($) shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenues and Other Income
Sales and other operating revenues	$ 78,494	$ 45,828	$ 18,784
Equity in earnings of affiliates	2,081	832	432
Gain on dispositions	1,077	486	549
Other income (loss)	504	1,203	(509)
Total Revenues and Other Income	82,156	48,349	19,256
Costs and Expenses
Purchased commodities	33,971	18,158	8,078
Production and operating expenses	7,006	5,694	4,344
Selling, general and administrative expenses	623	719	430
Exploration expenses	564	344	1,457
Depreciation, depletion and amortization	7,504	7,208	5,521
Impairments	(12)	674	813
Taxes other than income taxes	3,364	1,634	754
Accretion on discounted liabilities	250	242	252
Interest and debt expense	805	884	806
Foreign currency transaction gains	(100)	(22)	(72)
Other expenses	(47)	102	13
Total Costs and Expenses	53,928	35,637	22,396
Income (loss) before income taxes	28,228	12,712	(3,140)
Income tax provision (benefit)	9,548	4,633	(485)
Net income (loss)	18,680	8,079	(2,655)
Less: net income attributable to noncontrolling interests	0	0	(46)
Net Income (Loss) Attributable to ConocoPhillips	$ 18,680	$ 8,079	$ (2,701)
Net Income (Loss) Attributable to ConocoPhillips Per Share of Common Stock (dollars)
Basic (in dollars per share)	$ 14.62	$ 6.09	$ (2.51)
Diluted (in dollars per share)	$ 14.57	$ 6.07	$ (2.51)
Average Common Shares Outstanding (in thousands)
Basic (in shares)	1,274,028	1,324,194	1,078,030
Diluted (in shares)	1,278,163	1,328,151	1,078,030

Consolidated Statement of Compr

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions		12 Months Ended
		Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Statement of Comprehensive Income [Abstract]
Net income (loss)		$ 18,680	$ 8,079	$ (2,655)
Defined benefit plans
Prior service (cost) credit arising during the period		(10)	0	29
Reclassification adjustment for amortization of prior service credit included in net income (loss)		(39)	(38)	(32)
Net change		(49)	(38)	(3)
Net actuarial gain (loss) arising during the period		(623)	357	(210)
Reclassification adjustment for amortization of net actuarial losses included in net income (loss)		72	178	117
Net change		(551)	535	(93)
Nonsponsored plans	[1]	5	5	1
Income taxes on defined benefit plans		178	(108)	20
Defined benefit plans, net of tax		(417)	394	(75)
Unrealized holding gain (loss) on securities		(13)	(2)	2
Reclassification adjustment for loss included in net income		(1)	(1)	0
Income taxes on unrealized holding loss on securities		3	1	0
Unrealized holding gain (loss) on securities, net of tax		(11)	(2)	2
Foreign currency translation adjustments		(623)	(124)	209
Income taxes on foreign currency translation adjustments		1	0	3
Foreign currency translation adjustments, net of tax		(622)	(124)	212
Other Comprehensive Income (Loss), Net of Tax		(1,050)	268	139
Comprehensive Income (Loss)		17,630	8,347	(2,516)
Less: comprehensive income attributable to noncontrolling interests		0	0	(46)
Comprehensive Income (Loss) Attributable to ConocoPhillips		$ 17,630	$ 8,347	$ (2,562)
[1]Plans for which ConocoPhillips is not the primary obligor—primarily those administered by equity affiliates.

Consolidated Balance Sheet

Consolidated Balance Sheet - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Assets
Cash and cash equivalents	$ 6,458	$ 5,028
Short-term investments	2,785	446
Accounts and notes receivable (net of allowance of $2 and $2, respectively)	7,075	6,543
Accounts and notes receivable—related parties	13	127
Investment in Cenovus Energy	0	1,117
Inventories	1,219	1,208
Prepaid expenses and other current assets	1,199	1,581
Total Current Assets	18,749	16,050
Investments and long-term receivables	8,225	7,113
Net properties, plants and equipment (net of accumulated DD&A of $66,630 and $64,735, respectively)	64,866	64,911
Other assets	1,989	2,587
Total Assets	93,829	90,661
Liabilities
Accounts payable	6,113	5,002
Accounts payable—related parties	50	23
Short-term debt	417	1,200
Accrued income and other taxes	3,193	2,862
Employee benefit obligations	728	755
Other accruals	2,346	2,179
Total Current Liabilities	12,847	12,021
Long-term debt	16,226	18,734
Asset retirement obligations and accrued environmental costs	6,401	5,754
Deferred income taxes	7,726	6,179
Employee benefit obligations	1,074	1,153
Other liabilities and deferred credits	1,552	1,414
Total Liabilities	45,826	45,255
Equity
Common stock (2,500,000,000 shares authorized at $0.01 par value) Issued (2022-2,100,885,134 shares; 2021-2,091,562,747 shares), Par value	21	21
Capital in excess of par	61,142	60,581
Treasury stock (at cost: 2022—877,029,062 shares; 2021—789,319,875 shares)	(60,189)	(50,920)
Accumulated other comprehensive loss	(6,000)	(4,950)
Retained earnings	53,029	40,674
Total Equity	48,003	45,406
Total Liabilities and Equity	$ 93,829	$ 90,661

Consolidated Balance Sheet (Par

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Allowance for accounts and notes receivable	$ 2	$ 2
Less: Accumulated depreciation, depletion and amortization	$ 66,630	$ 64,735
Common stock, shares authorized (in shares)	2,500,000,000	2,500,000,000
Common stock, par value (in dollars per share)	$ 0.01	$ 0.01
Common stock, shares issued (in shares)	2,100,885,134	2,091,562,747
Treasury stock, shares (in shares)	877,029,062	789,319,875

Consolidated Statement of Cash

Consolidated Statement of Cash Flows - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022		Dec. 31, 2021		Dec. 31, 2020
Cash Flows From Operating Activities
Net income (loss)	$ 18,680		$ 8,079		$ (2,655)
Adjustments to reconcile net income (loss) to net cash provided by operating activities
Depreciation, depletion and amortization	7,504		7,208		5,521
Impairments	(12)		674		813
Dry hole costs and leasehold impairments	340		44		1,083
Accretion on discounted liabilities	250		242		252
Deferred taxes	2,086		1,346		(834)
Undistributed equity earnings	942		446		645
Gain on dispositions	(1,077)		(486)		(549)
(Gain) loss on investment in Cenovus Energy	(251)		(1,040)		855
Other	86		(788)		43
Working capital adjustments
Decrease (increase) in accounts and notes receivable	(963)		(2,500)		521
Increase in inventories	(38)		(160)		(25)
Decrease (increase) in prepaid expenses and other current assets	(173)		(649)		76
Increase (decrease) in accounts payable	901		1,399		(249)
Increase (decrease) in taxes and other accruals	39		3,181		(695)
Net Cash Provided by Operating Activities	28,314		16,996		4,802
Cash Flows From Investing Activities
Capital expenditures and investments	(10,159)		(5,324)		(4,715)
Working capital changes associated with investing activities	520		134		(155)
Acquisition of businesses, net of cash acquired	(60)		(8,290)		0
Proceeds from asset dispositions	3,471		1,653		1,317
Net sales (purchases) of investments	(2,629)		3,091		(658)
Collection of advances/loans—related parties	114		105		116
Other	2		87		(26)
Net Cash Used in Investing Activities	(8,741)		(8,544)		(4,121)
Cash Flows From Financing Activities
Issuance of debt	2,897		0		300
Repayment of debt	(6,267)		(505)		(254)
Issuance of company common stock	362		145		(5)
Repurchase of company common stock	(9,270)		(3,623)		(892)
Dividends paid	(5,726)		(2,359)		(1,831)
Other	(49)		7		(26)
Net Cash Used in Financing Activities	(18,053)		(6,335)		(2,708)
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash	(224)		(34)		(20)
Net Change in Cash, Cash Equivalents and Restricted Cash	1,296		2,083		(2,047)
Cash, cash equivalents and restricted cash at beginning of period	5,398	[1]	3,315		5,362
Cash, Cash Equivalents and Restricted Cash at End of Period	$ 6,694	[2]	$ 5,398	[1]	$ 3,315
[1]Restricted cash of $152 million and $218 million is included in the “Prepaid expenses and other current assets” and “Other assets” lines, respectively, of our Consolidated Balance Sheet as of December 31, 2021.[2]Restricted cash of $236 million is included in the “ Other assets

Consolidated Statement of Cas_2

Consolidated Statement of Cash Flows (Parenthetical) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Restricted cash	$ 236
Restricted Cash, Statement of Financial Position [Extensible Enumeration]	Other Assets, Noncurrent
Prepaid expenses and other current assets
Restricted cash		$ 152
Other assets
Restricted cash		$ 218

Consolidated Statement of Chang

Consolidated Statement of Changes in Equity - USD ($) $ in Millions	Total	Par Value	Capital in Excess of Par	Treasury Stock	Accum. Other Comprehensive Income (Loss)	Retained Earnings	Non- Controlling Interests
Beginning Balance at Dec. 31, 2019	$ 35,050	$ 18	$ 46,983	$ (46,405)	$ (5,357)	$ 39,742	$ 69
Issued
Net income (loss)	(2,655)					(2,701)	46
Other comprehensive income (loss)	139				139
Dividends declared, ordinary	(1,831)					(1,831)
Repurchase of company common stock	(892)			(892)
Distributions to noncontrolling interests and other	(32)						(32)
Disposition	(84)						(84)
Distributed under benefit plans	150		150
Other	4					3	1
Ending Balance at Dec. 31, 2020	29,849	18	47,133	(47,297)	(5,218)	35,213	0
Issued
Net income (loss)	8,079					8,079
Other comprehensive income (loss)	268				268
Dividends declared, ordinary	(2,359)					(2,359)
Dividends declared - variable return of cash	(260)					(260)
Acquisition of Concho	13,125	3	13,122
Repurchase of company common stock	(3,623)			(3,623)
Distributed under benefit plans	326		326
Other	1					1
Ending Balance at Dec. 31, 2021	45,406	21	60,581	(50,920)	(4,950)	40,674	0
Issued
Net income (loss)	18,680					18,680
Other comprehensive income (loss)	(1,050)				(1,050)
Dividends declared, ordinary	(2,419)					(2,419)
Dividends declared - variable return of cash	(3,908)					(3,908)
Repurchase of company common stock	(9,270)			(9,270)
Distributed under benefit plans	561		561
Other	3			1		2
Ending Balance at Dec. 31, 2022	$ 48,003	$ 21	$ 61,142	$ (60,189)	$ (6,000)	$ 53,029	$ 0

Consolidated Statement of Cha_2

Consolidated Statement of Changes in Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Stockholders' Equity Note [Abstract]
Dividends declared, ordinary (in dollars per share)	$ 1.89	$ 1.75	$ 1.69
Dividends declared, variable return of cash (in dollars per share)	$ 3.10	$ 0.20

Accounting Policies

Accounting Policies	12 Months Ended
	Dec. 31, 2022
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, if applicable, 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. See Note . • 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 U.S. GAAP 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 of one year or less, 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 to 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 . 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 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 —Long-lived assets 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 for prices, volumes and future development plans. If 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 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. The expected future cash flows used for impairment reviews and related fair value calculations are based on estimated future production volumes, commodity prices, operating costs and capital decisions, 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. 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. • 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 partial 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. See Note . 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. • 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. • 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 (EPS) is calculated using the two-class method. Under the two-class method, all earnings (distributed and undistributed) are allocated to common stock (including fully vested stock and unit awards that have not yet been issued as common stock) and participating securities. ConocoPhillips grants RSUs under its share-based compensation programs, the majority of which entitle recipients to receive non-forfeitable dividends during the vesting period on a basis equivalent to dividends paid to holders of the Company’s common stock. See Note

Inventories

Inventories	12 Months Ended
	Dec. 31, 2022
Inventory Disclosure [Abstract]
Inventories	Note 2—Inventories Inventories at December 31 were: Millions of Dollars 2022 2021 Crude oil and natural gas $ 641 647 Materials and supplies 578 561 Total inventories $ 1,219 1,208 Inventories valued on the LIFO basis $ 396 395 The estimated excess of current replacement cost over LIFO cost of inventories was approximately $149 million and $251 million at December 31, 2022 and 2021, respectively.

Acquisitions and Dispositions

Acquisitions and Dispositions	12 Months Ended
	Dec. 31, 2022
Business Combination, Asset Acquisition And Dispositions [Abstract]
Acquisitions and Dispositions	Note 3—Acquisitions and Dispositions All gains or losses on asset dispositions are reported before-tax and are included net in the “ Gain on dispositions 2022 Acquisition of Additional Shareholding Interest in Australia Pacific LNG Pty Ltd (APLNG) In February 2022, we completed the acquisition of an additional 10 percent interest in APLNG from Origin Energy for approximately $1.4 billion, after customary adjustments, in an all-cash transaction resulting from the exercise of our preemption right. This increased our ownership in APLNG to 47.5 percent, with Origin Energy and Sinopec owning 27.5 percent and 25.0 percent, respectively. APLNG is reported as an equity investment in our Asia Pacific segment. Qatar Liquefied Gas Company Limited (8) (QG8) During 2022, we were awarded a 25 percent interest in a new joint venture (QG8) with QatarEnergy that will participate in the North Field East (NFE) LNG project. QG8 has a 12.5 percent interest in the NFE project and is reported as an equity method investment in our Europe, Middle East and North Africa segment. See Note . Asset Acquisition In September 2022, we completed the acquisition of an additional working interest in certain Eagle Ford acreage in the Lower 48 segment for cash consideration of $236 million after customary adjustments. This agreement was accounted for as an asset acquisition, with the consideration allocated primarily to PP&E. Assets Sold During 2022, we sold our interests in certain noncore assets in our Lower 48 segment for net proceeds of $680 million, with no gain or loss recognized on sale. At the time of disposition, our interest in these assets had a net carrying value of $680 million, consisting of $825 million of assets, primarily related to $818 million of PP&E, and $145 million of liabilities, primarily related to AROs. In March 2022, we completed the divestiture of our subsidiaries that held our Indonesia assets and operations, and based on an effective date of January 1, 2021, we received net proceeds of $731 million after customary adjustments and recognized a $534 million before-tax and $462 million after-tax gain related to this transaction. Together, the subsidiaries sold indirectly held our 54 percent interest in the Indonesia Corridor Block Production Sharing Contract (PSC) and 35 percent shareholding in the Transasia Pipeline Company. At the time of the disposition, the net carrying value was approximately $0.2 billion, excluding $0.2 billion of cash and restricted cash. The net book value consisted primarily of $0.3 billion of PP&E and $0.1 billion of ARO. The before-tax earnings associated with the subsidiaries sold, excluding the gain on disposition noted above, were $138 million and $604 million and $394 million for the years ended December 31, 2022, 2021 and 2020, respectively. Results of operations for the Indonesia interests sold were reported in our Asia Pacific segment. In 2022, we recorded contingent payments of $451 million relating to the previous dispositions of our interest in the Foster Creek Christina Lake Partnership and western Canada gas assets and our San Juan assets. The contingent payments are recorded as gain on disposition on our consolidated income statement and are reflected within our Canada and Lower 48 segments. In our Canada segment, the contingent payment, calculated and paid on a quarterly basis, is $6 million CAD for every $1 CAD by which the WCS quarterly average crude price exceeds $52 CAD per barrel. In our Lower 48 segment, the contingent payment, paid on an annual basis, is calculated monthly at $7 million per month in which the U.S. Henry Hub price is at or above $3.20 per MMBTU. The term of contingent payments in our Canada segment ended in the second quarter of 2022 and continues through 2023 for the Lower 48 segment. We recorded contingent payments of $369 million in 2021. No payments were recorded in 2020. 2021 During the year, we completed the acquisitions of Concho Resources Inc. (Concho) and of Shell Enterprises LLC’s (Shell) Permian assets. The acquisitions were accounted for as business combinations under FASB Topic ASC 805 using the acquisition method, which requires assets acquired and liabilities assumed to be measured at their acquisition date fair values. Fair value measurements were made for acquired assets and liabilities, and adjustments to those measurements may be made in subsequent periods, up to one year from the acquisition date as we identify new information about facts and circumstances that existed as of the acquisition date to consider. Acquisition of Concho Resources Inc. In January 2021, we completed our acquisition of Concho, an independent oil and gas exploration and production company with operations across New Mexico and West Texas focused in the Permian-based Delaware and Midland Basins. Total consideration for the all-stock transaction was valued at $13.1 billion, in which 1.46 shares of ConocoPhillips common stock were exchanged for each outstanding share of Concho common stock. 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. Oil and gas properties were valued using a discounted cash flow approach incorporating market participant and internally generated price assumptions; production profiles; and operating and development cost assumptions. Debt assumed in the acquisition was valued based on observable market prices. The fair values determined for accounts receivable, accounts payable, and most other current assets and current liabilities were equivalent to the carrying value due to their short-term nature. The total consideration of $13.1 billion was allocated to the identifiable assets and liabilities based on their fair values as of January 15, 2021. Assets Acquired Millions of Dollars Cash and cash equivalents $ 382 Accounts receivable, net 745 Inventories 45 Prepaid expenses and other current assets 37 Investments and long-term receivables 333 Net properties, plants and equipment 18,923 Other assets 62 Total assets acquired $ 20,527 Liabilities Assumed Accounts payable $ 638 Accrued income and other taxes 56 Employee benefit obligations 4 Other accruals 510 Long-term debt 4,696 Asset retirement obligations and accrued environmental costs 310 Deferred income taxes 1,071 Other liabilities and deferred credits 117 Total liabilities assumed $ 7,402 Net assets acquired $ 13,125 With the completion of the Concho transaction, we acquired proved and unproved properties of approximately $11.8 billion and $6.9 billion, respectively. We recognized approximately $157 million of transaction-related costs, all of which were expensed in the first quarter of 2021. These non-recurring costs related primarily to fees paid to advisors and the settlement of share-based awards for certain Concho employees based on the terms of the Merger Agreement. In the first quarter of 2021, we commenced a company-wide restructuring program, the scope of which included combining the operations of the two companies as well as other global restructuring activities. We recognized non-recurring restructuring costs mainly for employee severance and related incremental pension benefit costs. The impact from the transaction and restructuring costs to the lines of our consolidated income statement for the year ended December 31, 2021, are below: Millions of Dollars Transaction Cost Restructuring Cost Total Cost Production and operating expenses 128 128 Selling, general and administration expenses 135 67 202 Exploration expenses 18 8 26 Taxes other than income taxes 4 2 6 Other expenses — 29 29 $ 157 234 391 In February 2021, we completed a debt exchange offer related to the debt assumed from Concho. As a result of the debt exchange, we recognized an additional income tax-related restructuring charge of $75 million. From the acquisition date through December 31, 2021, “Total Revenues and Other Income” and “Net Income (Loss) Attributable to ConocoPhillips” associated with the acquired Concho business were approximately $6,571 million and $2,330 million, respectively. The results associated with the Concho business for the same period include a before- and after-tax loss of $305 million and $233 million, respectively, on the acquired derivative contracts. The before-tax loss is recorded within “Total Revenues and Other Income” on our consolidated income statement. See Note . Acquisition of Shell Permian Assets In December 2021, we completed our acquisition of Shell assets in the Permian based Delaware Basin. The accounting close date used for reporting purposes was December 31, 2021. Assets acquired include approximately 225,000 net acres and producing properties located entirely in Texas. Total consideration for the transaction was $8.6 billion. Oil and gas properties were valued using a discounted cash flow approach incorporating market participant and internally generated price assumptions, production profiles, and operating and development cost assumptions. The fair values determined for accounts receivable, accounts payable, and most other current assets and current liabilities were equivalent to the carrying value due to their short-term nature. The total consideration of $8.6 billion was allocated to the identifiable assets and liabilities based on their fair values at the acquisition date. Assets Acquired Millions of Dollars Accounts receivable, net $ 337 Inventories 20 Net properties, plants and equipment 8,582 Other assets 50 Total assets acquired $ 8,989 Liabilities Assumed Accounts payable $ 206 Accrued income and other taxes 6 Other accruals 20 Asset retirement obligations and accrued environmental costs 86 Other liabilities and deferred credits 36 Total liabilities assumed $ 354 Net assets acquired $ 8,635 With the completion of the Shell Permian transaction, we acquired proved and unproved properties of approximately $4.2 billion and $4.3 billion, respectively. We recognized approximately $44 million of transaction-related costs which were expensed in 2021. Supplemental Pro Forma (unaudited) The following tables summarize the unaudited supplemental pro forma financial information for the year ended December 31, 2021, and 2020, as if we had completed the acquisitions of Concho and the Shell Permian assets on January 1, 2020. Millions of Dollars Year Ended December 31, 2021 As reported Pro forma Pro forma Total Revenues and Other Income $ 48,349 3,220 51,569 Income (loss) before income taxes 12,712 1,201 13,913 Net Income (Loss) attributable to ConocoPhillips 8,079 920 8,999 Earnings per share: Basic net income $ 6.09 6.78 Diluted net income 6.07 6.76 Millions of Dollars Year Ended December 31, 2020 As reported Pro forma Pro forma Pro forma Total Revenues and Other Income $ 19,256 3,762 1,685 24,703 Income (loss) before income taxes (3,140) 787 (247) (2,600) Net Income (Loss) attributable to ConocoPhillips (2,701) 498 (189) (2,392) Earnings per share: Basic net loss $ (2.51) (1.75) Diluted net loss (2.51) (1.75) The unaudited supplemental pro forma financial information is presented for illustration purposes only and is not necessarily indicative of the operating results that would have occurred had the transactions been completed on January 1, 2020, nor is it necessarily indicative of future operating results of the combined entity. The unaudited pro forma financial information for the twelve-month period ending December 31, 2020 is a result of combining the consolidated income statement of ConocoPhillips with the results of Concho and the assets acquired from Shell. The pro forma results do not include transaction-related costs, nor any cost savings anticipated as a result of the transactions. The pro forma results include adjustments from Concho’s historical results to reverse impairment expense of $10.5 billion and $1.9 billion related to oil and gas properties and goodwill, respectively. Other adjustments made relate primarily to DD&A, which is based on the unit-of-production method, resulting from the purchase price allocated to properties, plants and equipment. We believe the estimates and assumptions are reasonable, and the relative effects of the transaction are properly reflected. Assets Sold In 2020, we completed the sale of our Australia-West asset and operations. The sales agreement entitled us to a $200 million payment upon a final investment decision (FID) of the Barossa development project. In March 2021, FID was announced and as such, we recognized a $200 million gain on disposition in the first quarter of 2021. The purchaser failed to pay the FID bonus when due. We have commenced an arbitration proceeding against the purchaser to enforce our contractual right to the $200 million, plus interest accruing from the due date. Results of operations related to this transaction are reflected in our Asia Pacific segment. See Note . In the second half of 2021, we sold our interests in certain noncore assets in our Lower 48 segment for approximately $250 million after customary adjustments, recognizing a before-tax gain on sale of approximately $58 million. We also completed the sale of our noncore exploration interests in Argentina, recognizing a before-tax loss on disposition of $179 million. Results of operations for Argentina were reported in our Other International segment. 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 loss associated with our interests in Niobrara, including the loss on disposition noted above, was $25 million for the year ended December 31, 2020. 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. 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, was $851 million for the year ended December 31, 2020. The sales agreement entitled us to an additional $200 million upon FID of the Barossa development project. Results of operations for the subsidiaries sold were reported in our Asia Pacific segment.

Investments, Loans and Long-Ter

Investments, Loans and Long-Term Receivables	12 Months Ended
	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Investments, Loans and Long-Term Receivables	Note 4—Investments, Loans and Long-Term Receivables Components of investments and long-term receivables at December 31 were: Millions of Dollars 2022 2021 Equity investments $ 7,493 6,701 Long-term receivables 142 98 Long-term investments in debt securities 522 248 Other investments 68 66 $ 8,225 7,113 Equity Investments Affiliated companies in which we had a significant equity investment at December 31, 2022, included: • APLNG—47.5 percent owned joint venture with Origin Energy (27.5 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 QatarEnergy (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. • Qatar Liquefied Gas Company Limited (8) (QG8)—25 percent owned joint venture with QatarEnergy (75 percent)—participant in the North Field East (NFE) LNG project. See Note . Summarized 100 percent earnings information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2022 2021 2020 Revenues $ 18,356 11,824 7,931 Income before income taxes 8,234 3,946 1,843 Net income 5,507 2,557 1,426 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2022 2021 Current assets $ 5,001 4,493 Noncurrent assets 37,789 36,602 Current liabilities 4,169 3,498 Noncurrent liabilities 17,244 17,465 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, 2022, retained earnings included $42 million related to the undistributed earnings of affiliated companies. Dividends received from affiliates were $3,045 million, $1,279 million and $1,076 million in 2022, 2021 and 2020, 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 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. In 2012, APLNG executed an $8.5 billion project finance facility that became non-recourse following financial completion in 2017. The facility is currently composed of a financing agreement with the Export-Import Bank of the United States, a commercial bank facility and two United States Private Placement note facilities. APLNG principal and interest payments commenced in March 2017 and are scheduled to occur bi-annually until September 2030. At December 31, 2022, a balance of $5.2 billion was outstanding on the facilities. See Note . During the fourth quarter of 2021, Origin Energy Limited agreed to the sale of 10 percent of their interest in APLNG for $1.645 billion, before customary adjustments. ConocoPhillips announced in December 2021 that we were exercising our preemption right under the APLNG Shareholders Agreement to purchase an additional 10 percent shareholding interest in APLNG, subject to government approvals. The sales price associated with this preemption right was determined to reflect a relevant observable market participant view of APLNG’s fair value which was below the carrying value of our existing investment in APLNG. Based on a review of the facts and circumstances surrounding this decline in fair value, we concluded in the fourth quarter of 2021 the impairment was other than temporary under the guidance of FASB ASC Topic 323, and the recognition of an impairment of our existing investment was necessary. Accordingly, we recorded a noncash $688 million before-tax and after-tax impairment in the fourth quarter of 2021. The impairment was included in the “Impairments” line on our consolidated income statement. See Note . At December 31, 2022, the carrying value of our equity method investment in APLNG was approximately $6.2 billion. The historical cost basis of our 47.5 percent share of net assets of APLNG was $6.1 billion, resulting in a basis difference of $41 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 production license areas owned by APLNG. Any future additional payments are expected to be allocated in a similar manner. 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 2022, 2021 and 2020 was after-tax expense of $10 million, $39 million and $41 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, which was fully repaid in the third quarter of 2022, as described below under “Loans.” At December 31, 2022, the book value of our equity method investment in QG3 was approximately $0.7 billion. 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. Currently, the LNG from QG3 is being sold to markets outside of the U.S. QG8 During 2022, we were awarded a 25 percent interest in a new joint venture (QG8) with QatarEnergy that will participate in the NFE LNG project. QG8 has a 12.5 percent interest in the NFE project. At December 31, 2022, the book value of our equity method investment was approximately $0.3 billion. See N ote . Loans 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 to certain affiliated and non-affiliated companies. At December 31, 2022, there were no outstanding loans to affiliated companies as the final loan payment related to QG3 project financing was received in the third quarter of 2022. 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 had 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 were completed in July 2022, for all loan arrangements.

Investment in Cenovus Energy

Investment in Cenovus Energy	12 Months Ended
	Dec. 31, 2022
Investments, Debt and Equity Securities [Abstract]
Investment in Cenovus Energy	Note 5—Investment in Cenovus Energy At December 31, 2021, we held 91 million common shares of Cenovus Energy (CVE), which approximated 4.5 percent of the issued and outstanding common shares of CVE. Those shares were carried on our balance sheet at fair value of $1.1 billion based on NYSE closing price of $12.28 per share on the last day of trading for the period. During the first quarter of 2022, we sold our remaining 91 million shares, recognizing proceeds of $1.4 billion. All gains and losses were recognized within "Other income (loss)" on our consolidated income statement. Proceeds related to the sale of our CVE shares were included within "Cash Flows from Investing Activities" on our consolidated statement of cash flows. See Note . Millions of Dollars 2022 2021 2020 Total Net gain (loss) on equity securities $ 251 1,040 (855) Less: Net gain (loss) on equity securities sold during the period 251 473 Unrealized gain (loss) on equity securities still held at the reporting date $ 567 (855)

Suspended Wells and Exploration

Suspended Wells and Exploration Expenses	12 Months Ended
	Dec. 31, 2022
Extractive Industries [Abstract]
Suspended Wells and Exploration Expenses	Note 6—Suspended Wells and Exploration Expenses The following table reflects the net changes in suspended exploratory well costs during 2022, 2021 and 2020: Millions of Dollars 2022 2021 2020 Beginning balance at January 1 $ 660 682 1,020 Additions pending the determination of proved reserves 5 10 164 Reclassifications to proved properties (7) — (42) Sales of suspended wells — — (313) Charged to dry hole expense (131) (32) (147) Ending balance at December 31 $ 527 660 682 The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2022 2021 2020 Exploratory well costs capitalized for a period of one year or less $ 15 4 156 Exploratory well costs capitalized for a period greater than one year 512 656 526 Ending balance $ 527 660 682 Number of projects with exploratory well costs capitalized for a period greater than one year 17 22 22 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, 2022: Millions of Dollars Suspended Since Total 2019-2021 2016-2018 2006-2015 Willow—Alaska (2) 315 201 114 — PL 1009—Norway (1) 39 39 — — PL 891—Norway (1) 31 31 — — Narwhal Trend—Alaska (1) 25 — 25 — WL4-00—Malaysia (2) 24 7 17 — PL782S—Norway (1) 19 19 — — Montney—Canada (1) 12 4 8 — Other of $10 million or less each (1)(2) 47 7 10 30 Total $ 512 308 174 30 (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. 2022 In the fourth quarter, we recorded a before-tax expense of $129 million for impairment of certain aged, suspended wells associated with Surmont in our Canada segment. In our Europe, Middle East and North Africa segment, we recorded a before-tax expense of $102 million for dry hole costs associated with four operated exploration and appraisal wells and one partner operated well that were drilled in Norway in 2022. 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. We had stopped participating in evaluating gas line projects and did not believe a project would advance. We remain willing to sell our Alaska North Slope gas to interested parties on a competitive basis if a market materializes in the future. In our Other International segment, our interests in the Middle Magdalena Basin of Colombia are in force majeure. Because we had no immediate plans to perform under existing contracts, 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.

Impairments

Impairments	12 Months Ended
	Dec. 31, 2022
Asset Impairment Charges [Abstract]
Impairments	Note 7—Impairments During 2022, 2021 and 2020, we recognized the following before-tax impairment charges: Millions of Dollars 2022 2021 2020 Alaska $ 2 5 — Lower 48 (11) (8) 804 Canada (2) 6 3 Europe, Middle East and North Africa (1) (24) 6 Asia Pacific — 695 — $ (12) 674 813 2021 We recorded an impairment of $688 million on our APLNG investment included within the Asia Pacific segment. See Note and Note . In our Lower 48 segment, we recorded a credit to impairment of $89 million due to a decreased ARO estimate for a previously sold asset, in which we retained the ARO liability. This was offset by recorded impairments of $84 million during the fourth quarter of 2021, related to certain noncore assets due to changes in development plans. See Note . In our Europe, Middle East and North Africa segment, we recorded a credit to impairment of $24 million due to decreased ARO estimates on fields in Norway which ceased production and were fully depreciated in prior years. 2020 We recorded impairments of $813 million, primarily related to certain noncore 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.

Asset Retirement Obligations an

Asset Retirement Obligations and Accrued Environmental Costs	12 Months Ended
	Dec. 31, 2022
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations and Accrued Environmental Cost	Note 8—Asset Retirement Obligations and Accrued Environmental Costs Asset retirement obligations and accrued environmental costs at December 31 were: Millions of Dollars 2022 2021 Asset retirement obligations $ 6,380 5,926 Accrued environmental costs 182 187 Total asset retirement obligations and accrued environmental costs 6,562 6,113 Asset retirement obligations and accrued environmental costs due within one year* (161) (359) Long-term asset retirement obligations and accrued environmental costs $ 6,401 5,754 *Classified as a current liability on the balance sheet under “Other accruals.” Asset Retirement Obligations We record the fair value of a liability for an ARO when it is incurred (typically when the asset is installed at the production location). When the liability is initially recorded, we capitalize the associated asset retirement cost by increasing the carrying amount of the related PP&E. 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. If, in subsequent periods, our estimate of this liability changes, we will record an adjustment to both the liability and PP&E. Reductions to estimated liabilities for assets that are no longer producing are recorded as a credit to impairment. 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 2022 and 2021, our overall ARO changed as follows: Millions of Dollars 2022 2021 Balance at January 1 $ 5,926 5,573 Accretion of discount 245 238 New obligations 144 555 Changes in estimates of existing obligations 681 (113) Spending on existing obligations (231) (164) Property dispositions (203) (108) Foreign currency translation (182) (55) Balance at December 31 $ 6,380 5,926 Accrued Environmental Costs Total accrued environmental costs at December 31, 2022 and 2021, were $182 million and $187 million, respectively. We had accrued environmental costs of $107 million and $135 million at December 31, 2022 and 2021, respectively, related to remediation activities in the U.S. and Canada. We had also accrued in Corporate and Other $59 million and $36 million of environmental costs associated with sites no longer in operation at December 31, 2022 and 2021, respectively. In addition, both December 31, 2022 and 2021, included a $16 million accrual, 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

Debt

Debt	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Debt	Note 9—Debt Long-term debt at December 31 was: Millions of Dollars 2022 2021 2.40% Notes due 2022 — 329 7.65% Debentures due 2023 78 78 3.35% Notes due 2024 426 426 2.125% Notes due 2024 900 — 8.2% Notes due 2025 134 134 3.35% Debentures due 2025 199 199 2.40% Notes due 2025 900 — 6.875% Debentures due 2026 67 67 4.95% Notes due 2026 — 1,250 7.8% Debentures due 2027 203 203 3.75% Notes due 2027 196 1,000 4.3% Notes due 2028 223 1,000 7.375% Debentures due 2029 92 92 7.0% Debentures due 2029 112 200 6.95% Notes due 2029 1,195 1,549 8.125% Notes due 2030 390 390 7.4% Notes due 2031 382 500 7.25% Notes due 2031 400 500 7.2% Notes due 2031 447 575 2.4% Notes due 2031 227 500 5.9% Notes due 2032 505 505 4.15% Notes due 2034 246 246 5.95% Notes due 2036 326 500 5.951% Notes due 2037 631 645 5.9% Notes due 2038 350 600 6.5% Notes due 2039 1,588 2,750 3.758% Notes due 2042 785 — 4.3% Notes due 2044 750 750 5.95% Notes due 2046 329 500 7.9% Debentures due 2047 60 60 4.875% Notes due 2047 319 800 4.85% Notes due 2048 219 600 3.8% Notes due 2052 1,100 — 4.025% Notes due 2062 1,770 — Floating rate notes due 2022 at 1.06% – 1.41% during 2022 and 1.02% – 1.12% during 2021 — 500 Marine Terminal Revenue Refunding Bonds due 2031 at 0.07% – 4.10% during 2022 and 0.04% – 0.15% during 2021 265 265 Industrial Development Bonds due 2035 at 0.07% – 4.10% during 2022 and 0.04% – 0.12% during 2021 18 18 Other 23 35 Debt at face value 15,855 17,766 Finance leases 1,320 1,261 Net unamortized premiums, discounts and debt issuance costs (532) 907 Total debt 16,643 19,934 Short-term debt (417) (1,200) Long-term debt $ 16,226 18,734 In December 2022, the company retired $329 million principal amount of our 2.40 percent Notes at the natural maturity date. In May 2022, we redeemed $1,250 million principal amount of our 4.95 percent Notes due 2026 . We paid premiums above face value of $79 million to redeem the debt and recognized a loss on debt extinguishment of $83 million which is included in the "Other expenses" line on our consolidated income statement. We also paid $500 million to retire the outstanding principal amount of the floating rate notes due 2022 at maturity. In the first quarter of 2022, we completed a debt refinancing consisting of three concurrent transactions: a tender offer to repurchase existing debt for cash; exchange offers to retire certain debt in exchange for new debt and cash; and a new debt issuance to partially fund the cash paid in the tender and exchange offers. Tender Offer In March 2022, we repurchased a total of $2,716 million aggregate principal amount of debt as listed below. We paid premiums above face value of $333 million to repurchase these debt instruments and recognized a gain on debt extinguishment of $155 million which is included in the "Other expenses" line on our consolidated income statement. • 3.75% Notes due 2027 with principal of $1,000 million (partial repurchase of $804 million) • 4.3% Notes due 2028 with principal of $1,000 million (partial repurchase of $777 million) • 2.4% Notes due 2031 with principal of $500 million (partial repurchase of $273 million) • 4.875% Notes due 2047 with principal of $800 million (partial repurchase of $481 million) • 4.85% Notes due 2048 with principal of $600 million (partial repurchase of $381 million) Exchange Offers Also in March 2022, we completed two concurrent debt exchange offers through which $2,544 million of aggregate principal of existing notes was tendered and accepted in exchange for a combination of new notes and cash. The debt exchange offers were treated as debt modifications for accounting purposes resulting in a portion of the unamortized debt discount, premiums and debt issuance costs of the existing notes being allocated to the new notes on the settlement dates of the exchange offers. We paid premiums above face value of $883 million, comprised of $872 million of cash as well as new notes, which were capitalized as additional debt discount. We incurred expenses of $28 million in the exchanges which are included in the "Other expenses" line on our consolidated income statement. The notes tendered and accepted in the exchange offers were: • 7.0% Debentures due 2029 with principal amount of $200 million (partial exchange of $88 million) • 6.95% Notes due 2029 with principal amount of $1,549 million (partial exchange of $354 million) • 7.4% Notes due 2031 with principal amount of $500 million (partial exchange of $118 million) • 7.25% Notes due 2031 with principal amount of $500 million (partial exchange of $100 million) • 7.2% Notes due 2031 with principal amount of $575 million (partial exchange of $128 million) • 5.95% Notes due 2036 with principal amount of $500 million (partial exchange of $174 million) • 5.9% Notes due 2038 with principal amount of $600 million (partial exchange of $250 million) • 6.5% Notes due 2039 with principal amount of $2,750 million (partial exchange of $1,162 million) • 5.95% Notes due 2046 with principal amount of $500 million (partial exchange of $171 million) The notes tendered and accepted were exchanged for the following new notes: • 3.758% Notes due 2042 with principal amount of $785 million • 4.025% Notes due 2062 with principal amount of $1,770 million New Debt Issuance In March 2022, we issued the following new notes consisting of: • 2.125% Notes due 2024 with principal of $900 million • 2.4% Note due 2025 with principal of $900 million • 3.8% Note due 2052 with principal of $1,100 million In February 2022, we refinanced our revolving credit facility from a total borrowing capacity of $6.0 billion to $5.5 billion with an expiration date of February 2027. 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 the Secured Overnight Financing Rate (SOFR). The facility agreement calls for commitment fees on available, but unused, amounts. The facility 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 $5.5 billion of commercial paper. Commercial paper is generally limited to maturities of 90 days and is included in short-term debt on our consolidated balance sheet. With no commercial paper outstanding and no direct borrowings or letters of credit, we had access to $5.5 billion in available borrowing capacity under our revolving credit facility at December 31, 2022. At December 31, 2021, we had no commercial paper outstanding and no direct borrowings or letters of credit issued. In January 2021, we completed the acquisition of Concho in an all-stock transaction. In the acquisition, we assumed Concho’s publicly traded debt, with an outstanding principal balance of $3.9 billion, which was recorded at fair value of $4.7 billion on the acquisition date. The adjustment to fair value of the senior notes of approximately $0.8 billion on the acquisition date will be amortized as an adjustment to interest expense over the remaining contractual terms of the senior notes. In February 2021, we completed a debt exchange offer related to the debt assumed from Concho. Of the approximately $3.9 billion in aggregate principal amount of Concho’s senior notes offered in the exchange, 98 percent, or approximately $3.8 billion, was tendered and accepted. The new debt issued by ConocoPhillips had the same interest rates and maturity dates as the Concho senior notes. The portion not exchanged, approximately $67 million, remained outstanding across five series of senior notes issued by Concho. The debt exchange was treated as a debt modification for accounting purposes resulting in a portion of the unamortized fair value adjustment of the Concho senior notes allocated to the new debt issued by ConocoPhillips on the settlement date of the exchange. The new debt issued in the exchange is fully and unconditionally guaranteed by ConocoPhillips Company. See Note . For information on Finance Leases, see Note . The current credit ratings on our long-term debt are: • Fitch: “A” with a “stable” outlook • S&P: “A-” with a “stable” outlook • Moody's: "A2" with a "stable" outlook We do not have any ratings triggers on any of our corporate debt that would cause an automatic default, and thereby impact our access to liquidity upon downgrade of our credit ratings. If our credit ratings are downgraded from their current levels, it could increase the cost of corporate debt available to us and restrict our access to the commercial paper markets. If our credit ratings were to deteriorate to a level prohibiting us from accessing the commercial paper market, we would still be able to access funds under our revolving credit facility. At both December 31, 2022 and 2021, 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.

Guarantees

Guarantees	12 Months Ended
	Dec. 31, 2022
Guarantees [Abstract]
Guarantees	Note 10—Guarantees At December 31, 2022, 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, 2022, we had outstanding multiple guarantees in connection with our 47.5 percent ownership interest in APLNG. The following is a description of the guarantees with values calculated utilizing December 2022 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 eight years. Our maximum exposure under this guarantee is approximately $210 million and may become payable if an enforcement action is commenced by the project finance lenders against APLNG. At December 31, 2022, the carrying value of this guarantee was approximately $14 million. • In conjunction with our original purchase of an ownership interest in APLNG from Origin Energy Limited in October 2008, we agreed to reimburse Origin Energy Limited 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. The final guarantee expires in the fourth quarter of 2041. Our maximum potential liability for future payments, or cost of volume delivery, under these guarantees is estimated to be $780 million ($1.3 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-ventures 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 14 to 23 years or the life of the venture. Our maximum potential amount of future payments related to these guarantees is approximately $290 million and would become payable if APLNG does not perform. At December 31, 2022, the carrying value of these guarantees was approximately $20 million. QG8 Guarantee We have guaranteed our portion of certain fiscal and other joint venture obligations as a shareholder in QG8. This guarantee has an approximate 30-year term with no maximum limit. At December 31, 2022, the carrying value of this guarantee was approximately $7 million. Other Guarantees We have other guarantees with maximum future potential payment amounts totaling approximately $600 million, which consist primarily of guarantees of the residual value of leased office buildings and guarantees of the residual value of corporate aircraft. These guarantees have remaining terms of three 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. The carrying amount recorded for these indemnifications at December 31, 2022, was approximately $20 million. Those related to environmental issues have terms that are generally indefinite and the maximum amounts of future payments are generally unlimited. 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. See Note

Contingencies and Commitments

Contingencies and Commitments	12 Months Ended
	Dec. 31, 2022
Commitments and Contingencies Disclosure [Abstract]
Contingencies and Commitments	Note 11—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 , 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 and record accruals for environmental liabilities based on management’s best estimates. These estimates are based 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 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, claims of alleged environmental contamination and damages from historic operations, and climate change. 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, 2022, we had performance obligations secured by letters of credit of $368 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. 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, which automatically stayed enforcement of the award. On September 29, 2021, the ICSID annulment committee lifted the stay of enforcement of the award. The 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. 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. To date, ConocoPhillips has received approximately $774 million in connection with the ICC award. 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. Beginning in 2017, governmental and other entities in several states/territories 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 are unprecedented, therefore, there is significant uncertainty about the scope of the claims and alleged damages and any potential impact on the Company’s financial condition. 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. On October 17, 2022, the Fifth Circuit affirmed remand of lead cases to state court and the subsequent request for rehearing was denied. Accordingly, the federal district courts have issued remands to state court. Because Plaintiffs’ SLCRMA theories are unprecedented, there is uncertainty about these claims (both as to scope and damages) and we continue to evaluate our exposure in these lawsuits. 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. BSEE’s order to ConocoPhillips is premised on its connection to Phillips Petroleum Company, a legacy company of ConocoPhillips, which held a historical 25 percent interest in this lease and operated these facilities, but sold its interest approximately 30 years ago. ConocoPhillips continues to evaluate its exposure in this matter. On May 10, 2021, ConocoPhillips filed arbitration under the rules of the Singapore International Arbitration Centre (SIAC) against Santos KOTN Pty Ltd. and Santos Limited for their failure to timely pay the $200 million bonus due upon FID of the Barossa development project under the sale and purchase agreement. Santos KOTN Pty Ltd. and Santos Limited have filed a response and counterclaim, and the arbitration is underway. In July 2021, a federal securities class action was filed against Concho, certain of Concho’s officers, and ConocoPhillips as Concho’s successor in the United States District Court for the Southern District of Texas. On October 21, 2021, the court issued an order appointing Utah Retirement Systems and the Construction Laborers Pension Trust for Southern California as lead plaintiffs (Lead Plaintiffs). On January 7, 2022, the Lead Plaintiffs filed their consolidated complaint alleging that Concho made materially false and misleading statements regarding its business and operations in violation of the federal securities laws and seeking unspecified damages, attorneys’ fees, costs, equitable/injunctive relief, and such other relief that may be deemed appropriate. We believe the allegations in the action are without merit and are vigorously defending this litigation. 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 business. The aggregate amounts of estimated payments under these various agreements are: 2023—$7 million; 2024—$7 million; 2025—$7 million; 2026—$7 million; 2027—$7 million; and 2028 and after—$33 million. Total payments under the agreements were $26 million in 2022, $27 million in 2021 and $25 million in 2020.

Derivative and Financial Instru

Derivative and Financial Instruments	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Derivative and Financial Instruments	Note 12—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, 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 and certain gas 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 2022 2021 Assets Prepaid expenses and other current assets $ 1,795 1,168 Other assets 242 75 Liabilities Other accruals 1,800 1,160 Other liabilities and deferred credits 210 63 The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars 2022 2021 2020 Sales and other operating revenues $ (88) (228) 19 Other income (loss) (5) 25 4 Purchased commodities (91) 75 11 On January 15, 2021, we assumed financial derivative instruments consisting of oil and natural gas swaps in connection with the acquisition of Concho. At the acquisition date, these financial derivative instruments acquired were recognized at fair value as a net liability of $456 million with settlement dates under the contracts through December 31, 2022. During 2021, we recognized a loss on settlement of these derivatives contracts of $305 million. This loss is recorded within the “Sales and other operating revenues” line on our consolidated income statement. In connection with the settlement, we issued a cash payment of $761 million during 2021 which is included within “Cash Flows From Operating Activities” on our consolidated statement of cash flows. The table below summarizes our net exposures resulting from outstanding commodity derivative contracts: Open Position 2022 2021 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (14) 4 Basis (8) (22) 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, 2022 and 2021: Millions of Dollars Carrying Amount Cash and Cash Short-Term 2022 2021 2022 2021 Cash $ 593 670 Demand Deposits 1,638 1,554 Time Deposits 1 to 90 days 4,116 2,363 1,288 217 91 to 180 days 883 4 Within one year 11 4 U.S. Government Obligations 1 to 90 days 14 431 — — $ 6,361 5,018 2,182 225 The following investments in debt securities classified as available for sale are carried at fair value on our consolidated balance sheet at December 31, 2022 and 2021: Millions of Dollars Carrying Amount Cash and Cash Short-Term Investments and Long-Term 2022 2021 2022 2021 2022 2021 Major Security Type Corporate Bonds $ — 3 323 128 309 173 Commercial Paper 97 7 156 82 U.S. Government Obligations — — 115 — 63 2 U.S. Government Agency Obligations 8 2 5 8 Foreign Government Obligations — 7 7 2 Asset-backed Securities 1 2 138 63 $ 97 10 603 221 522 248 Cash and Cash Equivalents and Short-Term Investments have remaining maturities within one year. Investments and Long-Term Receivables have remaining maturities that vary from 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 at December 31: Millions of Dollars Amortized Cost Basis Fair Value 2022 2021 2022 2021 Major Security Type Corporate Bonds $ 641 305 632 304 Commercial Paper 253 88 253 89 U.S. Government Obligations 181 2 178 2 U.S. Government Agency Obligations 13 10 13 10 Foreign Government Obligations 7 9 7 9 Asset-backed Securities 139 65 139 65 $ 1,234 479 1,222 479 As of December 31, 2022 and 2021, total unrealized losses for debt securities classified as available for sale with net losses were $12 million and negligible, respectively. No allowance for credit losses has been recorded on investments in debt securities which are in an unrealized loss position. For the years ended December 31, 2022 and 2021, proceeds from sales and redemptions of investments in debt securities classified as available for sale were $644 million and $594 million, respectively. 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, U.S. government and government agency obligations, time deposits with major international banks and financial institutions, high-quality corporate bonds, foreign government obligations and asset-backed securities. Our long-term investments in debt securities are placed in high-quality corporate bonds, asset-backed securities, U.S. government and government agency obligations, foreign government obligations, and time deposits with major international banks and financial institutions. 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. 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.

Fair Value Measurement

Fair Value Measurement	12 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [Abstract]
Fair Value Measurement	Note 13—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 fair value hierarchy. 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 2022 or 2021. Recurring Fair Value Measurement Financial assets and liabilities reported at fair value on a recurring basis primarily include our investment in CVE 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 CVE, 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, 2022 December 31, 2021 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ 1,117 — — 1,117 Investments in debt securities 178 1,044 — 1,222 2 477 — 479 Commodity derivatives 958 951 128 2,037 562 619 62 1,243 Total assets $ 1,136 1,995 128 3,259 1,681 1,096 62 2,839 Liabilities Commodity derivatives $ 906 843 261 2,010 593 543 87 1,223 Total liabilities $ 906 843 261 2,010 593 543 87 1,223 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 Gross Net Cash Net December 31, 2022 Assets $ 2,037 39 1,998 1,176 822 37 785 Liabilities 2,010 20 1,990 1,176 814 52 762 December 31, 2021 Assets $ 1,243 85 1,158 650 508 — 508 Liabilities 1,223 82 1,141 650 491 36 455 At December 31, 2022 and December 31, 2021, 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 Level 2 Level 3 Before-Tax Year ended December 31, 2021 Net PP&E (held for use) December 31, 2021 $ 472 — — 472 80 Equity Method Investments December 31, 2021 5,574 — 5,574 — 688 Net PP&E (held for use) During 2021, the estimated fair value of certain noncore 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 Valuation Unobservable Inputs Range (Arithmetic Average) December 31, 2021 Lower 48 Gulf Coast and Rockies noncore field $ 472 Discounted cash flow Commodity production (MBOED) 0.2 - 17 (5.4) Commodity price outlook* ($/BOE) $41.45 - $93.68 ($64.39) Discount rate** 7.3% - 9.7% (8.7%) *Commodity price outlook based on a combination of external pricing service companies' and our internal outlook for years 2024-2050; 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. Equity Method Investments During the fourth quarter of 2021, Origin Energy Limited agreed to the sale of 10 percent of their interest in APLNG for $1.645 billion, before customary adjustments. ConocoPhillips announced in December 2021 that we were exercising our preemption right under the APLNG Shareholders Agreement to purchase an additional 10 percent shareholding interest in APLNG, subject to government approvals. The sales price associated with this preemption right was determined to reflect a relevant observable market participant view of APLNG’s fair value which was below the carrying value of our existing investment in APLNG. As such, our investment in APLNG was written down to its fair value of $5,574 million, resulting in a before-tax charge of $688 million. See Note and Not e . 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 for a discussion of the carrying value and fair value of our investment in CVE 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 . • 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 . • 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. 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 2022 2021 2022 2021 Financial assets Investment in CVE common shares $ — 1,117 $ — 1,117 Commodity derivatives 824 593 824 593 Investments in debt securities 1,222 479 1,222 479 Loans and advances—related parties — 114 — 114 Financial liabilities Total debt, excluding finance leases 15,323 18,673 15,545 22,451 Commodity derivatives 782 537 782 537

Equity

Equity	12 Months Ended
	Dec. 31, 2022
Equity [Abstract]
Equity	Note 14—Equity Common Stock The changes in our shares of common stock, as categorized in the equity section of the balance sheet, were: Shares 2022 2021 2020 Issued Beginning of year 2,091,562,747 1,798,844,267 1,795,652,203 Acquisition of Concho — 285,928,872 — Distributed under benefit plans 9,322,387 6,789,608 3,192,064 End of year 2,100,885,134 2,091,562,747 1,798,844,267 Held in Treasury Beginning of year 789,319,875 730,802,089 710,783,814 Repurchase of common stock 87,709,187 58,517,786 20,018,275 End of year 877,029,062 789,319,875 730,802,089 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, 2022 or 2021. Noncontrolling Interests In 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. Repurchase of Common Stock In late 2016, we initiated our current share repurchase program. In October 2022, our Board of Directors approved an increase to our authorization from $25 billion to $45 billion of our common stock to support our plan for future share repurchases.

Non-Mineral Leases

Non-Mineral Leases	12 Months Ended
	Dec. 31, 2022
Leases [Abstract]
Non-Mineral Leases	Note 15—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 . There are no significant restrictions imposed on us by the lease agreements with regard to dividends, asset dispositions or borrowing ability. We determine if an arrangement is or contains a lease at contract inception. Certain contractual arrangements may contain both lease and non-lease components. 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 existing asset classes (as of the adoption date of ASC 842) for accounting purposes. For contractual arrangements involving a new leased asset class, we 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 the adoption date of ASC 842 on 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 2022 2021 Operating Finance Operating Finance Right-of-Use Assets Properties, plants and equipment Gross 2,043 1,812 Accumulated DD&A (1,022) (857) Net PP&E* 1,021 955 Prepaid expenses and other current assets 16 2 Other assets 536 649 Lease Liabilities Short-term debt** 284 280 Other accruals 155 188 Long-term debt*** 1,036 981 Other liabilities and deferred credits 390 479 Total lease liabilities $ 545 1,320 667 1,261 * Includes proportionately consolidated finance lease assets of $171 million at December 31, 2022 and $208 million at December 31, 2021. ** Includes proportionately consolidated finance lease liabilities of $169 million at December 31, 2022 and $154 million at December 31, 2021. *** Includes proportionately consolidated finance lease liabilities of $399 million at December 31, 2022 and $462 million at December 31, 2021. The following table summarizes our lease costs: Millions of Dollars 2022 2021 2020 Lease Cost* Operating lease cost $ 212 278 321 Finance lease cost Amortization of right-of-use assets 189 148 163 Interest on lease liabilities 32 27 34 Short-term lease cost** 94 21 42 Total lease cost*** $ 527 474 560 * 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: 2022 2021 Lease Term and Discount Rate Weighted-average term (years) Operating leases 5.64 5.97 Finance leases 6.60 7.49 Weighted-average discount rate (percent) Operating leases 2.99 2.66 Finance leases 3.40 3.24 The following table summarizes other lease information: Millions of Dollars 2022 2021 2020 Other Information* Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 148 204 232 Operating cash flows from finance leases 30 6 11 Financing cash flows from finance leases 166 73 255 Right-of-use assets obtained in exchange for operating lease liabilities $ 114 174 250 Right-of-use assets obtained in exchange for finance lease liabilities 256 447 426 *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, 2022: Millions of Dollars Operating Leases Finance Leases Maturity of Lease Liabilities 2023 $ 169 356 2024 126 215 2025 81 210 2026 59 207 2027 46 164 Remaining years 118 352 Total* 599 1,504 Less: portion representing imputed interest (54) (184) Total lease liabilities $ 545 $ 1,320 *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.

Employee Benefit Plans

Employee Benefit Plans	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Employee Benefit Plans	Note 16—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 2022 2021 2022 2021 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 1,924 4,124 2,548 4,403 137 170 Service cost 58 47 73 61 1 2 Interest cost 62 77 53 79 4 4 Plan participant contributions — — — — 16 16 Plan amendments — — — — 9 — Actuarial (gain) loss (325) (847) (117) (176) (27) (16) Benefits paid (241) (144) (654) (162) (38) (40) Divestiture — (56) — — — — Curtailment — — 12 — — 1 Recognition of termination benefits — — 9 — — — Foreign currency exchange rate change — (425) — (81) — — Benefit obligation at December 31* $ 1,478 2,776 1,924 4,124 102 137 *Accumulated benefit obligation portion of above at December 31: $ 1,384 2,542 1,793 3,658 Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 1,664 4,812 1,770 4,793 — — Actual return on plan assets (319) (1,372) 97 147 — — Company contributions 75 96 451 119 22 24 Plan participant contributions — 1 — 1 16 16 Benefits paid (241) (144) (654) (162) (38) (40) Divestiture — (46) — — — — Foreign currency exchange rate change — (468) — (86) — — Fair value of plan assets at December 31 $ 1,179 2,879 1,664 4,812 — — Funded Status $ (299) 103 (260) 688 (102) (137) Millions of Dollars Pension Benefits Other Benefits 2022 2021 2022 2021 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ — 373 1 991 — — Current liabilities (28) (10) (29) (15) (32) (34) Noncurrent liabilities (271) (260) (232) (288) (70) (103) Total recognized $ (299) 103 (260) 688 (102) (137) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 5.65 % 4.20 2.80 2.15 5.65 2.65 Rate of compensation increase 5.00 3.65 4.00 3.40 Interest crediting rate for applicable benefits 3.55 2.50 Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.85 % 2.15 2.60 1.80 2.65 2.35 Expected return on plan assets 3.90 2.85 5.20 2.50 Rate of compensation increase 4.00 3.40 4.00 3.40 Interest crediting rate for applicable benefits 2.50 2.10 For both U.S. and international pension plans, 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. During 2022 and 2021, the actuarial gains related to the benefit obligations for U.S. and international plans were primarily related to an increase in the discount rates. During 2020, the actuarial losses related to the benefit obligations for U.S. and international plans were primarily related to a decrease in the discount rates. The following tables summarize information related to the Company's pension plans with projected and accumulated benefit obligations in excess of the fair value of the plans' assets: Millions of Dollars Pension Benefits 2022 2021 U.S. Int’l. U.S. Int’l. Pension Plans with Projected Benefit Obligation in Excess of Plan Assets Projected benefit obligation $ 1,478 277 261 362 Fair value of plan assets 1,179 6 — 58 Pension Plans with Accumulated Benefit Obligation in Excess of Plan Assets Accumulated benefit obligation $ 1,384 239 234 271 Fair value of plan assets 1,179 6 — 9 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 2022 2021 2022 2021 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial loss (gain) $ 172 681 188 86 (28) (1) Unrecognized prior service cost (credit) — 1 — 1 (98) (145) Millions of Dollars Pension Benefits Other Benefits 2022 2021 2022 2021 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ (44) (606) 134 207 27 16 Amortization of actuarial loss included in income (loss)* 61 11 145 33 — — Net change during the period $ 17 (595) 279 240 27 16 Prior service credit (cost) arising during the period $ — (1) — — (9) — Amortization of prior service (credit) included in income (loss) — (1) — (1) (38) (37) Net change during the period $ — (2) — (1) (47) (37) *Includes settlement (gains) losses recognized in 2022 and 2021. 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 2022 2021 2020 2022 2021 2020 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 58 47 73 61 85 54 1 2 2 Interest cost 62 77 53 79 66 85 4 4 6 Expected return on plan assets (50) (124) (80) (120) (85) (145) — — — Amortization of prior service credit — (1) — (1) — (1) (38) (37) (31) Recognized net actuarial loss (gain) 24 11 43 33 51 22 — — 1 Settlements loss (gain) 37 — 102 — 44 (1) — — — Curtailment loss — — 12 — — — — — — Net periodic benefit cost $ 131 10 203 52 161 14 (33) (31) (22) The components of net periodic benefit cost, other than the service cost component, are included in the “ Other expenses We recognized pension settlement losses of $37 million in 2022, $102 million in 2021, and $43 million in 2020 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. 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 non-pension postretirement benefit plans for health and life insurance. The health care plans are contributory and subject to various cost sharing features, most with participant and company contributions adjusted annually; the life insurance plans are noncontributory. The measurement of the U.S. pre-65 retiree medical accumulated postretirement benefit obligation assumes a health care cost trend rate of 6.5 percent in 2023 that declines to 5 percent by 2029. The measurement of the U.S. post-65 retiree medical accumulated postretirement benefit obligation assumes a health care cost trend rate of 4.5 percent in 2023 that increases to 5 percent by 2029. 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 25 percent equity securities, 71 percent debt securities, and 4 percent real estate. 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, 2022 and 2021. • 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, 2022, the participating interest in the annuity contract was valued at $55 million and consisted of $144 million in debt securities, less $89 million for the accumulated benefit obligation covered by the contract. At December 31, 2021, the participating interest in the annuity contract was valued at $83 million and consisted of $206 million in debt securities, less $123 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 2022 Equity securities U.S. $ 4 — — 4 — — — — International 36 — — 36 — — — — Mutual funds 14 — — 14 201 298 — 499 Debt securities Corporate — 1 — 1 — — — — Mutual funds — — — — 365 — — 365 Cash and cash equivalents — — — — 36 — — 36 Real estate — — — — — — 146 146 Total in fair value hierarchy $ 54 1 — 55 602 298 146 1,046 Investments measured at net asset value* Equity securities Common/collective trusts 265 192 Debt securities Common/collective trusts 759 1,637 Cash and cash equivalents 10 — Real estate 34 — Total** $ 54 1 — 1,123 602 298 146 2,875 *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 $55 million and net receivables related to security transactions of $5 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 2021 Equity securities U.S. $ 3 — 5 8 — — — — International 42 — — 42 — — — — Mutual funds 17 — — 17 236 403 — 639 Debt securities Corporate — 1 — 1 — — — — Mutual funds — — — — 511 — — 511 Cash and cash equivalents — — — — 68 — — 68 Derivatives — — — — — — — — Real estate — — — — — — 157 157 Total in fair value hierarchy $ 62 1 5 68 815 403 157 1,375 Investments measured at net asset value* Equity securities Common/collective trusts 394 417 Debt securities Common/collective trusts 1,073 3,015 Cash and cash equivalents 9 — Real estate 36 1 Total** $ 62 1 5 1,580 815 403 157 4,808 *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 $83 million and net receivables related to security transactions of $5 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 2023, we expect to contribute approximately $90 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $45 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 U.S. Int’l. 2023 $ 216 121 17 2024 199 123 15 2025 188 125 14 2026 173 126 12 2027 171 128 11 2028–2032 685 677 38 The following table summarizes our severance accrual activity: Millions of Dollars 2022 2021 2020 Balance at January 1 $ 78 24 23 Accruals 1 170 14 Benefit payments (48) (116) (13) Balance at December 31 $ 31 78 24 Accruals include severance costs associated with our company-wide restructuring program. Of the remaining balance at December 31, 2022, $19 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 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 of the ConocoPhillips Retirement Plan 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 $140 million in 2022, $93 million in 2021 and $62 million in 2020. 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 $24 million in 2022, $26 million in 2021 and $25 million in 2020. Share-Based Compensation Plans The 2014 Omnibus Stock and Performance Incentive Plan of ConocoPhillips (the Plan) was approved by shareholders in May 2014, replacing similar prior plans and providing that no new awards shall be granted under the prior plans. 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 Plan or 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. 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 were: Millions of Dollars 2022 2021 2020 Compensation cost $ 377 304 159 Tax benefit 95 76 40 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 beginning with 2020 awards. The following summarizes our stock option activity for the year ended December 31, 2022: Millions of Dollars Options Weighted-Average Aggregate Outstanding at December 31, 2021 11,973,783 $ 56.46 $ 188 Exercised (7,670,208) 57.12 (308) Expired or cancelled — — Outstanding at December 31, 2022 4,303,575 $ 55.28 $ 266 Vested at December 31, 2022 4,303,575 $ 55.28 $ 266 Exercisable at December 31, 2022 4,303,575 $ 55.28 $ 266 The weighted-average remaining contractual term of outstanding options, vested options and exercisable options at December 31, 2022, were all 2.57 years. The aggregate intrinsic value of options exercised was $68 million in 2021 and $23 million in 2020. During 2022, we received $438 million in cash and realized a tax benefit of $59 million from the exercise of options. At December 31, 2022, all outstanding stock options were fully vested and there was no remaining compensation cost to be recorded. Stock Unit Program —Generally, restricted stock units (RSU) 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, RSUs 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 RSUs receive a cash payment of a dividend equivalent or an accrued reinvested dividend equivalent that is charged to retained earnings. The grant date fair market value of these RSUs 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, 2022: Stock Units Weighted-Average Millions of Dollars Total Fair Value Outstanding at December 31, 2021 7,645,311 $ 53.81 Granted 2,139,168 90.57 Forfeited (137,011) 71.38 Issued (2,069,275) 63.57 $ 193 Outstanding at December 31, 2022 7,578,193 $ 61.20 Not Vested at December 31, 2022 5,264,282 $ 61.58 At December 31, 2022, the remaining unrecognized compensation cost from the unvested stock-settled units was $135 million, which will be recognized over a weighted-average period of 1.67 years, the longest period being 2.67 years. The weighted-average grant date fair value of stock unit awards granted during 2021 and 2020 was $46.56 and $57.40, respectively. The total fair value of stock units issued during 2021 and 2020 was $144 million and $143 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, 2022: Stock Units Weighted-Average Grant Date Fair Value Millions of Dollars Total Fair Value Outstanding at December 31, 2021 226,476 $ 72.18 Granted 531 85.37 Forfeited — — Issued (227,007) 91.47 $ 21 Outstanding at December 31, 2022 — $ — At December 31, 2022, there was no remaining unrecognized compensation cost to be recorded for the unvested cash-settled units. The weighted-average grant date fair value of stock unit awards granted during 2021 and 2020 were $57.19 and $41.59, respectively. The total fair value of stock units issued during 2021 and 2020 were $20 million and negligible, 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 effective 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 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, 2022: Weighted-Average Millions of Dollars Stock Units Total Fair Value Outstanding at December 31, 2021 1,448,847 $ 50.69 Granted 1,754 91.58 Issued (218,986) 51.04 $ 21 Outstanding at December 31, 2022 1,231,615 $ 50.68 At December 31, 2022, there was no remaining unrecognized compensation cost to be recorded on the unvested stock-settled performance shares. There were no stock-settled PSUs granted during 2021; however, the weighted-average grant date fair value of stock-settled PSUs granted during 2020 was $58.61. The total fair value of stock-settled PSUs issued during 2021 and 2020 were $18 million and $13 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 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 cash payment of a dividend equivalent, but after the performance period ends, until settlement in cash occurs, recipients of the PSUs receive a 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, 2022: Weighted-Average Millions of Dollars Stock Units Total Fair Value Outstanding at December 31, 2021 117,679 $ 72.18 Granted 967,151 91.58 Settled (975,007) 89.87 $ 88 Outstanding at December 31, 2022 109,823 $ 117.11 At December 31, 2022, 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 2021 and 2020 was $46.65 and $58.61, respectively. The total fair value of cash-settled performance share awards settled during 2021 and 2020 was $52 million and $116 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, as part of an executive compensation program that has been discontinued or acquired as a result of an acquisition. 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, 2022: Weighted-Av

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income Taxes	Note 17—Income Taxes Components of income tax provision (benefit) were: Millions of Dollars 2022 2021 2020 Income Taxes Federal Current $ 1,263 32 3 Deferred 1,629 1,161 (625) Foreign Current 5,813 3,128 350 Deferred 387 66 (70) State and local Current 386 127 (4) Deferred 70 119 (139) Total tax provision (benefit) $ 9,548 4,633 (485) 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 2022 2021 Deferred Tax Liabilities PP&E and intangibles $ 11,100 10,170 Inventory 48 44 Other 190 213 Total deferred tax liabilities 11,338 10,427 Deferred Tax Assets Benefit plan accruals 450 321 Asset retirement obligations and accrued environmental costs 2,333 2,297 Investments in joint ventures 1,917 1,684 Other financial accruals and deferrals 736 827 Loss and credit carryforwards 6,354 7,402 Other 112 399 Total deferred tax assets 11,902 12,930 Less: valuation allowance (8,049) (8,342) Total deferred tax assets net of valuation allowance 3,853 4,588 Net deferred tax liabilities $ 7,485 5,839 At December 31, 2022, noncurrent assets and liabilities included deferred taxes of $241 million and $7,726 million, respectively. At December 31, 2021, noncurrent assets and liabilities included deferred taxes of $340 million and $6,179 million, respectively. At December 31, 2022, the loss and credit carryforward deferred tax assets were primarily related to U.S. foreign tax credit carryforwards of $5.3 billion and various jurisdictions net operating loss and credit carryforwards of $1.1 billion. If not utilized, U.S. foreign tax credits and net operating losses will begin to expire in 2023. The following table shows a reconciliation of the beginning and ending deferred tax asset valuation allowance for 2022, 2021 and 2020: Millions of Dollars 2022 2021 2020 Balance at January 1 $ 8,342 9,965 10,214 Charged to expense (benefit) 5 (45) 460 Other* (298) (1,578) (709) Balance at December 31 $ 8,049 8,342 9,965 *Represents changes due to originating deferred tax assets that have no impact to our effective tax rate, acquisitions/dispositions/revisions and the effect of translating foreign financial statements. Valuation allowances have been established to reduce deferred tax assets to an amount that will, more likely than not, be realized. At December 31, 2022, we have maintained a valuation allowance with respect to substantially all U.S. foreign tax credit carryforwards, basis differences in our APLNG investment, and certain net operating loss carryforwards for various jurisdictions. During 2022, the valuation allowance movement charged to earnings primarily relates to the impact of 2022 changes to Norway’s Petroleum Tax System which is partly offset by the U.S. tax impact of the disposition of our CVE common shares. 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. During the second quarter of 2022, Norway enacted changes to the Petroleum Tax System. As a result of the enactment, a valuation allowance of $58 million was recorded during the second quarter to reflect changes to our ability to realize certain deferred tax assets under the new law. During 2021, the valuation allowance movement charged to earnings primarily relates to the fair value measurement of our CVE common shares that are not expected to be realized, and the expected realization of certain U.S. tax attributes associated with our planned disposition of our Indonesia assets. This is partially offset by Australian tax benefits associated with our impairment of APLNG that we do not expect to be realized. Other movements are primarily related to valuation allowances on expiring tax attributes. For more information on our Indonesia disposition see Note . During 2020, the valuation allowance movement charged to earnings primarily related to capital losses in Australia and to the fair value measurement of our CVE common shares that are not expected to be realized. Other movements are primarily related to valuation allowances on expiring tax attributes. At December 31, 2022, unremitted income considered to be permanently reinvested in certain foreign subsidiaries and foreign corporate joint ventures totaled approximately $4,477 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 $224 million. The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2022, 2021 and 2020: Millions of Dollars 2022 2021 2020 Balance at January 1 $ 1,345 1,206 1,177 Additions based on tax positions related to the current year 6 15 6 Additions for tax positions of prior years 6 177 67 Reductions for tax positions of prior years (62) (5) (34) Settlements (510) — (9) Lapse of statute (75) (48) (1) Balance at December 31 $ 710 1,345 1,206 Included in the balance of unrecognized tax benefits for 2022, 2021 and 2020 were $701 million, $1,261 million and $1,128 million respectively, which, if recognized, would impact our effective tax rate. The balance of the unrecognized tax benefits decreased due to the closing of the 2017 audit of our federal income tax return. As a result, we recognized federal and state tax benefits totaling $515 million relating to the recovery of outside tax basis previously offset by a full reserve. The balance of the unrecognized tax benefits increased in 2021 mainly due to U.S. tax credits acquired through our Concho acquisition. See Note Not e 11. At December 31, 2022, 2021 and 2020, accrued liabilities for interest and penalties totaled $35 million, $47 million and $46 million, respectively, net of accrued income taxes. Interest and penalties resulted in an increase to earnings of $12 million in 2022, a reduction of $1 million in 2021 and a reduction to earnings of $4 million in 2020. 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: Canada (2016), Norway (2021) and U.S. (2018). 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. Within the next twelve months, we may have audit periods close that could significantly impact our total unrecognized tax benefits. 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) 2022 2021 2020 2022 2021 2020 Income (loss) before income taxes United States $ 16,739 8,024 (3,587) 59.3 % 63.1 114.2 Foreign 11,489 4,688 447 40.7 36.9 (14.2) $ 28,228 12,712 (3,140) 100.0 % 100.0 100.0 Federal statutory income tax $ 5,928 2,670 (659) 21.0 % 21.0 21.0 Non-U.S. effective tax rates 3,866 1,915 194 13.7 15.1 (6.2) Australia disposition — — (349) — — 11.1 Recovery of outside basis (30) (55) (22) (0.1) (0.4) 0.7 Adjustment to tax reserves (551) (11) 18 (2.0) (0.1) (0.6) Adjustment to valuation allowance 5 (45) 460 — (0.4) (14.6) State income tax 405 194 (112) 1.4 1.5 3.6 Enhanced oil recovery credit (37) (99) (6) (0.1) (0.8) 0.2 Other (38) 64 (9) (0.1) 0.5 0.3 Total $ 9,548 4,633 (485) 33.8 % 36.4 15.5 Our effective tax rate for 2022 was driven by our jurisdictional tax rates for this profit mix with net favorable impacts from routine tax credits and valuation allowance adjustments. The adjustment to tax reserves primarily relates to the closing of the audit of our 2017 U.S. federal tax return and the recognition of the U.S. federal and state tax benefits described above. Our effective tax rate for 2021 was driven by our jurisdictional tax rates for this profit mix with net favorable impacts from routine tax credits and valuation allowance adjustments. The valuation allowance adjustment is primarily related to the fair value measurement and disposition of our CVE common shares of $218 million and the ability to utilize the U.S. foreign tax credit and capital loss carryforward due to our anticipated disposition of our Indonesia entities of $29 million. This was partially offset by an increase to our valuation allowance related to the tax impact of the impairment of our APLNG investment of $206 million for which we do not expect to receive a tax benefit. 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 CVE 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 CVE common shares, the valuation allowance was increased by $178 million to offset the expected capital loss. On August 16, 2022, the U.S. enacted the Inflation Reduction Act of 2022, which among other things, implements a 15 percent minimum tax on book income of certain large corporations, a 1 percent excise tax on net stock repurchases and several tax incentives to promote lower carbon energy. We are continuing to evaluate the impacts of this legislation as additional guidance is released; however, we do not believe any impacts will be material to our consolidated financial statements.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	12 Months Ended
	Dec. 31, 2022
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Accumulated Other Comprehensive Loss	Note 18—Accumulated Other Comprehensive Loss Accumulated other comprehensive loss in the equity section of the balance sheet included: Millions of Dollars Defined Net Foreign Accumulated 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) Other comprehensive income (loss) 394 (2) (124) 268 December 31, 2021 (31) — (4,919) (4,950) Other comprehensive income (loss) (417) (11) (622) (1,050) December 31, 2022 $ (448) (11) (5,541) (6,000) The following table summarizes reclassifications out of accumulated other comprehensive loss during the years ended December 31: Millions of Dollars 2022 2021 Defined Benefit Plans $ 26 109 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 7 31 See Note

Cash Flow Information

Cash Flow Information	12 Months Ended
	Dec. 31, 2022
Supplemental Cash Flow Information [Abstract]
Cash Flow Information	Note 19—Cash Flow Information Millions of Dollars 2022 2021 2020 Noncash Investing Activities Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations $ 825 442 (116) Cash Payments Interest $ 873 924 785 Income taxes 7,368 856 905 Net Sales (Purchases) of Investments Short-term investments purchased $ (5,046) (5,554) (12,435) Short-term investments sold 3,102 8,810 12,015 Investments and long-term receivables purchased (775) (279) (325) Investments and long-term receivables sold 90 114 87 $ (2,629) 3,091 (658) Income tax payments have increased in 2022 as the company is returning to a tax paying position in the U.S. as well as, increased taxes in Norway, and timing of tax payments in Libya. See Note and Note for additional information on cash and non-cash changes to our consolidated balance sheet associated with our Concho acquisition.

Other Financial Information

Other Financial Information	12 Months Ended
	Dec. 31, 2022
Other Income and Expenses [Abstract]
Other Financial Information	Note 20—Other Financial Information Millions of Dollars 2022 2021 2020 Interest and Debt Expense Incurred Debt $ 791 887 788 Other 72 59 73 863 946 861 Capitalized (58) (62) (55) Expensed $ 805 884 806 Other Income (Loss) Interest income $ 195 33 100 Gain (loss) on investment in Cenovus Energy* 251 1,040 (855) Other, net 58 130 246 $ 504 1,203 (509) *See Note . Research and Development Expenditures— expensed $ 71 62 75 Shipping and Handling Costs $ 1,595 1,047 857 Foreign Currency Transaction (Gains) Losses— after-tax Alaska $ — — — Lower 48 — — — Canada (20) (1) (7) Europe, Middle East and North Africa (110) (11) (15) Asia Pacific 30 2 (11) Other International (1) 1 2 Corporate and Other 21 (7) (31) $ (80) (16) (62) Millions of Dollars 2022 2021 Properties, Plants and Equipment Proved properties $ 119,609 114,274 * Unproved properties 7,325 10,993 Other 4,562 4,379 Gross properties, plants and equipment 131,496 129,646 Less: Accumulated depreciation, depletion and amortization (66,630) (64,735) * Net properties, plants and equipment $ 64,866 64,911 *Excludes assets classified as held for sale at December 31, 2021. See Note

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2022
Related Party Transactions [Abstract]
Related Party Transactions	Note 21—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 . Significant transactions with our equity affiliates were: Millions of Dollars 2022 2021 2020 Operating revenues and other income $ 88 88 79 Purchases 1 5 — Operating expenses and selling, general and administrative expenses 189 196 63 Net interest income* (1) (2) (5) *We paid interest to, or received interest from, various affiliates. See Note , for additional information on loans to affiliated companies.

Sales and Other Operating Reven

Sales and Other Operating Revenues	12 Months Ended
	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Sales and Other Operating Revenues	Note 22—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 2022 2021 2020 Revenue from contracts with customers $ 61,049 34,590 13,662 Revenue from contracts outside the scope of ASC Topic 606 Physical contracts meeting the definition of a derivative 17,150 11,500 5,177 Financial derivative contracts 295 (262) (55) Consolidated sales and other operating revenues $ 78,494 45,828 18,784 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 —Segment Disclosures and Related Information : Millions of Dollars 2022 2021 2020 Revenue from Outside the Scope of ASC Topic 606 by Segment Lower 48 $ 13,919 9,050 3,966 Canada 2,717 1,457 727 Europe, Middle East and North Africa 514 993 484 Physical contracts meeting the definition of a derivative $ 17,150 11,500 5,177 Millions of Dollars 2022 2021 2020 Revenue from Outside the Scope of ASC Topic 606 by Product Crude oil $ 495 757 395 Natural gas 15,368 10,034 4,339 Other 1,287 709 443 Physical contracts meeting the definition of a derivative $ 17,150 11,500 5,177 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, 2022, the “Accounts and notes receivable” line on our consolidated balance sheet included trade receivables of $5,241 million compared with $5,268 million at December 31, 2021, 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 certain agreements under which we license our proprietary technology, including the Optimized Cascade® process technology, to customers to maximize the efficiency of LNG plants. These agreements typically provide for milestone payments to be made during and after the construction phases of the LNG plant. The payments are not directly related to our performance obligations under the contract and are recorded as deferred revenue to be recognized when the customer is able to benefit from their right to use the applicable licensed technology. During the year ended December 31, 2022, we recognized revenue of $57 million in the "Sales and other operating revenues" line on our consolidated income statement. We expect to recognize the outstanding contract liabilities of $19 million as of December 31, 2022, as revenue during 2026.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2022
Earnings Per Share [Abstract]
Earnings Per Share	Note 23—Earnings Per Share The following table presents the calculation of net income available to common shareholders and basic and diluted EPS for the years ended December 31, 2022, 2021, and 2020. For each of the periods with net income presented in the table below, diluted EPS calculated under the two-class method was more dilutive. Millions of Dollars (except per share amounts) Years Ended December 31 2022 2021 2020 Basic earnings per share Net Income (Loss) Attributable to ConocoPhillips $ 18,680 8,079 (2,701) Less: Dividends and undistributed earnings allocated to participating securities 60 19 6 Net Income (Loss) available to common shareholders $ 18,620 8,060 (2,707) Average common shares outstanding (in Millions) 1,274 1,324 1,078 Net Income (Loss) Attributable to ConocoPhillips Per Share $ 14.62 6.09 (2.51) Diluted earnings per share Net Income (Loss) available to common shareholders $ 18,620 8,060 (2,707) Average common shares outstanding (in Millions) 1,274 1,324 1,078 Add: Dilutive impact of options and unvested non-participating RSU/PSUs 4 4 — Average diluted shares outstanding (in Millions) 1,278 1,328 1,078 Net Income (Loss) Attributable to ConocoPhillips Per Share $ 14.57 6.07 (2.51)

Segment Disclosures and Related

Segment Disclosures and Related Information	12 Months Ended
	Dec. 31, 2022
Segment Reporting [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 N ote . Intersegment sales are at prices that approximate market. In 2021, we completed our acquisition of Concho, an independent oil and gas exploration and production company with operations across New Mexico and West Texas as well as our acquisition of Shell’s Permian assets in the Texas Delaware Basin. The accounting close date of the Shell transaction, used for reporting purposes, was December 31, 2021. Results of operations for Concho and assets acquired from Shell are included in our Lower 48 segment. Certain transaction and restructuring costs associated with these acquisitions are included in our Corporate and Other segment. See Note 3 . Analysis of Results by Operating Segment Millions of Dollars 2022 2021 2020 Sales and Other Operating Revenues Alaska $ 7,905 5,480 3,408 Intersegment eliminations — — (11) Alaska 7,905 5,480 3,397 Lower 48 52,921 29,306 9,872 Intersegment eliminations (18) (12) (51) Lower 48 52,903 29,294 9,821 Canada 6,159 4,077 1,666 Intersegment eliminations (2,445) (1,583) (405) Canada 3,714 2,494 1,261 Europe, Middle East and North Africa 11,271 5,902 1,919 Intersegment eliminations (1) — (2) Europe, Middle East and North Africa 11,270 5,902 1,917 Asia Pacific 2,606 2,579 2,363 Other International — 4 7 Corporate and Other 96 75 18 Consolidated sales and other operating revenues $ 78,494 45,828 18,784 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 2022 2021 2020 Depreciation, Depletion, Amortization and Impairments Alaska $ 941 1,002 996 Lower 48 4,854 4,067 3,358 Canada 400 392 342 Europe, Middle East and North Africa 735 862 775 Asia Pacific 518 1,483 809 Other International — — — Corporate and Other 44 76 54 Consolidated depreciation, depletion, amortization and impairments $ 7,492 7,882 6,334 Equity in Earnings of Affiliates Alaska $ 4 5 (7) Lower 48 (14) (18) (11) Canada — — — Europe, Middle East and North Africa 780 502 311 Asia Pacific 1,310 343 137 Other International 1 — 2 Corporate and Other — — — Consolidated equity in earnings of affiliates $ 2,081 832 432 Millions of Dollars 2022 2021 2020 Income Tax Provision (Benefit) Alaska $ 885 402 (256) Lower 48 3,088 1,390 (378) Canada 206 150 (185) Europe, Middle East and North Africa 5,445 2,543 136 Asia Pacific 480 483 294 Other International 53 (53) (20) Corporate and Other (609) (282) (76) Consolidated income tax provision (benefit) $ 9,548 4,633 (485) Net Income (Loss) Attributable to ConocoPhillips Alaska $ 2,352 1,386 (719) Lower 48 11,015 4,932 (1,122) Canada 714 458 (326) Europe, Middle East and North Africa 2,244 1,167 448 Asia Pacific 2,736 453 962 Other International (51) (107) (64) Corporate and Other (330) (210) (1,880) Consolidated net income (loss) attributable to ConocoPhillips $ 18,680 8,079 (2,701) Investments in and Advances to Affiliates Alaska $ 55 58 62 Lower 48 235 242 25 Canada — — — Europe, Middle East and North Africa 1,049 797 918 Asia Pacific 6,154 5,603 6,705 Other International — 1 — Corporate and Other — — — Consolidated investments in and advances to affiliates $ 7,493 6,701 7,710 Total Assets Alaska $ 15,126 14,812 14,623 Lower 48 42,950 41,699 11,932 Canada 6,971 7,439 6,863 Europe, Middle East and North Africa 8,263 9,125 8,756 Asia Pacific 9,511 9,840 11,231 Other International — 1 226 Corporate and Other 11,008 7,745 8,987 Consolidated total assets $ 93,829 90,661 62,618 Millions of Dollars 2022 2021 2020 Capital Expenditures and Investments Alaska $ 1,091 982 1,038 Lower 48 5,630 3,129 1,881 Canada 530 203 651 Europe, Middle East and North Africa 998 534 600 Asia Pacific 1,880 390 384 Other International — 33 121 Corporate and Other 30 53 40 Consolidated capital expenditures and investments $ 10,159 5,324 4,715 Interest Income and Expense Interest income Alaska $ — — — Lower 48 — — — Canada — — — Europe, Middle East and North Africa 1 2 5 Asia Pacific 9 9 7 Other International — — — Corporate and Other 185 22 88 Interest and debt expense Corporate and Other $ 805 884 806 Sales and Other Operating Revenues by Product Crude oil $ 41,492 23,648 9,736 Natural gas 26,941 16,904 6,427 Natural gas liquids 3,650 1,668 528 Other* 6,411 3,608 2,093 Consolidated sales and other operating revenues by product $ 78,494 45,828 18,784 *Includes LNG and bitumen. Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2022 2021 2020 2022 2021 2020 United States $ 60,899 34,847 13,230 51,200 50,580 24,034 Australia and Timor-Leste — — 605 6,158 5,579 6,676 Canada 3,714 2,494 1,261 6,269 6,608 6,385 China 1,135 724 460 1,538 1,476 1,491 Indonesia (3) 159 879 689 — 28 464 Libya 1,582 1,102 155 714 659 670 Malaysia 1,312 975 610 1,107 1,252 1,501 Norway 3,415 2,563 1,426 4,369 4,681 5,294 United Kingdom 6,273 2,236 336 1 1 1 Other foreign countries 5 8 12 1,003 748 1,087 Worldwide consolidated $ 78,494 45,828 18,784 72,359 71,612 47,603 (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. (3) Assets divested in 2022. See Note 3 .

Accounting Policies (Policy)

Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2022
Accounting Policies [Abstract]
Consolidation Principles and Investments	Consolidation Principles and Investments—Our consolidated financial statements include the accounts of majority-owned, controlled subsidiaries and, if applicable, 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.
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 U.S. GAAP 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.
Shipping and Handling Costs	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 —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—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 of one year or less, as of the balance sheet date.
Long-Term Investments in Debt Securities	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.
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 . 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 development costs is based on the unit-of-production method using estimated proved developed oil and gas reserves.
Capitalized Interest	Capitalized Interest —Interest from external borrowings is capitalized on major projects with an expected construction period of one year or longer. Capitalized interest is added to the cost of the underlying asset and is amortized over the useful lives of the assets in the same 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 —Long-lived assets 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 for prices, volumes and future development plans. If 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 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. The expected future cash flows used for impairment reviews and related fair value calculations are based on estimated future production volumes, commodity prices, operating costs and capital decisions, 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. 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.
Maintenace 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 partial 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. See Note .
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.
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.
Share-Based Compensation	Share-Based Compensation —We recognize share-based compensation expense over the shorter of the service period (i.e., the stated period of time required to earn the award) or the period beginning at the start of the service period and ending when an employee first becomes eligible for retirement. We have elected to recognize expense on a straight-line basis over the service period for the entire award, whether the award was granted with ratable or cliff vesting.
Income Taxes	Income Taxes —Deferred income taxes are computed using the liability method and are provided on all temporary differences between the financial reporting basis and the tax basis of our assets and liabilities, except for deferred taxes on income and temporary differences related to the 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 (EPS) is calculated using the two-class method. Under the two-class method, all earnings (distributed and undistributed) are allocated to common stock (including fully vested stock and unit awards that have not yet been issued as common stock) and participating securities. ConocoPhillips grants RSUs under its share-based compensation programs, the majority of which entitle recipients to receive non-forfeitable dividends during the vesting period on a basis equivalent to dividends paid to holders of the Company’s common stock. See Note

Inventories (Tables)

Inventories (Tables)	12 Months Ended
	Dec. 31, 2022
Inventory Disclosure [Abstract]
Schedule of Inventories	Inventories at December 31 were: Millions of Dollars 2022 2021 Crude oil and natural gas $ 641 647 Materials and supplies 578 561 Total inventories $ 1,219 1,208 Inventories valued on the LIFO basis $ 396 395

Acquisitions and Dispositions (

Acquisitions and Dispositions (Tables)	12 Months Ended
	Dec. 31, 2022
Business Combination, Asset Acquisition And Dispositions [Abstract]
Schedule of Business Combination	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.
Schedule of Assets Acquired and Liabilities Assumed	Assets Acquired Millions of Dollars Cash and cash equivalents $ 382 Accounts receivable, net 745 Inventories 45 Prepaid expenses and other current assets 37 Investments and long-term receivables 333 Net properties, plants and equipment 18,923 Other assets 62 Total assets acquired $ 20,527 Liabilities Assumed Accounts payable $ 638 Accrued income and other taxes 56 Employee benefit obligations 4 Other accruals 510 Long-term debt 4,696 Asset retirement obligations and accrued environmental costs 310 Deferred income taxes 1,071 Other liabilities and deferred credits 117 Total liabilities assumed $ 7,402 Net assets acquired $ 13,125 Assets Acquired Millions of Dollars Accounts receivable, net $ 337 Inventories 20 Net properties, plants and equipment 8,582 Other assets 50 Total assets acquired $ 8,989 Liabilities Assumed Accounts payable $ 206 Accrued income and other taxes 6 Other accruals 20 Asset retirement obligations and accrued environmental costs 86 Other liabilities and deferred credits 36 Total liabilities assumed $ 354 Net assets acquired $ 8,635
Schedule of Non-Recurring Restructuring and Transition-Related Costs	The impact from the transaction and restructuring costs to the lines of our consolidated income statement for the year ended December 31, 2021, are below: Millions of Dollars Transaction Cost Restructuring Cost Total Cost Production and operating expenses 128 128 Selling, general and administration expenses 135 67 202 Exploration expenses 18 8 26 Taxes other than income taxes 4 2 6 Other expenses — 29 29 $ 157 234 391
Schedule of Supplemental Pro Forma Financial Information	The following tables summarize the unaudited supplemental pro forma financial information for the year ended December 31, 2021, and 2020, as if we had completed the acquisitions of Concho and the Shell Permian assets on January 1, 2020. Millions of Dollars Year Ended December 31, 2021 As reported Pro forma Pro forma Total Revenues and Other Income $ 48,349 3,220 51,569 Income (loss) before income taxes 12,712 1,201 13,913 Net Income (Loss) attributable to ConocoPhillips 8,079 920 8,999 Earnings per share: Basic net income $ 6.09 6.78 Diluted net income 6.07 6.76 Millions of Dollars Year Ended December 31, 2020 As reported Pro forma Pro forma Pro forma Total Revenues and Other Income $ 19,256 3,762 1,685 24,703 Income (loss) before income taxes (3,140) 787 (247) (2,600) Net Income (Loss) attributable to ConocoPhillips (2,701) 498 (189) (2,392) Earnings per share: Basic net loss $ (2.51) (1.75) Diluted net loss (2.51) (1.75)

Investments, Loans and Long-T_2

Investments, Loans and Long-Term Receivables (Tables)	12 Months Ended
	Dec. 31, 2022
Equity Method Investments and Joint Ventures [Abstract]
Components of Investments, Loans and Long-Term Receivables	Components of investments and long-term receivables at December 31 were: Millions of Dollars 2022 2021 Equity investments $ 7,493 6,701 Long-term receivables 142 98 Long-term investments in debt securities 522 248 Other investments 68 66 $ 8,225 7,113
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 2022 2021 2020 Revenues $ 18,356 11,824 7,931 Income before income taxes 8,234 3,946 1,843 Net income 5,507 2,557 1,426 Summarized 100 percent balance sheet information for equity method investments in affiliated companies, combined, was as follows: Millions of Dollars 2022 2021 Current assets $ 5,001 4,493 Noncurrent assets 37,789 36,602 Current liabilities 4,169 3,498 Noncurrent liabilities 17,244 17,465

Investment in Cenovus Energy (T

Investment in Cenovus Energy (Tables)	12 Months Ended
	Dec. 31, 2022
Investments, Debt and Equity Securities [Abstract]
Gains and Losses Recorded in Other Income (Loss)	Millions of Dollars 2022 2021 2020 Total Net gain (loss) on equity securities $ 251 1,040 (855) Less: Net gain (loss) on equity securities sold during the period 251 473 Unrealized gain (loss) on equity securities still held at the reporting date $ 567 (855)

Suspended Wells and Explorati_2

Suspended Wells and Exploration Expenses (Tables)	12 Months Ended
	Dec. 31, 2022
Extractive Industries [Abstract]
Net Changes in Suspended Exploratory Well Costs	The following table reflects the net changes in suspended exploratory well costs during 2022, 2021 and 2020: Millions of Dollars 2022 2021 2020 Beginning balance at January 1 $ 660 682 1,020 Additions pending the determination of proved reserves 5 10 164 Reclassifications to proved properties (7) — (42) Sales of suspended wells — — (313) Charged to dry hole expense (131) (32) (147) Ending balance at December 31 $ 527 660 682
Aging of Suspended Well Cost	The following table provides an aging of suspended well balances at December 31: Millions of Dollars 2022 2021 2020 Exploratory well costs capitalized for a period of one year or less $ 15 4 156 Exploratory well costs capitalized for a period greater than one year 512 656 526 Ending balance $ 527 660 682 Number of projects with exploratory well costs capitalized for a period greater than one year 17 22 22
Aging of Exploratory Well Cost, 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, 2022: Millions of Dollars Suspended Since Total 2019-2021 2016-2018 2006-2015 Willow—Alaska (2) 315 201 114 — PL 1009—Norway (1) 39 39 — — PL 891—Norway (1) 31 31 — — Narwhal Trend—Alaska (1) 25 — 25 — WL4-00—Malaysia (2) 24 7 17 — PL782S—Norway (1) 19 19 — — Montney—Canada (1) 12 4 8 — Other of $10 million or less each (1)(2) 47 7 10 30 Total $ 512 308 174 30 (1) Additional appraisal wells planned. (2) Appraisal drilling complete; costs being incurred to assess development.

Impairments (Tables)

Impairments (Tables)	12 Months Ended
	Dec. 31, 2022
Asset Impairment Charges [Abstract]
Schedule of Before-tax Impairment Charges	During 2022, 2021 and 2020, we recognized the following before-tax impairment charges: Millions of Dollars 2022 2021 2020 Alaska $ 2 5 — Lower 48 (11) (8) 804 Canada (2) 6 3 Europe, Middle East and North Africa (1) (24) 6 Asia Pacific — 695 — $ (12) 674 813

Asset Retirement Obligations _2

Asset Retirement Obligations and Accrued Environmental Costs (Tables)	12 Months Ended
	Dec. 31, 2022
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligations and Accrued Environmental Costs	Asset retirement obligations and accrued environmental costs at December 31 were: Millions of Dollars 2022 2021 Asset retirement obligations $ 6,380 5,926 Accrued environmental costs 182 187 Total asset retirement obligations and accrued environmental costs 6,562 6,113 Asset retirement obligations and accrued environmental costs due within one year* (161) (359) Long-term asset retirement obligations and accrued environmental costs $ 6,401 5,754
Changes in Asset Retirement Obligation	During 2022 and 2021, our overall ARO changed as follows: Millions of Dollars 2022 2021 Balance at January 1 $ 5,926 5,573 Accretion of discount 245 238 New obligations 144 555 Changes in estimates of existing obligations 681 (113) Spending on existing obligations (231) (164) Property dispositions (203) (108) Foreign currency translation (182) (55) Balance at December 31 $ 6,380 5,926

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2022
Debt Disclosure [Abstract]
Schedule of Debt	Long-term debt at December 31 was: Millions of Dollars 2022 2021 2.40% Notes due 2022 — 329 7.65% Debentures due 2023 78 78 3.35% Notes due 2024 426 426 2.125% Notes due 2024 900 — 8.2% Notes due 2025 134 134 3.35% Debentures due 2025 199 199 2.40% Notes due 2025 900 — 6.875% Debentures due 2026 67 67 4.95% Notes due 2026 — 1,250 7.8% Debentures due 2027 203 203 3.75% Notes due 2027 196 1,000 4.3% Notes due 2028 223 1,000 7.375% Debentures due 2029 92 92 7.0% Debentures due 2029 112 200 6.95% Notes due 2029 1,195 1,549 8.125% Notes due 2030 390 390 7.4% Notes due 2031 382 500 7.25% Notes due 2031 400 500 7.2% Notes due 2031 447 575 2.4% Notes due 2031 227 500 5.9% Notes due 2032 505 505 4.15% Notes due 2034 246 246 5.95% Notes due 2036 326 500 5.951% Notes due 2037 631 645 5.9% Notes due 2038 350 600 6.5% Notes due 2039 1,588 2,750 3.758% Notes due 2042 785 — 4.3% Notes due 2044 750 750 5.95% Notes due 2046 329 500 7.9% Debentures due 2047 60 60 4.875% Notes due 2047 319 800 4.85% Notes due 2048 219 600 3.8% Notes due 2052 1,100 — 4.025% Notes due 2062 1,770 — Floating rate notes due 2022 at 1.06% – 1.41% during 2022 and 1.02% – 1.12% during 2021 — 500 Marine Terminal Revenue Refunding Bonds due 2031 at 0.07% – 4.10% during 2022 and 0.04% – 0.15% during 2021 265 265 Industrial Development Bonds due 2035 at 0.07% – 4.10% during 2022 and 0.04% – 0.12% during 2021 18 18 Other 23 35 Debt at face value 15,855 17,766 Finance leases 1,320 1,261 Net unamortized premiums, discounts and debt issuance costs (532) 907 Total debt 16,643 19,934 Short-term debt (417) (1,200) Long-term debt $ 16,226 18,734

Derivative and Financial Inst_2

Derivative and Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2022
Derivative Instruments and Hedging Activities Disclosure [Abstract]
Balance Sheet Location - Fair Value Amounts of Derivatives, Balance Sheet Location	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 2022 2021 Assets Prepaid expenses and other current assets $ 1,795 1,168 Other assets 242 75 Liabilities Other accruals 1,800 1,160 Other liabilities and deferred credits 210 63
Gain (Loss) Amounts of Derivatives, Income Statement Location	The gains (losses) from commodity derivatives incurred, and the line items where they appear on our consolidated income statement were: Millions of Dollars 2022 2021 2020 Sales and other operating revenues $ (88) (228) 19 Other income (loss) (5) 25 4 Purchased commodities (91) 75 11
Net Exposures from Outstanding Derivative Contracts	The table below summarizes our net exposures resulting from outstanding commodity derivative contracts: Open Position 2022 2021 Commodity Natural gas and power (billions of cubic feet equivalent) Fixed price (14) 4 Basis (8) (22)
Net Carrying Amount of Investments and Long-term Receivables Carried at Cost plus Accrued Interest	The following investments are carried on our consolidated balance sheet at cost, plus accrued interest and the table reflects remaining maturities at December 31, 2022 and 2021: Millions of Dollars Carrying Amount Cash and Cash Short-Term 2022 2021 2022 2021 Cash $ 593 670 Demand Deposits 1,638 1,554 Time Deposits 1 to 90 days 4,116 2,363 1,288 217 91 to 180 days 883 4 Within one year 11 4 U.S. Government Obligations 1 to 90 days 14 431 — — $ 6,361 5,018 2,182 225
Debt Securities, Available-for-Sale	The following investments in debt securities classified as available for sale are carried at fair value on our consolidated balance sheet at December 31, 2022 and 2021: Millions of Dollars Carrying Amount Cash and Cash Short-Term Investments and Long-Term 2022 2021 2022 2021 2022 2021 Major Security Type Corporate Bonds $ — 3 323 128 309 173 Commercial Paper 97 7 156 82 U.S. Government Obligations — — 115 — 63 2 U.S. Government Agency Obligations 8 2 5 8 Foreign Government Obligations — 7 7 2 Asset-backed Securities 1 2 138 63 $ 97 10 603 221 522 248 The following table summarizes the amortized cost basis and fair value of investments in debt securities classified as available for sale at December 31: Millions of Dollars Amortized Cost Basis Fair Value 2022 2021 2022 2021 Major Security Type Corporate Bonds $ 641 305 632 304 Commercial Paper 253 88 253 89 U.S. Government Obligations 181 2 178 2 U.S. Government Agency Obligations 13 10 13 10 Foreign Government Obligations 7 9 7 9 Asset-backed Securities 139 65 139 65 $ 1,234 479 1,222 479

Fair Value Measurement (Tables)

Fair Value Measurement (Tables)	12 Months Ended
	Dec. 31, 2022
Fair Value Disclosures [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, 2022 December 31, 2021 Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total Assets Investment in Cenovus Energy $ 1,117 — — 1,117 Investments in debt securities 178 1,044 — 1,222 2 477 — 479 Commodity derivatives 958 951 128 2,037 562 619 62 1,243 Total assets $ 1,136 1,995 128 3,259 1,681 1,096 62 2,839 Liabilities Commodity derivatives $ 906 843 261 2,010 593 543 87 1,223 Total liabilities $ 906 843 261 2,010 593 543 87 1,223
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 Gross Net Cash Net December 31, 2022 Assets $ 2,037 39 1,998 1,176 822 37 785 Liabilities 2,010 20 1,990 1,176 814 52 762 December 31, 2021 Assets $ 1,243 85 1,158 650 508 — 508 Liabilities 1,223 82 1,141 650 491 36 455
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 Level 2 Level 3 Before-Tax Year ended December 31, 2021 Net PP&E (held for use) December 31, 2021 $ 472 — — 472 80 Equity Method Investments December 31, 2021 5,574 — 5,574 — 688
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 Valuation Unobservable Inputs Range (Arithmetic Average) December 31, 2021 Lower 48 Gulf Coast and Rockies noncore field $ 472 Discounted cash flow Commodity production (MBOED) 0.2 - 17 (5.4) Commodity price outlook* ($/BOE) $41.45 - $93.68 ($64.39) Discount rate** 7.3% - 9.7% (8.7%) *Commodity price outlook based on a combination of external pricing service companies' and our internal outlook for years 2024-2050; 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.
Schedule of Net Fair Value of 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 2022 2021 2022 2021 Financial assets Investment in CVE common shares $ — 1,117 $ — 1,117 Commodity derivatives 824 593 824 593 Investments in debt securities 1,222 479 1,222 479 Loans and advances—related parties — 114 — 114 Financial liabilities Total debt, excluding finance leases 15,323 18,673 15,545 22,451 Commodity derivatives 782 537 782 537

Equity (Tables)

Equity (Tables)	12 Months Ended
	Dec. 31, 2022
Equity [Abstract]
Changes in Shares of Common Stock	Common Stock The changes in our shares of common stock, as categorized in the equity section of the balance sheet, were: Shares 2022 2021 2020 Issued Beginning of year 2,091,562,747 1,798,844,267 1,795,652,203 Acquisition of Concho — 285,928,872 — Distributed under benefit plans 9,322,387 6,789,608 3,192,064 End of year 2,100,885,134 2,091,562,747 1,798,844,267 Held in Treasury Beginning of year 789,319,875 730,802,089 710,783,814 Repurchase of common stock 87,709,187 58,517,786 20,018,275 End of year 877,029,062 789,319,875 730,802,089

Non-Mineral Lease (Tables)

Non-Mineral Lease (Tables)	12 Months Ended
	Dec. 31, 2022
Leases [Abstract]
Right-of-Use Assets and Lease Liabilities	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 2022 2021 Operating Finance Operating Finance Right-of-Use Assets Properties, plants and equipment Gross 2,043 1,812 Accumulated DD&A (1,022) (857) Net PP&E* 1,021 955 Prepaid expenses and other current assets 16 2 Other assets 536 649 Lease Liabilities Short-term debt** 284 280 Other accruals 155 188 Long-term debt*** 1,036 981 Other liabilities and deferred credits 390 479 Total lease liabilities $ 545 1,320 667 1,261 * Includes proportionately consolidated finance lease assets of $171 million at December 31, 2022 and $208 million at December 31, 2021. ** Includes proportionately consolidated finance lease liabilities of $169 million at December 31, 2022 and $154 million at December 31, 2021.
Lease Cost	The following table summarizes our lease costs: Millions of Dollars 2022 2021 2020 Lease Cost* Operating lease cost $ 212 278 321 Finance lease cost Amortization of right-of-use assets 189 148 163 Interest on lease liabilities 32 27 34 Short-term lease cost** 94 21 42 Total lease cost*** $ 527 474 560 * 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.
Lease Term and Discount Rate	The following table summarizes the lease terms and discount rates as of December 31: 2022 2021 Lease Term and Discount Rate Weighted-average term (years) Operating leases 5.64 5.97 Finance leases 6.60 7.49 Weighted-average discount rate (percent) Operating leases 2.99 2.66 Finance leases 3.40 3.24
Other Information	The following table summarizes other lease information: Millions of Dollars 2022 2021 2020 Other Information* Cash paid for amounts included in the measurement of lease liabilities Operating cash flows from operating leases $ 148 204 232 Operating cash flows from finance leases 30 6 11 Financing cash flows from finance leases 166 73 255 Right-of-use assets obtained in exchange for operating lease liabilities $ 114 174 250 Right-of-use assets obtained in exchange for finance lease liabilities 256 447 426 *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.
Maturity of Lease Liabilities	The following table summarizes future lease payments for operating and finance leases at December 31, 2022: Millions of Dollars Operating Leases Finance Leases Maturity of Lease Liabilities 2023 $ 169 356 2024 126 215 2025 81 210 2026 59 207 2027 46 164 Remaining years 118 352 Total* 599 1,504 Less: portion representing imputed interest (54) (184) Total lease liabilities $ 545 $ 1,320 *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.

Employee Benefit Plans (Tables)

Employee Benefit Plans (Tables)	12 Months Ended
	Dec. 31, 2022
Retirement Benefits [Abstract]
Change in Benefit Obligations and Fair Value of Plan Assets	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 2022 2021 2022 2021 U.S. Int’l. U.S. Int’l. Change in Benefit Obligation Benefit obligation at January 1 $ 1,924 4,124 2,548 4,403 137 170 Service cost 58 47 73 61 1 2 Interest cost 62 77 53 79 4 4 Plan participant contributions — — — — 16 16 Plan amendments — — — — 9 — Actuarial (gain) loss (325) (847) (117) (176) (27) (16) Benefits paid (241) (144) (654) (162) (38) (40) Divestiture — (56) — — — — Curtailment — — 12 — — 1 Recognition of termination benefits — — 9 — — — Foreign currency exchange rate change — (425) — (81) — — Benefit obligation at December 31* $ 1,478 2,776 1,924 4,124 102 137 *Accumulated benefit obligation portion of above at December 31: $ 1,384 2,542 1,793 3,658 Change in Fair Value of Plan Assets Fair value of plan assets at January 1 $ 1,664 4,812 1,770 4,793 — — Actual return on plan assets (319) (1,372) 97 147 — — Company contributions 75 96 451 119 22 24 Plan participant contributions — 1 — 1 16 16 Benefits paid (241) (144) (654) (162) (38) (40) Divestiture — (46) — — — — Foreign currency exchange rate change — (468) — (86) — — Fair value of plan assets at December 31 $ 1,179 2,879 1,664 4,812 — — Funded Status $ (299) 103 (260) 688 (102) (137)
Amounts Recognized in Balance Sheet and Assumptions	Millions of Dollars Pension Benefits Other Benefits 2022 2021 2022 2021 U.S. Int’l. U.S. Int’l. Amounts Recognized in the Consolidated Balance Sheet at December 31 Noncurrent assets $ — 373 1 991 — — Current liabilities (28) (10) (29) (15) (32) (34) Noncurrent liabilities (271) (260) (232) (288) (70) (103) Total recognized $ (299) 103 (260) 688 (102) (137) Weighted-Average Assumptions Used to Determine Benefit Obligations at December 31 Discount rate 5.65 % 4.20 2.80 2.15 5.65 2.65 Rate of compensation increase 5.00 3.65 4.00 3.40 Interest crediting rate for applicable benefits 3.55 2.50 Weighted-Average Assumptions Used to Determine Net Periodic Benefit Cost for Years Ended December 31 Discount rate 3.85 % 2.15 2.60 1.80 2.65 2.35 Expected return on plan assets 3.90 2.85 5.20 2.50 Rate of compensation increase 4.00 3.40 4.00 3.40 Interest crediting rate for applicable benefits 2.50 2.10
Projected and Accumulated Benefit Obligations in Excess of Fair Value	The following tables summarize information related to the Company's pension plans with projected and accumulated benefit obligations in excess of the fair value of the plans' assets: Millions of Dollars Pension Benefits 2022 2021 U.S. Int’l. U.S. Int’l. Pension Plans with Projected Benefit Obligation in Excess of Plan Assets Projected benefit obligation $ 1,478 277 261 362 Fair value of plan assets 1,179 6 — 58 Pension Plans with Accumulated Benefit Obligation in Excess of Plan Assets Accumulated benefit obligation $ 1,384 239 234 271 Fair value of plan assets 1,179 6 — 9
Before-Tax Amounts not Recognized in Net Periodic 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 2022 2021 2022 2021 U.S. Int’l. U.S. Int’l. Unrecognized net actuarial loss (gain) $ 172 681 188 86 (28) (1) Unrecognized prior service cost (credit) — 1 — 1 (98) (145)
Source of Change in Other Comprehensive Income (Loss)	Millions of Dollars Pension Benefits Other Benefits 2022 2021 2022 2021 U.S. Int’l. U.S. Int’l. Sources of Change in Other Comprehensive Income (Loss) Net gain (loss) arising during the period $ (44) (606) 134 207 27 16 Amortization of actuarial loss included in income (loss)* 61 11 145 33 — — Net change during the period $ 17 (595) 279 240 27 16 Prior service credit (cost) arising during the period $ — (1) — — (9) — Amortization of prior service (credit) included in income (loss) — (1) — (1) (38) (37) Net change during the period $ — (2) — (1) (47) (37) *Includes settlement (gains) losses recognized in 2022 and 2021.
Components of Net Periodic Benefit Cost	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 2022 2021 2020 2022 2021 2020 U.S. Int’l. U.S. Int’l. U.S. Int’l. Components of Net Periodic Benefit Cost Service cost $ 58 47 73 61 85 54 1 2 2 Interest cost 62 77 53 79 66 85 4 4 6 Expected return on plan assets (50) (124) (80) (120) (85) (145) — — — Amortization of prior service credit — (1) — (1) — (1) (38) (37) (31) Recognized net actuarial loss (gain) 24 11 43 33 51 22 — — 1 Settlements loss (gain) 37 — 102 — 44 (1) — — — Curtailment loss — — 12 — — — — — — Net periodic benefit cost $ 131 10 203 52 161 14 (33) (31) (22)
Fair Values of 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 2022 Equity securities U.S. $ 4 — — 4 — — — — International 36 — — 36 — — — — Mutual funds 14 — — 14 201 298 — 499 Debt securities Corporate — 1 — 1 — — — — Mutual funds — — — — 365 — — 365 Cash and cash equivalents — — — — 36 — — 36 Real estate — — — — — — 146 146 Total in fair value hierarchy $ 54 1 — 55 602 298 146 1,046 Investments measured at net asset value* Equity securities Common/collective trusts 265 192 Debt securities Common/collective trusts 759 1,637 Cash and cash equivalents 10 — Real estate 34 — Total** $ 54 1 — 1,123 602 298 146 2,875 *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 $55 million and net receivables related to security transactions of $5 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 2021 Equity securities U.S. $ 3 — 5 8 — — — — International 42 — — 42 — — — — Mutual funds 17 — — 17 236 403 — 639 Debt securities Corporate — 1 — 1 — — — — Mutual funds — — — — 511 — — 511 Cash and cash equivalents — — — — 68 — — 68 Derivatives — — — — — — — — Real estate — — — — — — 157 157 Total in fair value hierarchy $ 62 1 5 68 815 403 157 1,375 Investments measured at net asset value* Equity securities Common/collective trusts 394 417 Debt securities Common/collective trusts 1,073 3,015 Cash and cash equivalents 9 — Real estate 36 1 Total** $ 62 1 5 1,580 815 403 157 4,808 *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.
Benefit Payments	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 U.S. Int’l. 2023 $ 216 121 17 2024 199 123 15 2025 188 125 14 2026 173 126 12 2027 171 128 11 2028–2032 685 677 38
Severance Accrual	The following table summarizes our severance accrual activity: Millions of Dollars 2022 2021 2020 Balance at January 1 $ 78 24 23 Accruals 1 170 14 Benefit payments (48) (116) (13) Balance at December 31 $ 31 78 24
Compensation Expense	Compensation Expense —Total share-based compensation expense recognized in net income (loss) and the associated tax benefit were: Millions of Dollars 2022 2021 2020 Compensation cost $ 377 304 159 Tax benefit 95 76 40
Stock Option Activity	The following summarizes our stock option activity for the year ended December 31, 2022: Millions of Dollars Options Weighted-Average Aggregate Outstanding at December 31, 2021 11,973,783 $ 56.46 $ 188 Exercised (7,670,208) 57.12 (308) Expired or cancelled — — Outstanding at December 31, 2022 4,303,575 $ 55.28 $ 266 Vested at December 31, 2022 4,303,575 $ 55.28 $ 266 Exercisable at December 31, 2022 4,303,575 $ 55.28 $ 266
Restricted Stock Unit Activity	The following summarizes our stock-settled stock unit activity for the year ended December 31, 2022: Stock Units Weighted-Average Millions of Dollars Total Fair Value Outstanding at December 31, 2021 7,645,311 $ 53.81 Granted 2,139,168 90.57 Forfeited (137,011) 71.38 Issued (2,069,275) 63.57 $ 193 Outstanding at December 31, 2022 7,578,193 $ 61.20 Not Vested at December 31, 2022 5,264,282 $ 61.58 The following summarizes our cash-settled stock unit activity for the year ended December 31, 2022: Stock Units Weighted-Average Grant Date Fair Value Millions of Dollars Total Fair Value Outstanding at December 31, 2021 226,476 $ 72.18 Granted 531 85.37 Forfeited — — Issued (227,007) 91.47 $ 21 Outstanding at December 31, 2022 — $ —
Performance Share Program Activity	The following summarizes our stock-settled Performance Share Program activity for the year ended December 31, 2022: Weighted-Average Millions of Dollars Stock Units Total Fair Value Outstanding at December 31, 2021 1,448,847 $ 50.69 Granted 1,754 91.58 Issued (218,986) 51.04 $ 21 Outstanding at December 31, 2022 1,231,615 $ 50.68 The following summarizes our cash-settled Performance Share Program activity for the year ended December 31, 2022: Weighted-Average Millions of Dollars Stock Units Total Fair Value Outstanding at December 31, 2021 117,679 $ 72.18 Granted 967,151 91.58 Settled (975,007) 89.87 $ 88 Outstanding at December 31, 2022 109,823 $ 117.11
Restricted Shares and Units Aggregate Activity	The following summarizes the aggregate activity of these restricted shares and units for the year ended December 31, 2022: Weighted-Average Millions of Dollars Stock Units Total Fair Value Outstanding at December 31, 2021 1,616,367 $ 47.24 Granted 73,450 96.20 Cancelled (1,030) 24.61 Issued (449,028) 48.28 $ 40 Outstanding at December 31, 2022 1,239,759 $ 49.78 Not Vested at December 31, 2022 437,994 $ 45.90

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2022
Income Tax Disclosure [Abstract]
Income Taxes Charged to Income (Loss)	Components of income tax provision (benefit) were: Millions of Dollars 2022 2021 2020 Income Taxes Federal Current $ 1,263 32 3 Deferred 1,629 1,161 (625) Foreign Current 5,813 3,128 350 Deferred 387 66 (70) State and local Current 386 127 (4) Deferred 70 119 (139) Total tax provision (benefit) $ 9,548 4,633 (485)
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 2022 2021 Deferred Tax Liabilities PP&E and intangibles $ 11,100 10,170 Inventory 48 44 Other 190 213 Total deferred tax liabilities 11,338 10,427 Deferred Tax Assets Benefit plan accruals 450 321 Asset retirement obligations and accrued environmental costs 2,333 2,297 Investments in joint ventures 1,917 1,684 Other financial accruals and deferrals 736 827 Loss and credit carryforwards 6,354 7,402 Other 112 399 Total deferred tax assets 11,902 12,930 Less: valuation allowance (8,049) (8,342) Total deferred tax assets net of valuation allowance 3,853 4,588 Net deferred tax liabilities $ 7,485 5,839
Reconciliation of Deferred Tax Asset Valuation Allowance	The following table shows a reconciliation of the beginning and ending deferred tax asset valuation allowance for 2022, 2021 and 2020: Millions of Dollars 2022 2021 2020 Balance at January 1 $ 8,342 9,965 10,214 Charged to expense (benefit) 5 (45) 460 Other* (298) (1,578) (709) Balance at December 31 $ 8,049 8,342 9,965 *Represents changes due to originating deferred tax assets that have no impact to our effective tax rate, acquisitions/dispositions/revisions and the effect of translating foreign financial statements.
Reconciliation of Unrecognized Tax Benefits	The following table shows a reconciliation of the beginning and ending unrecognized tax benefits for 2022, 2021 and 2020: Millions of Dollars 2022 2021 2020 Balance at January 1 $ 1,345 1,206 1,177 Additions based on tax positions related to the current year 6 15 6 Additions for tax positions of prior years 6 177 67 Reductions for tax positions of prior years (62) (5) (34) Settlements (510) — (9) Lapse of statute (75) (48) (1) Balance at December 31 $ 710 1,345 1,206
Effective Income Tax Rate Reconciliation	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) 2022 2021 2020 2022 2021 2020 Income (loss) before income taxes United States $ 16,739 8,024 (3,587) 59.3 % 63.1 114.2 Foreign 11,489 4,688 447 40.7 36.9 (14.2) $ 28,228 12,712 (3,140) 100.0 % 100.0 100.0 Federal statutory income tax $ 5,928 2,670 (659) 21.0 % 21.0 21.0 Non-U.S. effective tax rates 3,866 1,915 194 13.7 15.1 (6.2) Australia disposition — — (349) — — 11.1 Recovery of outside basis (30) (55) (22) (0.1) (0.4) 0.7 Adjustment to tax reserves (551) (11) 18 (2.0) (0.1) (0.6) Adjustment to valuation allowance 5 (45) 460 — (0.4) (14.6) State income tax 405 194 (112) 1.4 1.5 3.6 Enhanced oil recovery credit (37) (99) (6) (0.1) (0.8) 0.2 Other (38) 64 (9) (0.1) 0.5 0.3 Total $ 9,548 4,633 (485) 33.8 % 36.4 15.5

Accumulated Other Comprehensi_2

Accumulated Other Comprehensive Loss (Tables)	12 Months Ended
	Dec. 31, 2022
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Components of Accumulated Other Comprehensive Loss in the Equity Section of the Balance Sheet	Accumulated other comprehensive loss in the equity section of the balance sheet included: Millions of Dollars Defined Net Foreign Accumulated 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) Other comprehensive income (loss) 394 (2) (124) 268 December 31, 2021 (31) — (4,919) (4,950) Other comprehensive income (loss) (417) (11) (622) (1,050) December 31, 2022 $ (448) (11) (5,541) (6,000)
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 2022 2021 Defined Benefit Plans $ 26 109 Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of: $ 7 31 See Note

Cash Flow Information (Tables)

Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2022
Supplemental Cash Flow Information [Abstract]
Cash Flow Information	Millions of Dollars 2022 2021 2020 Noncash Investing Activities Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations $ 825 442 (116) Cash Payments Interest $ 873 924 785 Income taxes 7,368 856 905 Net Sales (Purchases) of Investments Short-term investments purchased $ (5,046) (5,554) (12,435) Short-term investments sold 3,102 8,810 12,015 Investments and long-term receivables purchased (775) (279) (325) Investments and long-term receivables sold 90 114 87 $ (2,629) 3,091 (658)

Other Financial Information (Ta

Other Financial Information (Tables)	12 Months Ended
	Dec. 31, 2022
Other Income and Expenses [Abstract]
Other Financial Information	Millions of Dollars 2022 2021 2020 Interest and Debt Expense Incurred Debt $ 791 887 788 Other 72 59 73 863 946 861 Capitalized (58) (62) (55) Expensed $ 805 884 806 Other Income (Loss) Interest income $ 195 33 100 Gain (loss) on investment in Cenovus Energy* 251 1,040 (855) Other, net 58 130 246 $ 504 1,203 (509) *See Note . Research and Development Expenditures— expensed $ 71 62 75 Shipping and Handling Costs $ 1,595 1,047 857 Foreign Currency Transaction (Gains) Losses— after-tax Alaska $ — — — Lower 48 — — — Canada (20) (1) (7) Europe, Middle East and North Africa (110) (11) (15) Asia Pacific 30 2 (11) Other International (1) 1 2 Corporate and Other 21 (7) (31) $ (80) (16) (62)
Property Plant And Equipment	Millions of Dollars 2022 2021 Properties, Plants and Equipment Proved properties $ 119,609 114,274 * Unproved properties 7,325 10,993 Other 4,562 4,379 Gross properties, plants and equipment 131,496 129,646 Less: Accumulated depreciation, depletion and amortization (66,630) (64,735) * Net properties, plants and equipment $ 64,866 64,911 *Excludes assets classified as held for sale at December 31, 2021. See Note

Related Party Transactions (Tab

Related Party Transactions (Tables)	12 Months Ended
	Dec. 31, 2022
Related Party Transactions [Abstract]
Significant Transactions with Related Parties	Significant transactions with our equity affiliates were: Millions of Dollars 2022 2021 2020 Operating revenues and other income $ 88 88 79 Purchases 1 5 — Operating expenses and selling, general and administrative expenses 189 196 63 Net interest income* (1) (2) (5) *We paid interest to, or received interest from, various affiliates. See Note , for additional information on loans to affiliated companies.

Sales and Other Operating Rev_2

Sales and Other Operating Revenues (Tables)	12 Months Ended
	Dec. 31, 2022
Revenue from Contract with Customer [Abstract]
Disaggregation of Revenue	Revenue from Contracts with Customers The following table provides further disaggregation of our consolidated sales and other operating revenues: Millions of Dollars 2022 2021 2020 Revenue from contracts with customers $ 61,049 34,590 13,662 Revenue from contracts outside the scope of ASC Topic 606 Physical contracts meeting the definition of a derivative 17,150 11,500 5,177 Financial derivative contracts 295 (262) (55) Consolidated sales and other operating revenues $ 78,494 45,828 18,784 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 —Segment Disclosures and Related Information : Millions of Dollars 2022 2021 2020 Revenue from Outside the Scope of ASC Topic 606 by Segment Lower 48 $ 13,919 9,050 3,966 Canada 2,717 1,457 727 Europe, Middle East and North Africa 514 993 484 Physical contracts meeting the definition of a derivative $ 17,150 11,500 5,177 Millions of Dollars 2022 2021 2020 Revenue from Outside the Scope of ASC Topic 606 by Product Crude oil $ 495 757 395 Natural gas 15,368 10,034 4,339 Other 1,287 709 443 Physical contracts meeting the definition of a derivative $ 17,150 11,500 5,177

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2022
Earnings Per Share [Abstract]
Earnings Per Share, Basic and Diluted	The following table presents the calculation of net income available to common shareholders and basic and diluted EPS for the years ended December 31, 2022, 2021, and 2020. For each of the periods with net income presented in the table below, diluted EPS calculated under the two-class method was more dilutive. Millions of Dollars (except per share amounts) Years Ended December 31 2022 2021 2020 Basic earnings per share Net Income (Loss) Attributable to ConocoPhillips $ 18,680 8,079 (2,701) Less: Dividends and undistributed earnings allocated to participating securities 60 19 6 Net Income (Loss) available to common shareholders $ 18,620 8,060 (2,707) Average common shares outstanding (in Millions) 1,274 1,324 1,078 Net Income (Loss) Attributable to ConocoPhillips Per Share $ 14.62 6.09 (2.51) Diluted earnings per share Net Income (Loss) available to common shareholders $ 18,620 8,060 (2,707) Average common shares outstanding (in Millions) 1,274 1,324 1,078 Add: Dilutive impact of options and unvested non-participating RSU/PSUs 4 4 — Average diluted shares outstanding (in Millions) 1,278 1,328 1,078 Net Income (Loss) Attributable to ConocoPhillips Per Share $ 14.57 6.07 (2.51)

Segment Disclosures and Relat_2

Segment Disclosures and Related Information (Tables)	12 Months Ended
	Dec. 31, 2022
Segment Reporting [Abstract]
Sales and Other Operating Revenues	Analysis of Results by Operating Segment Millions of Dollars 2022 2021 2020 Sales and Other Operating Revenues Alaska $ 7,905 5,480 3,408 Intersegment eliminations — — (11) Alaska 7,905 5,480 3,397 Lower 48 52,921 29,306 9,872 Intersegment eliminations (18) (12) (51) Lower 48 52,903 29,294 9,821 Canada 6,159 4,077 1,666 Intersegment eliminations (2,445) (1,583) (405) Canada 3,714 2,494 1,261 Europe, Middle East and North Africa 11,271 5,902 1,919 Intersegment eliminations (1) — (2) Europe, Middle East and North Africa 11,270 5,902 1,917 Asia Pacific 2,606 2,579 2,363 Other International — 4 7 Corporate and Other 96 75 18 Consolidated sales and other operating revenues $ 78,494 45,828 18,784
Depreciation, Depletion, Amortization and Impairments	Millions of Dollars 2022 2021 2020 Depreciation, Depletion, Amortization and Impairments Alaska $ 941 1,002 996 Lower 48 4,854 4,067 3,358 Canada 400 392 342 Europe, Middle East and North Africa 735 862 775 Asia Pacific 518 1,483 809 Other International — — — Corporate and Other 44 76 54 Consolidated depreciation, depletion, amortization and impairments $ 7,492 7,882 6,334
Equity in Earnings of Affiliates	Equity in Earnings of Affiliates Alaska $ 4 5 (7) Lower 48 (14) (18) (11) Canada — — — Europe, Middle East and North Africa 780 502 311 Asia Pacific 1,310 343 137 Other International 1 — 2 Corporate and Other — — — Consolidated equity in earnings of affiliates $ 2,081 832 432
Income Tax Provision (Benefit)	Millions of Dollars 2022 2021 2020 Income Tax Provision (Benefit) Alaska $ 885 402 (256) Lower 48 3,088 1,390 (378) Canada 206 150 (185) Europe, Middle East and North Africa 5,445 2,543 136 Asia Pacific 480 483 294 Other International 53 (53) (20) Corporate and Other (609) (282) (76) Consolidated income tax provision (benefit) $ 9,548 4,633 (485)
Net Income (Loss) Attributable to ConocoPhillips	Net Income (Loss) Attributable to ConocoPhillips Alaska $ 2,352 1,386 (719) Lower 48 11,015 4,932 (1,122) Canada 714 458 (326) Europe, Middle East and North Africa 2,244 1,167 448 Asia Pacific 2,736 453 962 Other International (51) (107) (64) Corporate and Other (330) (210) (1,880) Consolidated net income (loss) attributable to ConocoPhillips $ 18,680 8,079 (2,701)
Investments In and Advances To Affiliates	Investments in and Advances to Affiliates Alaska $ 55 58 62 Lower 48 235 242 25 Canada — — — Europe, Middle East and North Africa 1,049 797 918 Asia Pacific 6,154 5,603 6,705 Other International — 1 — Corporate and Other — — — Consolidated investments in and advances to affiliates $ 7,493 6,701 7,710
Total Assets	Total Assets Alaska $ 15,126 14,812 14,623 Lower 48 42,950 41,699 11,932 Canada 6,971 7,439 6,863 Europe, Middle East and North Africa 8,263 9,125 8,756 Asia Pacific 9,511 9,840 11,231 Other International — 1 226 Corporate and Other 11,008 7,745 8,987 Consolidated total assets $ 93,829 90,661 62,618
Capital Expenditures and Investments	Millions of Dollars 2022 2021 2020 Capital Expenditures and Investments Alaska $ 1,091 982 1,038 Lower 48 5,630 3,129 1,881 Canada 530 203 651 Europe, Middle East and North Africa 998 534 600 Asia Pacific 1,880 390 384 Other International — 33 121 Corporate and Other 30 53 40 Consolidated capital expenditures and investments $ 10,159 5,324 4,715
Interest Income and Expense	Interest Income and Expense Interest income Alaska $ — — — Lower 48 — — — Canada — — — Europe, Middle East and North Africa 1 2 5 Asia Pacific 9 9 7 Other International — — — Corporate and Other 185 22 88 Interest and debt expense Corporate and Other $ 805 884 806
Sales and Other Operating Revenues by Product	Sales and Other Operating Revenues by Product Crude oil $ 41,492 23,648 9,736 Natural gas 26,941 16,904 6,427 Natural gas liquids 3,650 1,668 528 Other* 6,411 3,608 2,093 Consolidated sales and other operating revenues by product $ 78,494 45,828 18,784 *Includes LNG and bitumen.
Geographic Information	Geographic Information Millions of Dollars Sales and Other Operating Revenues (1) Long-Lived Assets (2) 2022 2021 2020 2022 2021 2020 United States $ 60,899 34,847 13,230 51,200 50,580 24,034 Australia and Timor-Leste — — 605 6,158 5,579 6,676 Canada 3,714 2,494 1,261 6,269 6,608 6,385 China 1,135 724 460 1,538 1,476 1,491 Indonesia (3) 159 879 689 — 28 464 Libya 1,582 1,102 155 714 659 670 Malaysia 1,312 975 610 1,107 1,252 1,501 Norway 3,415 2,563 1,426 4,369 4,681 5,294 United Kingdom 6,273 2,236 336 1 1 1 Other foreign countries 5 8 12 1,003 748 1,087 Worldwide consolidated $ 78,494 45,828 18,784 72,359 71,612 47,603 (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. (3) Assets divested in 2022. See Note 3 .

Accounting Policies (Details)

Accounting Policies (Details)	12 Months Ended
	Dec. 31, 2022 segment
Accounting Policies [Abstract]
Number of operating segments	6

Inventories - Schedule of Inven

Inventories - Schedule of Inventories (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Crude oil and natural gas	$ 641	$ 647
Materials and supplies	578	561
Total inventories	1,219	1,208
Inventories valued on the LIFO basis	$ 396	$ 395

Inventories - Narrative (Detail

Inventories - Narrative (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Excess of replacement or current costs over stated LIFO value	$ 149	$ 251

Acquisitions and Dispositions -

Acquisitions and Dispositions - Narrative (Details)		1 Months Ended									3 Months Ended	6 Months Ended	12 Months Ended
	Jan. 15, 2021 USD ($)	Sep. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Feb. 28, 2022 USD ($)	Feb. 28, 2021 USD ($)	Jan. 31, 2021 USD ($)	Aug. 31, 2020 USD ($) a	May 31, 2020 USD ($)	Mar. 31, 2020 USD ($)	Feb. 29, 2020 USD ($)	Mar. 31, 2021 USD ($)	Dec. 31, 2021 USD ($) a	Dec. 31, 2022 USD ($) $ / MMBTU $ / bbl	Dec. 31, 2021 USD ($) a	Dec. 31, 2021 USD ($) a	Dec. 31, 2020 USD ($)	May 27, 2020 USD ($)
Business Acquisition [Line Items]
Disposal Group, Not Discontinued Operation, Gain (Loss) on Disposal, Statement of Income or Comprehensive Income [Extensible Enumeration]													Gain (loss) from dispositions
Capitalized costs, proved properties												$ 114,274,000,000	$ 119,609,000,000	$ 114,274,000,000	$ 114,274,000,000
Capitalized costs, unproved properties												10,993,000,000	7,325,000,000	10,993,000,000	10,993,000,000
Income tax provision													9,548,000,000		4,633,000,000	$ (485,000,000)
Total revenues and other Income													82,156,000,000		48,349,000,000	19,256,000,000
Net Income (Loss) attributable to ConocoPhillips													18,680,000,000		8,079,000,000	(2,701,000,000)
Gain (loss) from dispositions													1,077,000,000		486,000,000	549,000,000
Asset retirement obligations												5,754,000,000	6,401,000,000	5,754,000,000	5,754,000,000
Assets Acquisition In The Lower 48 Segment
Business Acquisition [Line Items]
Asset acquisition, consideration transferred		$ 236,000,000
Lower 48
Business Acquisition [Line Items]
Before-tax gain (loss) on disposition												58,000,000
Proceeds from asset dispositions												250,000,000
Canada | Additional Montney acreage
Business Acquisition [Line Items]
Asset acquisition, assets acquired and liabilities assumed, net							$ 382,000,000
Asset acquisition, liabilities assumed							$ 31,000,000
Asset acquisition, undeveloped acreage acquired | a							140,000
Oil and gas, net underdeveloped acreage | a							295,000
Asset acquisition, percent of working interest acquired							100%
Property, plant and equipment, additions							$ 490,000,000
Asset retirement obligations							$ 77,000,000
Barossa Project | Asia Pacific
Business Acquisition [Line Items]
Before-tax gain (loss) on disposition											$ 200,000,000
Receivable in dispute																200,000,000
Proceeds from asset dispositions								$ 200,000,000
Noncore Exploration Interests
Business Acquisition [Line Items]
Before-tax gain (loss) on disposition												(179,000,000)
Waddell Ranch | Lower 48
Business Acquisition [Line Items]
Proceeds from asset dispositions										$ 184,000,000
Gain (loss) from dispositions										$ 0
Niobrara | Lower 48
Business Acquisition [Line Items]
Disposal group including discontinued operation, net carrying value, asset									$ 397,000,000
Disposal group including discontinued operation, net carrying value, PP&E									433,000,000
Proceeds from asset dispositions									359,000,000
Disposal group including discontinued operation, net carrying value, ARO									34,000,000
Gain on disposition of oil and gas property									$ 38,000,000
Losses before income taxes																25,000,000
Australia West Assets | Asia Pacific
Business Acquisition [Line Items]
Disposal group including discontinued operation, net carrying value, asset																	$ 200,000,000
Disposal group including discontinued operation, net carrying value, PP&E																	1,300,000,000
Disposal group including discontinued operation, net carrying value, cash and cash equivalents																	500,000,000
Proceeds from asset dispositions								$ 765,000,000
Disposal group including discontinued operation, net carrying value, ARO																	700,000,000
Gain on disposition of oil and gas property																587,000,000
Disposal group including discontinued operation, net carrying value, other assets																	100,000,000
Disposal group including discontinued operation, net carrying value, deferred tax liabilities																	300,000,000
Disposal group including discontinued operation, net carrying value, other liabilities																	$ 200,000,000
Before-tax earnings on subsidiaries sold																851,000,000
Certain Noncore Assets | Lower 48 | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Business Acquisition [Line Items]
Before-tax gain (loss) on disposition													0
Net carrying value													680,000,000
Disposal group including discontinued operation, net carrying value, asset													825,000,000
Disposal group including discontinued operation, net carrying value, PP&E													818,000,000
Disposal group, including discontinued operation, liabilities													145,000,000
Proceeds from asset dispositions													680,000,000
Subsidiaries Holding Indonesia Assets And Operations | Disposal Group, Disposed of by Sale, Not Discontinued Operations
Business Acquisition [Line Items]
Before-tax gain (loss) on disposition			$ 534,000,000
Net carrying value			200,000,000
Disposal group including discontinued operation, net carrying value, PP&E			300,000,000
Gain (loss) on disposal, net of tax			462,000,000
Disposal group including discontinued operation, net carrying value, cash and cash equivalents			200,000,000
Disposal group, including discontinued operation, asset retirement obligation			100,000,000
Disposal group, including discontinued operation, income (loss) before taxes													138,000,000		604,000,000	394,000,000
Proceeds from asset dispositions			$ 731,000,000
Previous Dispositions | Canada and Lower 48
Business Acquisition [Line Items]
Disposal group, including discontinued operation, contingent payment													451,000,000		369,000,000	$ 0
Previous Dispositions | Lower 48
Business Acquisition [Line Items]
Contingent payment calculation, monthly payment													$ 7,000,000
Contingent payment calculation, threshold U.S. Henry Hub price | $ / MMBTU													3.20
Previous Dispositions | Canada
Business Acquisition [Line Items]
Contingent payment calculation, cost per one Canadian dollar													6,000,000
Threshold average crude price per barrel | $ / bbl													52
Australia Pacific APLNG
Business Acquisition [Line Items]
Additional ownership percentage in equity investment acquired				10%
Payments to acquire additional interest				$ 1,400,000,000
Ownership percentage in equity investment				47.50%									47.50%
QG8
Business Acquisition [Line Items]
Ownership percentage in equity investment													25%
Origin Energy | Australia Pacific APLNG
Business Acquisition [Line Items]
Investment, ownership percentage				27.50%
Sinopec | Australia Pacific APLNG
Business Acquisition [Line Items]
Investment, ownership percentage				25%
Subsidiaries Holding Indonesia Assets And Operations | Transasia Pipeline Company
Business Acquisition [Line Items]
Investment, ownership percentage			35%
Subsidiaries Holding Indonesia Assets And Operations | Indonesia Corridor Block Production Sharing Contract
Business Acquisition [Line Items]
Investment, ownership percentage			54%
QatarEnergy | QG8
Business Acquisition [Line Items]
Ownership percentage in equity investment													75%
QG8 | North Field East LNG Project
Business Acquisition [Line Items]
Investment, ownership percentage													12.50%
Concho Resources Incorporated
Business Acquisition [Line Items]
Total consideration	$ 13,100,000,000					$ 13,100,000,000								13,125,000,000
Exchange ratio	1.46					1.46
Capitalized costs, proved properties	$ 11,800,000,000
Capitalized costs, unproved properties	$ 6,900,000,000
Transaction Cost											$ 157,000,000			157,000,000
Total revenues and other Income														6,571,000,000
Net Income (Loss) attributable to ConocoPhillips														2,330,000,000
Concho Resources Incorporated | Commodity
Business Acquisition [Line Items]
Gain (Loss) on price risk derivative instruments not designated as hedging instruments, before tax														(305,000,000)
Gain (Loss) on price risk derivative instruments not designated as hedging instruments, after tax														(233,000,000)
Concho Resources Incorporated | Concho Resources Inc.
Business Acquisition [Line Items]
Income tax provision					$ 75,000,000
Oil and gas properties, impairment loss															10,500,000,000
Goodwill, impairment loss															1,900,000,000
Shell Permian Assets
Business Acquisition [Line Items]
Total consideration															8,600,000,000
Capitalized costs, proved properties												4,200,000,000		4,200,000,000	4,200,000,000
Capitalized costs, unproved properties												$ 4,300,000,000		$ 4,300,000,000	4,300,000,000
Transaction Cost															$ 44,000,000
Area of land | a												225,000		225,000	225,000

Acquisitions and Dispositions_2

Acquisitions and Dispositions - Schedule of Business Combination (Details) $ / shares in Units, $ in Millions		1 Months Ended	12 Months Ended
	Jan. 15, 2021 USD ($) $ / shares shares	Jan. 31, 2021 USD ($)	Dec. 31, 2021 USD ($) shares	Dec. 31, 2022 shares	Dec. 31, 2020 shares	Dec. 31, 2019 shares
Business Acquisition [Line Items]
Number of shares of Concho stock awards outstanding (in shares)			11,973,783	4,303,575
Number of shares of Concho common stock issued (in shares)			2,091,562,747	2,100,885,134	1,798,844,267	1,795,652,203
Concho Resources Incorporated
Business Acquisition [Line Items]
Exchange ratio	1.46	1.46
Average price per share of ConocoPhillips common stock (in dollars per share) | $ / shares	$ 45.9025
Total consideration | $	$ 13,100	$ 13,100	$ 13,125
Concho Resources Incorporated | Common Stock
Business Acquisition [Line Items]
Additional shares of ConocoPhillips common stock issued as consideration (in shares)			285,929,000
Concho Resources Inc. | Concho Resources Incorporated
Business Acquisition [Line Items]
Number of shares of common stock outstanding (in shares)	194,243,000
Number of shares of Concho stock awards outstanding (in shares)	1,599,000
Number of shares exchanged (in shares)	195,842,000
Number of shares of Concho common stock issued (in shares)	194,243,000

Acquisitions and Dispositions_3

Acquisitions and Dispositions - Schedule of Assets Acquired and Liabilities Assumed (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Jan. 15, 2021
Assets Acquired
Investments and long-term receivables	$ 8,225	$ 7,113
Concho Resources Incorporated
Assets Acquired
Cash and cash equivalents			$ 382
Accounts receivable, net			745
Inventories			45
Prepaid expenses and other current assets			37
Investments and long-term receivables			333
Net properties, plants and equipment			18,923
Other assets			62
Total assets acquired			20,527
Liabilities Assumed
Accounts payable			638
Accrued income and other taxes			56
Employee benefit obligations			4
Other accruals			510
Long-term debt			4,696
Asset retirement obligations and accrued environmental costs			310
Deferred income taxes			1,071
Other liabilities and deferred credits			117
Total liabilities assumed			7,402
Net assets acquired			$ 13,125
Shell Permian Assets
Assets Acquired
Accounts receivable, net		337
Inventories		20
Net properties, plants and equipment		8,582
Other assets		50
Total assets acquired		8,989
Liabilities Assumed
Accounts payable		206
Accrued income and other taxes		6
Other accruals		20
Asset retirement obligations and accrued environmental costs		86
Other liabilities and deferred credits		36
Total liabilities assumed		354
Net assets acquired		$ 8,635

Acquisitions and Dispositions_4

Acquisitions and Dispositions - Schedule of Non-Recurring Restructuring and Transition-Related Costs (Details) - Concho Resources Incorporated - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2021	Dec. 31, 2021
Business Acquisition [Line Items]
Transaction Cost	$ 157	$ 157
Restructuring Cost		234
Total Cost		391
Production and operating expenses
Business Acquisition [Line Items]
Transaction Cost
Restructuring Cost		128
Total Cost		128
Selling, general and administration expenses
Business Acquisition [Line Items]
Transaction Cost		135
Restructuring Cost		67
Total Cost		202
Exploration expenses
Business Acquisition [Line Items]
Transaction Cost		18
Restructuring Cost		8
Total Cost		26
Taxes other than income taxes
Business Acquisition [Line Items]
Transaction Cost		4
Restructuring Cost		2
Total Cost		6
Other expenses
Business Acquisition [Line Items]
Transaction Cost		0
Restructuring Cost		29
Total Cost		$ 29

Acquisitions and Dispositions_5

Acquisitions and Dispositions - Schedule of Supplemental Pro Forma Financial Information (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2021	Dec. 31, 2020
Supplemental Pro Forma (unaudited)
Total revenues and other Income	$ 82,156		$ 48,349	$ 19,256
Income (loss) before income taxes			12,712	(3,140)
Net income (loss)	$ 18,680		$ 8,079	$ (2,701)
Earnings per share:
Basic (in dollars per share)	$ 14.62		$ 6.09	$ (2.51)
Diluted (in dollars per share)	$ 14.57		$ 6.07	$ (2.51)
Pro Forma
Supplemental Pro Forma (unaudited)
Total revenues and other Income			$ 51,569	$ 24,703
Income (loss) before income taxes			13,913	(2,600)
Net income (loss)			$ 8,999	$ (2,392)
Earnings per share:
Basic (in dollars per share)			$ 6.78	$ (1.75)
Diluted (in dollars per share)			$ 6.76	$ (1.75)
Concho Resources Incorporated
Supplemental Pro Forma (unaudited)
Total revenues and other Income		$ 6,571
Net income (loss)		$ 2,330
Pro forma - Total Revenues and Other Income				$ 3,762
Pro forma - Income (loss) before income taxes				787
Pro forma - Net Income (Loss) attributable to ConocoPhillips				498
Shell Permian Assets
Supplemental Pro Forma (unaudited)
Pro forma - Total Revenues and Other Income			$ 3,220	1,685
Pro forma - Income (loss) before income taxes			1,201	(247)
Pro forma - Net Income (Loss) attributable to ConocoPhillips			$ 920	$ (189)

Investments, Loans and Long-T_3

Investments, Loans and Long-Term Receivables - Components of Investments, Loans and Long-Term Receivables (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Equity Method Investments and Joint Ventures [Abstract]
Equity Method Investments	$ 7,493	$ 6,701
Long-term receivables	142	98
Long-term investments in debt securities	522	248
Other investments	68	66
Total	$ 8,225	$ 7,113

Investments, Loans and Long-T_4

Investments, Loans and Long-Term Receivables - Narrative (Details) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2021 USD ($)	Dec. 31, 2022 USD ($) facility	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Dec. 31, 2012 USD ($)	Dec. 31, 2005 USD ($)
Schedule of Equity Method Investments [Line Items]
Retained earnings, undistributed earnings of affiliated companies		$ 42
Dividends from affiliates		3,045	$ 1,279	$ 1,076
Impairments		(12)	674	813
Carrying value of equity method investment	$ 6,701	$ 7,493	$ 6,701
APLNG
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment		47.50%
Project finance facility, maximum borrowing capacity					$ 8,500
Line of credit facility, outstanding		$ 5,200
Additional ownership percentage in equity investment acquired	10%		10%
Payments to acquire additional interest	$ 1,645
Impairments	688
Impairments, after tax	688
Carrying value of equity method investment		6,200
Underlying equity in net assets		6,100
Difference between estimated value and book value of equity method investment		41
Amortizable portion of the basis difference in PPE	$ 39	$ 10	$ 39	$ 41
QG3
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment		30%
Project finance facility, maximum borrowing capacity						$ 4,000
Carrying value of equity method investment		$ 700
QG8
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment		25%
Carrying value of equity method investment		$ 300
Origin Energy | APLNG
Schedule of Equity Method Investments [Line Items]
Investment, ownership percentage		27.50%
Sinopec | APLNG
Schedule of Equity Method Investments [Line Items]
Investment, ownership percentage		25%
QatarEnergy | QG3
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment		68.50%
QatarEnergy | QG8
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment		75%
Mitsui & Co., Ltd. | QG3
Schedule of Equity Method Investments [Line Items]
Ownership percentage in equity investment		1.50%
QG8 | North Field East LNG Project
Schedule of Equity Method Investments [Line Items]
Investment, ownership percentage		12.50%
U S Private Placement Bond | APLNG
Schedule of Equity Method Investments [Line Items]
Number of note facilities | facility		2
Credit Agencies | QG3
Schedule of Equity Method Investments [Line Items]
Project finance facility, maximum borrowing capacity						1,300
Commerical Banks | QG3
Schedule of Equity Method Investments [Line Items]
Project finance facility, maximum borrowing capacity						1,500
Parent Company | QG3
Schedule of Equity Method Investments [Line Items]
Project finance facility, maximum borrowing capacity						$ 1,200

Investments, Loans and Long-T_5

Investments, Loans and Long-Term Receivables - Summarized Financial Information for Equity Method Investments in Affiliated Companies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Revenues	$ 78,494	$ 45,828	$ 18,784
Net income	18,680	8,079	(2,655)
Current assets	18,749	16,050
Current liabilities	12,847	12,021
Affiliated Companies
Schedule of Equity Method Investments [Line Items]
Revenues	18,356	11,824	7,931
Income before income taxes	8,234	3,946	1,843
Net income	5,507	2,557	$ 1,426
Current assets	5,001	4,493
Noncurrent assets	37,789	36,602
Current liabilities	4,169	3,498
Noncurrent liabilities	$ 17,244	$ 17,465

Investment in Cenovus Energy -

Investment in Cenovus Energy - Narrative (Details) - Cenovus Energy Inc - USD ($) $ / shares in Units, shares in Millions, $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2022	Dec. 31, 2022	Dec. 31, 2021
Debt and Equity Securities, FV-NI [Line Items]
Number of shares of common stock outstanding (in shares)			91
Investment owned, percent of issued and outstanding			4.50%
Common stock, outstanding value			$ 1,100
Share price (in dollars per share)			$ 12.28
Common Stock
Debt and Equity Securities, FV-NI [Line Items]
Equity securities, shares sold (in shares)	91
Proceeds received from sale of equity securities		$ 1,400

Investment in Cenovus Energy _2

Investment in Cenovus Energy - Gains and Losses Recorded in Other Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Debt and Equity Securities, FV-NI [Line Items]
Total Net gain (loss) on equity securities	$ 251	$ 1,040	$ (855)
Cenovus Energy Inc
Debt and Equity Securities, FV-NI [Line Items]
Total Net gain (loss) on equity securities	251	1,040	(855)
Less: Net gain (loss) on equity securities sold during the period	251	473
Unrealized gain (loss) on equity securities still held at the reporting date		$ 567	$ (855)

Suspended Wells and Explorati_3

Suspended Wells and Exploration Expenses - Net Changes in Suspended Exploratory Well Costs (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Increase (Decrease) in Capitalized Exploratory Well Costs that are Pending Determination of Proved Reserves [Roll Forward]
Beginning balance	$ 660	$ 682	$ 1,020
Additions pending the determination of proved reserves	5	10	164
Reclassifications to proved properties	(7)	0	(42)
Sales of suspended wells	0	0	(313)
Charged to dry hole expense	(131)	(32)	(147)
Ending balance	$ 527	$ 660	$ 682

Suspended Wells and Explorati_4

Suspended Wells and Exploration Expenses - Aging of Suspended Well Cost (Details) $ in Millions	Dec. 31, 2022 USD ($) project	Dec. 31, 2021 USD ($) project	Dec. 31, 2020 USD ($) project	Dec. 31, 2019 USD ($)
Extractive Industries [Abstract]
Exploratory well costs capitalized for a period of one year or less	$ 15	$ 4	$ 156
Exploratory well costs capitalized for a period greater than one year	512	656	526
Capitalized cost of suspended wells	$ 527	$ 660	$ 682	$ 1,020
Number of projects with exploratory well costs capitalized for a period greater than one year | project	17	22	22

Suspended Wells and Explorati_5

Suspended Wells and Exploration Expenses - Aging of Exploratory Well Cost, Capitalized for More than One Year (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	$ 512	$ 656	$ 526
2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	308
2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	174
2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	30
Willow - Alaska
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	315
Willow - Alaska | 2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	201
Willow - Alaska | 2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	114
Willow - Alaska | 2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
PL 1009 - Norway
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	39
PL 1009 - Norway | 2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	39
PL 1009 - Norway | 2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
PL 1009 - Norway | 2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
PL 891 - Norway
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	31
PL 891 - Norway | 2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	31
PL 891 - Norway | 2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
PL 891 - Norway | 2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
Narwhal Trend - Alaska
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	25
Narwhal Trend - Alaska | 2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
Narwhal Trend - Alaska | 2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	25
Narwhal Trend - Alaska | 2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
WL4-00 - Malaysia
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	24
WL4-00 - Malaysia | 2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	7
WL4-00 - Malaysia | 2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	17
WL4-00 - Malaysia | 2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
PL782S - Norway
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	19
PL782S - Norway | 2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	19
PL782S - Norway | 2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
PL782S - Norway | 2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
Montney - Canada
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	12
Montney - Canada | 2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	4
Montney - Canada | 2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	8
Montney - Canada | 2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	0
Other of $10 Million or less each
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	47
Other of $10 Million or less each | 2019-2021
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	7
Other of $10 Million or less each | 2016-2018
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	10
Other of $10 Million or less each | 2006-2015
Capitalized Exploratory Well Costs [Line Items]
Exploratory well costs capitalized for a period greater than one year	$ 30

Suspended Wells and Explorati_6

Suspended Wells and Exploration Expenses - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Before-tax impairment related to the associated carrying value of capitalized undeveloped leasehold costs		$ 564	$ 344	$ 1,457
Canada
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Before-tax impairment related to the associated carrying value of capitalized undeveloped leasehold costs	$ 129
Europe, Middle East and North Africa
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Before-tax impairment related to the associated carrying value of capitalized undeveloped leasehold costs		$ 102
Alaska
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Before-tax impairment related to the associated carrying value of capitalized undeveloped leasehold costs				828
Asia Pacific
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Before-tax impairment related to the associated carrying value of capitalized undeveloped leasehold costs				50
Other International
Impaired Assets to be Disposed of by Method Other than Sale [Line Items]
Before-tax impairment related to the associated carrying value of capitalized undeveloped leasehold costs				$ 84

Impairments - Before Tax Impair

Impairments - Before Tax Impairment Charges (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Impairments		$ (12)	$ 674	$ 813
Alaska | Operating Segments
Segment Reporting Information [Line Items]
Impairments		2	5	0
Lower 48
Segment Reporting Information [Line Items]
Impairments			(89)
Lower 48 | Operating Segments
Segment Reporting Information [Line Items]
Impairments	$ 84	(11)	(8)	804
Canada | Operating Segments
Segment Reporting Information [Line Items]
Impairments		(2)	6	3
Europe, Middle East and North Africa | Operating Segments
Segment Reporting Information [Line Items]
Impairments		(1)	(24)	6
Asia Pacific | Operating Segments
Segment Reporting Information [Line Items]
Impairments		$ 0	$ 695	$ 0

Impairments - Narrative (Detail

Impairments - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		12 Months Ended
	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Impairments			$ (12)	$ 674	$ 813
Asia Pacific | Operating Segments
Segment Reporting Information [Line Items]
Impairments			0	695	0
Lower 48
Segment Reporting Information [Line Items]
Impairments				(89)
Lower 48 | Operating Segments
Segment Reporting Information [Line Items]
Impairments	$ 84		(11)	(8)	804
Europe, Middle East and North Africa | Operating Segments
Segment Reporting Information [Line Items]
Impairments			$ (1)	(24)	6
APLNG
Segment Reporting Information [Line Items]
Impairments	$ 688
APLNG | Asia Pacific | Operating Segments
Segment Reporting Information [Line Items]
Impairments				$ 688
Noncore Assets | Lower 48 | Operating Segments
Segment Reporting Information [Line Items]
Impairments					813
Wind River Basin | Lower 48 | Operating Segments
Segment Reporting Information [Line Items]
Impairments		$ 287			$ 523

Asset Retirement Obligations _3

Asset Retirement Obligations and Accrued Environmental Costs - Asset Retirement Obligations and Accrued Environmental Costs (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Asset Retirement Obligation Disclosure [Abstract]
Asset retirement obligations	$ 6,380	$ 5,926	$ 5,573
Accrued environmental costs	182	187
Total asset retirement obligations and accrued environmental costs	6,562	6,113
Asset retirement obligations and accrued environmental costs due within one year*	(161)	(359)
Long-term asset retirement obligations and accrued environmental costs	$ 6,401	$ 5,754

Asset Retirement Obligations _4

Asset Retirement Obligations and Accrued Environmental Costs - Changes in Asset Retirement Obligation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Asset Retirement Obligation, Roll Forward Analysis [Roll Forward]
Beginning balance	$ 5,926	$ 5,573
Accretion of discount	245	238
New obligations	144	555
Changes in estimates of existing obligations	681	(113)
Spending on existing obligations	(231)	(164)
Property dispositions	(203)	(108)
Foreign currency translation	(182)	(55)
Ending balance	$ 6,380	$ 5,926

Asset Retirement Obligations _5

Asset Retirement Obligations and Accrued Environmental Costs - Narrative (Details) - USD ($) $ in Millions	1 Months Ended
	Dec. 31, 2021	Dec. 31, 2022
Site Contingency [Line Items]
Accrued environmental costs	$ 187	$ 182
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%
Total environmental accrual included in balance sheet		$ 111
Environmental Loss Contingency, Statement of Financial Position [Extensible Enumeration]		Asset retirement obligations
Accrued environmental costs discounted		$ 147
Cleanup Remediation Activities
Site Contingency [Line Items]
Accrued environmental costs	$ 135	107
Corporate and Other Environmental Liabilities
Site Contingency [Line Items]
Accrued environmental costs	36	59
Federal Comprehensive Environmental Response Compensation and Liability Act or Similar State Laws
Site Contingency [Line Items]
Accrued environmental costs	$ 16	$ 16

Debt - Schedule of Debt (Detail

Debt - Schedule of Debt (Details) - USD ($) $ in Millions	Dec. 31, 2022	May 31, 2022	Mar. 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Finance leases	$ 1,320			$ 1,261
Net unamortized premiums, discounts and debt issuance costs	532			(907)
Total debt	16,643			19,934
Short-term debt	(417)			(1,200)
Long-term debt	$ 16,226			18,734
2.40% Notes due 2022 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	2.40%
Long-term and short-term, combined amount, gross	$ 0			329
7.65% Debentures due 2023 | Debentures
Debt Instrument [Line Items]
Stated interest rate	7.65%
Long-term and short-term, combined amount, gross	$ 78			78
3.35% Notes due 2024 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	3.35%
Long-term and short-term, combined amount, gross	$ 426			426
2.125% Notes due 2024 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	2.125%		2.125%
Long-term and short-term, combined amount, gross	$ 900			0
8.2% Notes due 2025 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	8.20%
Long-term and short-term, combined amount, gross	$ 134			134
3.35% Debentures due 2025 | Debentures
Debt Instrument [Line Items]
Stated interest rate	3.35%
Long-term and short-term, combined amount, gross	$ 199			199
2.40% Notes due 2025 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	2.40%		2.40%
Long-term and short-term, combined amount, gross	$ 900			0
6.875% Debentures due 2026 | Debentures
Debt Instrument [Line Items]
Stated interest rate	6.875%
Long-term and short-term, combined amount, gross	$ 67			67
4.95% Notes due 2026 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	4.95%	4.95%
Long-term and short-term, combined amount, gross	$ 0			1,250
7.8% Debentures due 2027 | Debentures
Debt Instrument [Line Items]
Stated interest rate	7.80%
Long-term and short-term, combined amount, gross	$ 203			203
3.75% Notes due 2027 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	3.75%
Long-term and short-term, combined amount, gross	$ 196			1,000
4.3% Notes due 2028 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	4.30%
Long-term and short-term, combined amount, gross	$ 223			1,000
7.375% Debentures due 2029 | Debentures
Debt Instrument [Line Items]
Stated interest rate	7.375%
Long-term and short-term, combined amount, gross	$ 92			92
7.0% Debentures due 2029 | Debentures
Debt Instrument [Line Items]
Stated interest rate	7%
Long-term and short-term, combined amount, gross	$ 112			200
6.95% Notes due 2029 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	6.95%
Long-term and short-term, combined amount, gross	$ 1,195			1,549
8.125% Notes due 2030 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	8.125%
Long-term and short-term, combined amount, gross	$ 390			390
7.4% Notes due 2031 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	7.40%
Long-term and short-term, combined amount, gross	$ 382			500
7.25% Notes due 2031 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	7.25%
Long-term and short-term, combined amount, gross	$ 400			500
7.2% Notes due 2031 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	7.20%
Long-term and short-term, combined amount, gross	$ 447			575
2.4% Notes due 2031 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	2.40%
Long-term and short-term, combined amount, gross	$ 227			500
5.9% Notes due 2032 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	5.90%
Long-term and short-term, combined amount, gross	$ 505			505
4.15% Notes due 2034 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	4.15%
Long-term and short-term, combined amount, gross	$ 246			246
5.95% Notes due 2036 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	5.95%
Long-term and short-term, combined amount, gross	$ 326			500
5.951% Notes due 2037 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	5.951%
Long-term and short-term, combined amount, gross	$ 631			645
5.9% Notes due 2038 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	5.90%
Long-term and short-term, combined amount, gross	$ 350			600
6.5% Notes due 2039 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	6.50%
Long-term and short-term, combined amount, gross	$ 1,588			2,750
3.758% Notes due 2042 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	3.758%
Long-term and short-term, combined amount, gross	$ 785			0
4.3% Notes due 2044 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	4.30%
Long-term and short-term, combined amount, gross	$ 750			750
5.95% Notes due 2046 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	5.95%
Long-term and short-term, combined amount, gross	$ 329			500
7.9% Debentures due 2047 | Debentures
Debt Instrument [Line Items]
Stated interest rate	7.90%
Long-term and short-term, combined amount, gross	$ 60			60
4.875% Notes due 2047 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	4.875%
Long-term and short-term, combined amount, gross	$ 319			800
4.85% Notes due 2048 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	4.85%
Long-term and short-term, combined amount, gross	$ 219			600
3.8% Notes due 2052 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	3.80%		3.80%
Long-term and short-term, combined amount, gross	$ 1,100			0
4.025% Notes due 2062 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	4.025%
Long-term and short-term, combined amount, gross	$ 1,770			0
Floating rate notes due 2022 at 1.06% – 1.41% during 2022 and 1.02% – 1.12% during 2021 | Floating Rate Notes
Debt Instrument [Line Items]
Long-term and short-term, combined amount, gross	$ 0			$ 500
Floating rate notes due 2022 at 1.06% – 1.41% during 2022 and 1.02% – 1.12% during 2021 | Floating Rate Notes | Minimum
Debt Instrument [Line Items]
Stated interest rate	1.06%			1.02%
Floating rate notes due 2022 at 1.06% – 1.41% during 2022 and 1.02% – 1.12% during 2021 | Floating Rate Notes | Maximum
Debt Instrument [Line Items]
Stated interest rate	1.41%			1.12%
Marine Terminal Revenue Refunding Bonds due 2031 at 0.07% – 4.10% during 2022 and 0.04% – 0.15% during 2021 | Variable Rate Debt Bonds
Debt Instrument [Line Items]
Long-term and short-term, combined amount, gross	$ 265			$ 265
Marine Terminal Revenue Refunding Bonds due 2031 at 0.07% – 4.10% during 2022 and 0.04% – 0.15% during 2021 | Variable Rate Debt Bonds | Minimum
Debt Instrument [Line Items]
Stated interest rate	0.07%			0.04%
Marine Terminal Revenue Refunding Bonds due 2031 at 0.07% – 4.10% during 2022 and 0.04% – 0.15% during 2021 | Variable Rate Debt Bonds | Maximum
Debt Instrument [Line Items]
Stated interest rate	4.10%			0.15%
Industrial Development Bonds due 2035 at 0.07% – 4.10% during 2022 and 0.04% – 0.12% during 2021 | Variable Rate Debt Bonds
Debt Instrument [Line Items]
Long-term and short-term, combined amount, gross	$ 18			$ 18
Industrial Development Bonds due 2035 at 0.07% – 4.10% during 2022 and 0.04% – 0.12% during 2021 | Variable Rate Debt Bonds | Minimum
Debt Instrument [Line Items]
Stated interest rate	0.07%			0.04%
Industrial Development Bonds due 2035 at 0.07% – 4.10% during 2022 and 0.04% – 0.12% during 2021 | Variable Rate Debt Bonds | Maximum
Debt Instrument [Line Items]
Stated interest rate	4.10%			0.12%
Other
Debt Instrument [Line Items]
Long-term and short-term, combined amount, gross	$ 23			$ 35

Debt - Narrative (Details)

Debt - Narrative (Details) $ in Millions		1 Months Ended			12 Months Ended
	Jan. 15, 2021 USD ($)	Dec. 31, 2022 USD ($)	May 31, 2022 USD ($)	Mar. 31, 2022 USD ($) transaction	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	Dec. 31, 2020 USD ($)	Feb. 28, 2022 USD ($)	Jan. 31, 2022 USD ($)	Feb. 28, 2021 USD ($)
Debt Instrument [Line Items]
Debt instrument, repurchased face amount				$ 2,716
Gain (loss) on repurchase of debt instrument				155
Debt repurchase, incurred debt premium				$ 333
Repayments of debt					$ 6,267	$ 505	$ 254
Debt at face value		$ 15,855			$ 15,855	17,766
Number of debt exchange transactions | transaction				2
Debt instrument, exchange amount				$ 2,544
Debt exchange, incurred premium				883
Debt premium cash component				872
Expense from exchange of debt				28
Concho Resources Incorporated
Debt Instrument [Line Items]
Debt at face value										$ 67
Business combination, notes offered in the exchange	$ 3,900									$ 3,900
Long-term debt	4,696
Adjustment to fair value of the senior notes	$ 800
Business combination, percent of notes offered in the exchange, tendered and accepted										98%
Business combination, notes offered in the exchange, tendered and accepted										$ 3,800
Debentures | 7.0% Debentures due 2029
Debt Instrument [Line Items]
Stated interest rate		7%			7%
Debt at face value								$ 200
Debt instrument, exchange amount				88
Notes Payable to Banks | 2.40% Notes due 2022
Debt Instrument [Line Items]
Retirement of debt		$ 329
Stated interest rate		2.40%			2.40%
Notes Payable to Banks | 4.95% Notes due 2026
Debt Instrument [Line Items]
Stated interest rate		4.95%	4.95%		4.95%
Debt instrument, repurchased face amount			$ 1,250
Gain (loss) on repurchase of debt instrument			(83)
Debt repurchase, incurred debt premium			79
Notes Payable to Banks | 3.75% Notes due 2027
Debt Instrument [Line Items]
Stated interest rate		3.75%			3.75%
Debt instrument, repurchased face amount				804
Debt at face value								1,000
Notes Payable to Banks | 4.3% Notes due 2028
Debt Instrument [Line Items]
Stated interest rate		4.30%			4.30%
Debt instrument, repurchased face amount				777
Debt at face value								1,000
Notes Payable to Banks | 2.4% Notes due 2031
Debt Instrument [Line Items]
Stated interest rate		2.40%			2.40%
Debt instrument, repurchased face amount				273
Debt at face value								500
Notes Payable to Banks | 4.875% Notes due 2047
Debt Instrument [Line Items]
Stated interest rate		4.875%			4.875%
Debt instrument, repurchased face amount				481
Debt at face value								800
Notes Payable to Banks | 4.85% Notes due 2048
Debt Instrument [Line Items]
Stated interest rate		4.85%			4.85%
Debt instrument, repurchased face amount				381
Debt at face value								600
Notes Payable to Banks | 6.95% Notes due 2029
Debt Instrument [Line Items]
Stated interest rate		6.95%			6.95%
Debt at face value								1,549
Debt instrument, exchange amount				354
Notes Payable to Banks | 7.4% Notes due 2031
Debt Instrument [Line Items]
Stated interest rate		7.40%			7.40%
Debt at face value								500
Debt instrument, exchange amount				118
Notes Payable to Banks | 7.25% Notes due 2031
Debt Instrument [Line Items]
Stated interest rate		7.25%			7.25%
Debt at face value								500
Debt instrument, exchange amount				100
Notes Payable to Banks | 7.2% Notes due 2031
Debt Instrument [Line Items]
Stated interest rate		7.20%			7.20%
Debt at face value								575
Debt instrument, exchange amount				128
Notes Payable to Banks | 5.95% Notes due 2036
Debt Instrument [Line Items]
Stated interest rate		5.95%			5.95%
Debt at face value								500
Debt instrument, exchange amount				174
Notes Payable to Banks | 5.9% Notes due 2038
Debt Instrument [Line Items]
Stated interest rate		5.90%			5.90%
Debt at face value								600
Debt instrument, exchange amount				250
Notes Payable to Banks | 6.5% Notes due 2039
Debt Instrument [Line Items]
Stated interest rate		6.50%			6.50%
Debt at face value								2,750
Debt instrument, exchange amount				1,162
Notes Payable to Banks | 5.95% Notes due 2046
Debt Instrument [Line Items]
Stated interest rate		5.95%			5.95%
Debt at face value								500
Debt instrument, exchange amount				$ 171
Notes Payable to Banks | 3.758% Notes due 2042
Debt Instrument [Line Items]
Stated interest rate		3.758%			3.758%
Debt at face value		$ 785			$ 785
Notes Payable to Banks | 4.025% Notes due 2062
Debt Instrument [Line Items]
Stated interest rate		4.025%			4.025%
Debt at face value		$ 1,770			$ 1,770
Notes Payable to Banks | 2.125% Notes due 2024
Debt Instrument [Line Items]
Stated interest rate		2.125%		2.125%	2.125%
Debt at face value				$ 900
Notes Payable to Banks | 2.40% Notes due 2025
Debt Instrument [Line Items]
Stated interest rate		2.40%		2.40%	2.40%
Debt at face value				$ 900
Notes Payable to Banks | 3.8% Notes due 2052
Debt Instrument [Line Items]
Stated interest rate		3.80%		3.80%	3.80%
Debt at face value				$ 1,100
Variable Rate Debt Bonds
Debt Instrument [Line Items]
Debt at face value		$ 283			$ 283	$ 283
Floating Rate Notes | Floating rate notes due 2022 at 1.06% – 1.41% during 2022 and 1.02% – 1.12% during 2021
Debt Instrument [Line Items]
Repayments of debt			$ 500
Floating Rate Notes | Floating rate notes due 2022 at 1.06% – 1.41% during 2022 and 1.02% – 1.12% during 2021 | Maximum
Debt Instrument [Line Items]
Stated interest rate		1.41%			1.41%	1.12%
Revolving Credit Facility
Debt Instrument [Line Items]
Project finance facility, maximum borrowing capacity								$ 5,500	$ 6,000
Minimum limit of debt for cross default provision		$ 200			$ 200
Commercial paper program, amount outstanding		0			0	$ 0
Remaining borrowing capacity under revolving credit facility		5,500			5,500
Commercial Paper | Conoco Phillips Commercial Paper Program
Debt Instrument [Line Items]
Commercial paper program, amount outstanding						$ 0
Letter of Credit | Maximum
Debt Instrument [Line Items]
Line of credit facility, capacity available for specific purpose other than for trade purchases		$ 500			$ 500

Guarantees (Details)

Guarantees (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Feb. 28, 2022
Australia Pacific APLNG
Guarantor Obligations [Line Items]
Ownership percentage in equity investment	47.50%	47.50%
QG8
Guarantor Obligations [Line Items]
Ownership percentage in equity investment	25%
Finance Reserve Guarantee | Australia Pacific APLNG
Guarantor Obligations [Line Items]
Guarantor obligations, remaining term	8 years
Maximum potential amount of future payments	$ 210
Carrying value of the guarantee to third-party lenders	14
Max Potential Future Payments-Prorata Share | Australia Pacific APLNG
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	780
Max potential Future Payments-Reckless Breach | Australia Pacific APLNG
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	1,300
Continued Development | Australia Pacific APLNG
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	290
Carrying value of the guarantee to third-party lenders	$ 20
Continued Development | Australia Pacific APLNG | Minimum
Guarantor Obligations [Line Items]
Guarantor obligations, remaining term	14 years
Continued Development | Australia Pacific APLNG | Maximum
Guarantor Obligations [Line Items]
Guarantor obligations, remaining term	23 years
Joint Venture Obligation Guarantee | QG8
Guarantor Obligations [Line Items]
Carrying value of the guarantee to third-party lenders	$ 7
Guarantor obligations, term	30 years
Other Guarantees
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	$ 600
Carrying value of the guarantee to third-party lenders	$ 0
Other Guarantees | Minimum
Guarantor Obligations [Line Items]
Guarantor obligations, remaining term	3 years
Other Guarantees | Maximum
Guarantor Obligations [Line Items]
Guarantor obligations, remaining term	4 years
Indemnifications
Guarantor Obligations [Line Items]
Carrying value of the guarantee to third-party lenders	$ 20

Contingencies and Commitments -

Contingencies and Commitments - Narrative (Details) $ in Millions		1 Months Ended				12 Months Ended	57 Months Ended
	Aug. 02, 2019 USD ($)	Oct. 31, 2020	Mar. 31, 2019 USD ($)	Aug. 31, 2018 USD ($)	Apr. 30, 2018 USD ($)	Dec. 31, 2017 lawsuit	Dec. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)	May 10, 2021 USD ($)	Dec. 31, 2020 USD ($)	Aug. 29, 2019 USD ($)
Loss Contingencies [Line Items]
Purchase obligation							$ 368
2023							7
2024							7
2025							7
2026							7
2027							7
2028 and after							33
Total payments under agreement							26	$ 27		$ 25
Several Louisiana parishes and the State of Louisiana against oil and gas companies
Loss Contingencies [Line Items]
Loss contingency, number of new claims filed | lawsuit						43
Outer Continental Shelf Lease | Phillips Petroleum Company
Loss Contingencies [Line Items]
Ownership percentage in equity investment		25%
Sale of interest, duration		30 years
Barossa Project | Asia Pacific
Loss Contingencies [Line Items]
Receivable in dispute										$ 200
Barossa Project | Asia Pacific | Operating Segments
Loss Contingencies [Line Items]
Receivable in dispute									$ 200
ConocoPhillips Entities | Several Louisiana parishes and the State of Louisiana against oil and gas companies
Loss Contingencies [Line Items]
Loss contingency, number of new claims filed | lawsuit						22
VENEZUELA | ConocoPhillips Versus Petroleos de Venezuela ICISD
Loss Contingencies [Line Items]
Litigation settlement, amount awarded			$ 8,700
Litigation award reduction											$ 227
Litigation settlement, amount awarded revised							8,500
VENEZUELA | ConocoPhillips vs Petroleos De Venezuela ICC
Loss Contingencies [Line Items]
Litigation settlement, amount awarded	$ 33			$ 500	$ 2,000
Litigation settlement, initial payment term				90 days
Litigation settlement, remaining payment term				4 years 6 months
Proceeds from legal settlements							$ 774

Derivative and Financial Inst_3

Derivative and Financial Instruments - Fair Value Amounts of Derivatives, Balance Sheet Location (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Derivatives, Fair Value [Line Items]
Derivative Asset, Statement of Financial Position [Extensible Enumeration]	Other Assets, Noncurrent, Prepaid Expense and Other Assets, Current
Commodity | Prepaid expenses and other current assets
Derivatives, Fair Value [Line Items]
Commodity derivative assets	$ 1,795	$ 1,168
Commodity | Other assets
Derivatives, Fair Value [Line Items]
Commodity derivative assets	242	75
Commodity | Other accruals
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	1,800	1,160
Commodity | Other liabilities and deferred credits
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	$ 210	$ 63

Derivative and Financial Inst_4

Derivative and Financial Instruments - Gain (Loss) Amounts of Derivatives, Income Statement Location (Details) - Commodity - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Sales and other operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (88)	$ (228)	$ 19
Other income (loss)
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	(5)	25	4
Purchased commodities
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (91)	$ 75	$ 11

Derivative and Financial Inst_5

Derivative and Financial Instruments - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Jan. 15, 2021
Derivative [Line Items]
Debt securities, available-for-sale, unrealized loss	$ 12
Proceeds from sales and redemptions of investments in debt securities classified as available for sale	644	$ 594
Collateral was posted for derivative instruments in a liability position	42	0
In Event of Lowered Credit Rating
Derivative [Line Items]
Derivative, liability position, aggregate fair value	333	281
In Event of Downgrade Below Investment Grade
Derivative [Line Items]
Additional collateral, either in the form of cash or letters of credit	$ 270
Maximum | Trade Receivables
Derivative [Line Items]
Terms of financial instruments and trade receivables	30 days
Concho Resources Incorporated | Commodity
Derivative [Line Items]
Business combination, derivative liabilities assumed			$ 456
Gains (losses) from commodity derivatives		(305)
Cash payment		$ 761

Derivative and Financial Inst_6

Derivative and Financial Instruments - Net Exposures from Outstanding Derivative Contracts (Details) - Commodity - Bcf	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Fixed price | Long
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures		4
Fixed price | Short
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	14
Basis | Short
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	8	22

Derivative and Financial Inst_7

Derivative and Financial Instruments - Net Carrying Amount of Investments and Long-term Receivables Carried at Cost plus Accrued Interest (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents	$ 6,361	$ 5,018
Short-Term Investments	2,182	225
Cash
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents	593	670
Demand Deposits
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents	1,638	1,554
Time Deposits | 1 to 90 days
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents	4,116	2,363
Short-Term Investments	1,288	217
Time Deposits | 91 to 180 days
Schedule of Held-to-maturity Securities [Line Items]
Short-Term Investments	883	4
Time Deposits | Within one year
Schedule of Held-to-maturity Securities [Line Items]
Short-Term Investments	11	4
U.S. Government Obligations | 1 to 90 days
Schedule of Held-to-maturity Securities [Line Items]
Cash and Cash Equivalents	14	431
Short-Term Investments	$ 0	$ 0

Derivative and Financial Inst_8

Derivative and Financial Instruments - Financial Instruments, Debt Securities Carried at Fair Value (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Cash and cash equivalents	$ 6,458	$ 5,028
Short-Term Investments	2,785	446
Investments and long-term receivables	8,225	7,113
Within one year | Carrying Amount
Debt Securities, Available-for-sale [Line Items]
Cash and cash equivalents	97	10
Short-Term Investments	603	221
Within one year | Carrying Amount | Corporate Bonds
Debt Securities, Available-for-sale [Line Items]
Cash and cash equivalents	0	3
Short-Term Investments	323	128
Within one year | Carrying Amount | Commercial Paper
Debt Securities, Available-for-sale [Line Items]
Cash and cash equivalents	97	7
Short-Term Investments	156	82
Within one year | Carrying Amount | U.S. Government Obligations
Debt Securities, Available-for-sale [Line Items]
Cash and cash equivalents	0	0
Short-Term Investments	115	0
Within one year | Carrying Amount | U.S. Government Agency Obligations
Debt Securities, Available-for-sale [Line Items]
Short-Term Investments	8	2
Within one year | Carrying Amount | Foreign Government Obligations
Debt Securities, Available-for-sale [Line Items]
Short-Term Investments	0	7
Within one year | Carrying Amount | Asset-backed Securities
Debt Securities, Available-for-sale [Line Items]
Short-Term Investments	1	2
One year through eight years | Carrying Amount
Debt Securities, Available-for-sale [Line Items]
Investments and long-term receivables	522	248
One year through eight years | Carrying Amount | Corporate Bonds
Debt Securities, Available-for-sale [Line Items]
Investments and long-term receivables	309	173
One year through eight years | Carrying Amount | U.S. Government Obligations
Debt Securities, Available-for-sale [Line Items]
Investments and long-term receivables	63	2
One year through eight years | Carrying Amount | U.S. Government Agency Obligations
Debt Securities, Available-for-sale [Line Items]
Investments and long-term receivables	5	8
One year through eight years | Carrying Amount | Foreign Government Obligations
Debt Securities, Available-for-sale [Line Items]
Investments and long-term receivables	7	2
One year through eight years | Carrying Amount | Asset-backed Securities
Debt Securities, Available-for-sale [Line Items]
Investments and long-term receivables	$ 138	$ 63

Derivative and Financial Inst_9

Derivative and Financial Instruments - Financial Instruments, Amortized Cost Basis and Fair Value of Investments in Debt Securities Classified as Available for Sale (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	$ 1,234	$ 479
Fair Value	1,222	479
Corporate Bonds
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	641	305
Fair Value	632	304
Commercial Paper
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	253	88
Fair Value	253	89
U.S. Government Obligations
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	181	2
Fair Value	178	2
U.S. Government Agency Obligations
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	13	10
Fair Value	13	10
Foreign Government Obligations
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	7	9
Fair Value	7	9
Asset-backed Securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	139	65
Fair Value	$ 139	$ 65

Fair Value Measurement - Fair V

Fair Value Measurement - Fair Value Hierarchy for Gross Financial Assets and Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	$ 0	$ 1,117
Commodity derivatives	2,037	1,243
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy		1,117
Investments in debt securities	1,222	479
Commodity derivatives	2,037	1,243
Total assets	3,259	2,839
Commodity derivatives	2,010	1,223
Total liabilities	2,010	1,223
Level 1 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy		1,117
Investments in debt securities	178	2
Commodity derivatives	958	562
Total assets	1,136	1,681
Commodity derivatives	906	593
Total liabilities	906	593
Level 2 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy		0
Investments in debt securities	1,044	477
Commodity derivatives	951	619
Total assets	1,995	1,096
Commodity derivatives	843	543
Total liabilities	843	543
Level 3 | Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy		0
Investments in debt securities	0	0
Commodity derivatives	128	62
Total assets	128	62
Commodity derivatives	261	87
Total liabilities	$ 261	$ 87

Fair Value Measurement - Commod

Fair Value Measurement - Commodity Derivative Balances Subject to Right of Setoff (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Offsetting Derivative Assets [Abstract]
Assets - Gross Amounts Recognized	$ 2,037	$ 1,243
Assets - Amounts Not Subject to Right of Setoff	39	85
Assets - Amounts Subject to Right of Setoff, Gross Amounts	1,998	1,158
Assets - Amounts Subject to Right of Setoff, Gross Amounts Offset	1,176	650
Assets - Amounts Subject to Right of Setoff, Net Amounts Presented	822	508
Assets - Amounts Subject to Right of Setoff, Cash Collateral	37	0
Assets - Amounts Subject to Right of Setoff, Net Amounts	785	508
Offsetting Derivative Liabilities [Abstract]
Liabilities - Gross Amounts Recognized	2,010	1,223
Liabilities - Amounts Not Subject to Right of Setoff	20	82
Liabilities - Amounts Subject to Right of Setoff, Gross Amounts	1,990	1,141
Liabilities - Amounts Subject to Right of Setoff, Gross Amounts Offset	1,176	650
Liabilities - Amounts Subject to Right of Setoff, Net Amounts Presented	814	491
Liabilities - Amounts Subject to Right of Setoff, Cash Collateral	52	36
Liabilities - Amounts Subject to Right of Setoff, Net Amounts	$ 762	$ 455

Fair Value Measurement - Values

Fair Value Measurement - Values of Assets, by Major Category, Measured at Fair Value on a Nonrecurring Basis (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Before-Tax Loss, Equity Method Investments	$ (2,081)	$ (832)	$ (432)
Fair Value, Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for use)		472
Before-Tax Loss - Net PP&E (Held for use)		80
Fair Value - Equity Method Investments		5,574
Before-Tax Loss, Equity Method Investments		688
Level 1 Inputs | Fair Value, Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for use)		0
Fair Value - Equity Method Investments		0
Level 2 Inputs | Fair Value, Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for use)		0
Fair Value - Equity Method Investments		5,574
Level 3 Inputs | Fair Value, Nonrecurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Fair Value - Net PP&E (held for use)		472
Fair Value - Equity Method Investments		$ 0

Fair Value Measurement - Range

Fair Value Measurement - Range and Arithmetic Average of Significant Unobservable Inputs (Details) - Lower 48 Gulf Coast and Rockies noncore field - Level 3 Inputs - Fair Value, Nonrecurring - Lower 48 $ in Millions	3 Months Ended	12 Months Ended
	Mar. 31, 2021 $ / MMBTU	Dec. 31, 2021 USD ($) MMcf
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Fair Value | $		$ 472
Measurement Input, Commodity Future Price | Valuation Technique, Discounted Cash Flow
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Future prices annual increase (decrease), percentage		2%
Measurement Input, Natural Gas | Valuation Technique, Discounted Cash Flow | Minimum
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Commodity production (MBOED) | MMcf		0.2
Oil and gas, price outlook | $ / MMBTU	41.45
Measurement Input, Natural Gas | Valuation Technique, Discounted Cash Flow | Maximum
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Commodity production (MBOED) | MMcf		17
Oil and gas, price outlook | $ / MMBTU	93.68
Measurement Input, Natural Gas | Valuation Technique, Discounted Cash Flow | Arithmetic Average
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Commodity production (MBOED) | MMcf		5.4
Oil and gas, price outlook | $ / MMBTU	64.39
Measurement Input, Discount Rate | Valuation Technique, Discounted Cash Flow | Minimum
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Discount rate	7.30%
Measurement Input, Discount Rate | Valuation Technique, Discounted Cash Flow | Maximum
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Discount rate	9.70%
Measurement Input, Discount Rate | Valuation Technique, Discounted Cash Flow | Arithmetic Average
Fair Value Measurement Inputs and Valuation Techniques [Line Items]
Discount rate	8.70%

Fair Value Measurement - Narrat

Fair Value Measurement - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Dec. 31, 2021	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Schedule of Equity Method Investments [Line Items]
Carrying value of equity method investment	$ 6,701	$ 7,493	$ 6,701
Impairments		$ (12)	$ 674	$ 813
APLNG
Schedule of Equity Method Investments [Line Items]
Equity interest of ConocoPhillips	10%		10%
Carrying value of equity method investment	$ 1,645		$ 1,645
APLNG | Equity Method Investments
Schedule of Equity Method Investments [Line Items]
Fair value, equity method investments	5,574		$ 5,574
Impairments	$ 688

Fair Value Measurement - Net Fa

Fair Value Measurement - Net Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Financial assets
Investment in CVE common shares	$ 0	$ 1,117
Carrying Amount
Financial assets
Investment in CVE common shares	0	1,117
Commodity derivatives	824	593
Investments in debt securities	1,222	479
Loans and advances—related parties	0	114
Financial liabilities
Total debt, excluding finance leases	15,323	18,673
Carrying Amount | Commodity
Financial liabilities
Commodity derivatives	782	537
Fair Value
Financial assets
Investment in CVE common shares	0	1,117
Commodity derivatives	824	593
Investments in debt securities	1,222	479
Loans and advances—related parties	0	114
Financial liabilities
Total debt, excluding finance leases	15,545	22,451
Fair Value | Commodity
Financial liabilities
Commodity derivatives	$ 782	$ 537

Equity - Changes in Shares of C

Equity - Changes in Shares of Common Stock (Details) - shares	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Issued
Beginning of year	2,091,562,747	1,798,844,267	1,795,652,203
Acquisition of Concho	0	285,928,872	0
Distributed under benefit plans	9,322,387	6,789,608	3,192,064
End of year	2,100,885,134	2,091,562,747	1,798,844,267
Held in Treasury
Beginning of year	789,319,875	730,802,089	710,783,814
Repurchase of common stock	87,709,187	58,517,786	20,018,275
End of year	877,029,062	789,319,875	730,802,089

Equity - Narrative (Details)

Equity - Narrative (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended			72 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2022	Oct. 31, 2022	Sep. 30, 2022
Equity [Abstract]
Preferred stock, authorized (in shares)	500,000,000	500,000,000		500,000,000
Preferred stock, par value per share (in dollars per share)	$ 0.01	$ 0.01		$ 0.01
Preferred stock, shares issued (in shares)	0	0		0
Preferred stock, share outstanding (in shares)	0	0		0
Stock repurchase program authorized					$ 45,000	$ 25,000
Treasury stock, shares acquired (in shares)				335,000,000
Repurchase of company common stock	$ 9,270	$ 3,623	$ 892	$ 23,000

Non-Mineral Leases - Right-of-U

Non-Mineral Leases - Right-of-Use Assets and Lease Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Right-of-Use Assets
Gross	$ 2,043	$ 1,812
Finance Leases, Properties, plants and equipment, Accumulated DD&A	(1,022)	$ (857)
Net PPE	$ 1,021
Finance Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Property, Plant, and Equipment and Finance Lease Right-of-Use Asset, after Accumulated Depreciation and Amortization	Property, Plant, and Equipment and Finance Lease Right-of-Use Asset, after Accumulated Depreciation and Amortization
Operating leases, right-of-use assets	$ 536
Operating Lease, Right-of-Use Asset, Statement of Financial Position [Extensible Enumeration]	Other Assets, Noncurrent
Finance leases	$ 1,320	$ 1,261
Total lease liabilities	545	667
Proportionately Consolidated
Right-of-Use Assets
Net PPE	171	208
Finance leases, current	169	154
Finance leases, noncurrent	399	462
Net PPE
Right-of-Use Assets
Net PPE		955
Prepaid expenses and other current assets
Right-of-Use Assets
Net PPE		2
Operating leases, right-of-use assets		16
Other assets
Right-of-Use Assets
Operating leases, right-of-use assets		649
Other accruals
Right-of-Use Assets
Total lease liabilities	155	188
Other liabilities and deferred credits
Right-of-Use Assets
Total lease liabilities	390	479
Short-term debt
Right-of-Use Assets
Finance leases	284	280
Long-term debt
Right-of-Use Assets
Finance leases	$ 1,036	$ 981

Non-Mineral Leases - Lease Cost

Non-Mineral Leases - Lease Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating lease cost	$ 212	$ 278	$ 321
Finance lease cost, amortization of right-of-use-assets	189	148	163
Finance lease cost, interest on lease liabilities	32	27	34
Short-term lease cost	94	21	42
Total lease cost	$ 527	$ 474	$ 560

Non-Mineral Leases - Lease Term

Non-Mineral Leases - Lease Term and Discount Rate (Details)	Dec. 31, 2022	Dec. 31, 2021
Leases [Abstract]
Weighted-average term, operating leases	5 years 7 months 20 days	5 years 11 months 19 days
Weighted-average term, finance leases	6 years 7 months 6 days	7 years 5 months 26 days
Weighted-average discount rate, operating leases	2.99%	2.66%
Weighted-average discount rate, finance leases	3.40%	3.24%

Non-Mineral Leases - Other Info

Non-Mineral Leases - Other Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Leases [Abstract]
Operating cash flows from operating leases	$ 148	$ 204	$ 232
Operating cash flows from finance leases	30	6	11
Financing cash flows from finance leases	166	73	255
Right-of-use assets obtained in exchange for operating lease liabilities	114	174	250
Right-of-use assets obtained in exchange for finance lease liabilities	$ 256	$ 447	$ 426

Non-Mineral Leases - Maturity o

Non-Mineral Leases - Maturity of Lease Liabilities (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Operating Leases
2023	$ 169
2024	126
2025	81
2026	59
2027	46
Remaining years	118
Total	599
Less: portion representing imputed interest	(54)
Total lease liabilities	545	$ 667
Finance Leases
2023	356
2024	215
2025	210
2026	207
2027	164
Remaining years	352
Total	1,504
Less: portion representing imputed interest	(184)
Total lease liabilities	$ 1,320	$ 1,261

Employee Benefit Plans - Change

Employee Benefit Plans - Change in Benefit Obligations and Fair Value of Plan Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Pension Benefits | United States
Change in Benefit Obligation
Benefit obligation, beginning balance	$ 1,924	$ 2,548
Service cost	58	73	$ 85
Interest cost	62	53	66
Plan participant contributions	0	0
Plan amendments	0	0
Actuarial (gain) loss	(325)	(117)
Benefits paid	(241)	(654)
Divestiture	0	0
Curtailment	0	12
Recognition of termination benefits	0	9
Foreign currency exchange rate change	0	0
Benefit obligation, ending balance	1,478	1,924	2,548
Accumulated benefit obligation	1,384	1,793
Change in Fair Value of Plan Assets
Fair value of plan assets, beginning balance	1,664	1,770
Actual return on plan assets	(319)	97
Company contributions	75	451
Plan participant contributions	0	0
Benefits paid	(241)	(654)
Divestiture	0	0
Foreign currency exchange rate change	0	0
Fair value of plan assets, ending balance	1,179	1,664	1,770
Funded Status	(299)	(260)
Pension Benefits | Int’l.
Change in Benefit Obligation
Benefit obligation, beginning balance	4,124	4,403
Service cost	47	61	54
Interest cost	77	79	85
Plan participant contributions	0	0
Plan amendments	0	0
Actuarial (gain) loss	(847)	(176)
Benefits paid	(144)	(162)
Divestiture	(56)	0
Curtailment	0	0
Recognition of termination benefits	0	0
Foreign currency exchange rate change	(425)	(81)
Benefit obligation, ending balance	2,776	4,124	4,403
Accumulated benefit obligation	2,542	3,658
Change in Fair Value of Plan Assets
Fair value of plan assets, beginning balance	4,812	4,793
Actual return on plan assets	(1,372)	147
Company contributions	96	119
Plan participant contributions	1	1
Benefits paid	(144)	(162)
Divestiture	(46)	0
Foreign currency exchange rate change	(468)	(86)
Fair value of plan assets, ending balance	2,879	4,812	4,793
Funded Status	103	688
Other Benefits
Change in Benefit Obligation
Benefit obligation, beginning balance	137	170
Service cost	1	2	2
Interest cost	4	4	6
Plan participant contributions	16	16
Plan amendments	9	0
Actuarial (gain) loss	(27)	(16)
Benefits paid	(38)	(40)
Divestiture	0	0
Curtailment	0	1
Recognition of termination benefits	0	0
Foreign currency exchange rate change	0	0
Benefit obligation, ending balance	102	137	170
Change in Fair Value of Plan Assets
Fair value of plan assets, beginning balance	0	0
Actual return on plan assets	0	0
Company contributions	22	24
Plan participant contributions	16	16
Benefits paid	(38)	(40)
Divestiture	0	0
Foreign currency exchange rate change	0	0
Fair value of plan assets, ending balance	0	0	$ 0
Funded Status	$ (102)	$ (137)

Employee Benefit Plans - Amount

Employee Benefit Plans - Amounts Recognized in Balance Sheet and Assumptions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract]
Noncurrent liabilities	$ (1,074)	$ (1,153)
Pension Benefits | United States
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract]
Noncurrent assets	0	1
Current liabilities	(28)	(29)
Noncurrent liabilities	(271)	(232)
Total recognized	$ (299)	$ (260)
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount rate	5.65%	2.80%
Rate of compensation increase	5%	4%
Interest crediting rate for applicable benefits	3.55%	2.50%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount rate	3.85%	2.60%
Expected return on plan assets	3.90%	5.20%
Rate of compensation increase	4%	4%
Interest crediting rate for applicable benefits	2.50%	2.10%
Pension Benefits | Int’l.
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract]
Noncurrent assets	$ 373	$ 991
Current liabilities	(10)	(15)
Noncurrent liabilities	(260)	(288)
Total recognized	$ 103	$ 688
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount rate	4.20%	2.15%
Rate of compensation increase	3.65%	3.40%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount rate	2.15%	1.80%
Expected return on plan assets	2.85%	2.50%
Rate of compensation increase	3.40%	3.40%
Other Benefits
Defined Benefit Plan, Amounts for Asset (Liability) Recognized in Statement of Financial Position [Abstract]
Noncurrent assets	$ 0	$ 0
Current liabilities	(32)	(34)
Noncurrent liabilities	(70)	(103)
Total recognized	$ (102)	$ (137)
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Benefit Obligation [Abstract]
Discount rate	5.65%	2.65%
Defined Benefit Plan, Weighted Average Assumptions Used in Calculating Net Periodic Benefit Cost [Abstract]
Discount rate	2.65%	2.35%

Employee Benefit Plans - Projec

Employee Benefit Plans - Projected and Accumulated Benefit Obligations in Excess of Fair Value (Details) - Pension Benefits - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
United States
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	$ 1,478	$ 261
Fair value of plan assets	1,179	0
Accumulated benefit obligation	1,384	234
Fair value of plan assets	1,179	0
Int’l.
Defined Benefit Plan Disclosure [Line Items]
Projected benefit obligation	277	362
Fair value of plan assets	6	58
Accumulated benefit obligation	239	271
Fair value of plan assets	$ 6	$ 9

Employee Benefit Plans - Before

Employee Benefit Plans - Before-Tax Amounts not Recognized in Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Unrecognized net actuarial loss (gain)	$ (28)	$ (1)
Unrecognized prior service cost (credit)	(98)	(145)
United States | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Unrecognized net actuarial loss (gain)	172	188
Unrecognized prior service cost (credit)	0	0
Int’l. | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Unrecognized net actuarial loss (gain)	681	86
Unrecognized prior service cost (credit)	$ 1	$ 1

Employee Benefit Plans - Befo_2

Employee Benefit Plans - Before-Tax Amounts not Recognized in Net Periodic Benefit Cost and Sources of Change in Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax [Abstract]
Net actuarial gain (loss) arising during the period	$ (623)	$ 357	$ (210)
Amortization of actuarial loss included in income (loss)	72	178	117
Prior service credit (cost) arising during the period	(10)	0	29
Amortization of prior service (credit) included in income (loss)	(39)	(38)	$ (32)
Pension Benefits | United States
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax [Abstract]
Net actuarial gain (loss) arising during the period	(44)	134
Amortization of actuarial loss included in income (loss)	61	145
Net change during the period	17	279
Prior service credit (cost) arising during the period	0	0
Amortization of prior service (credit) included in income (loss)	0	0
Net change during the period	0	0
Pension Benefits | Int’l.
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax [Abstract]
Net actuarial gain (loss) arising during the period	(606)	207
Amortization of actuarial loss included in income (loss)	11	33
Net change during the period	(595)	240
Prior service credit (cost) arising during the period	(1)	0
Amortization of prior service (credit) included in income (loss)	(1)	(1)
Net change during the period	(2)	(1)
Other Benefits
Other Comprehensive (Income) Loss, Defined Benefit Plan, after Reclassification Adjustment, before Tax [Abstract]
Net actuarial gain (loss) arising during the period	27	16
Amortization of actuarial loss included in income (loss)	0	0
Net change during the period	27	16
Prior service credit (cost) arising during the period	(9)	0
Amortization of prior service (credit) included in income (loss)	(38)	(37)
Net change during the period	$ (47)	$ (37)

Employee Benefit Plans - Compon

Employee Benefit Plans - Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Settlements loss (gain)	$ 37	$ 102	$ 43
Pension Benefits | United States
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	58	73	85
Interest cost	62	53	66
Expected return on plan assets	(50)	(80)	(85)
Amortization of prior service credit	0	0	0
Recognized net actuarial loss (gain)	24	43	51
Settlements loss (gain)	37	102	44
Curtailment loss	0	12	0
Net periodic benefit cost	131	203	161
Pension Benefits | Int’l.
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	47	61	54
Interest cost	77	79	85
Expected return on plan assets	(124)	(120)	(145)
Amortization of prior service credit	(1)	(1)	(1)
Recognized net actuarial loss (gain)	11	33	22
Settlements loss (gain)	0	0	(1)
Curtailment loss	0	0	0
Net periodic benefit cost	10	52	14
Other Benefits
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	1	2	2
Interest cost	4	4	6
Expected return on plan assets	0	0	0
Amortization of prior service credit	(38)	(37)	(31)
Recognized net actuarial loss (gain)	0	0	1
Settlements loss (gain)	0	0	0
Curtailment loss	0	0	0
Net periodic benefit cost	$ (33)	$ (31)	$ (22)

Employee Benefit Plans - Narrat

Employee Benefit Plans - Narrative (Details) $ / shares in Units, shares in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) investment_option $ / shares shares	Dec. 31, 2021 USD ($) $ / shares	Dec. 31, 2020 USD ($) $ / shares	Dec. 31, 2019 USD ($)
Defined Benefit Plan Disclosure [Line Items]
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) Excluding Service Cost, Statement of Income or Comprehensive Income [Extensible Enumeration]	Other Nonoperating Income (Expense)	Other Nonoperating Income (Expense)	Other Nonoperating Income (Expense)
Settlements loss (gain)	$ 37,000,000	$ 102,000,000	$ 43,000,000
Percent amortized for net actuarial gains and losses	10%
Aggregate intrinsic value, exercised	$ 308,000,000
Restricted Stock Units (RSUs) | Discontinued Operations
Defined Benefit Plan Disclosure [Line Items]
Unrecognized compensation cost from stock options	$ 10,000,000
Weighted average period of recognition of unvested options	1 year
Weighted-average grant date fair value, granted (in dollars per share) | $ / shares	$ 96.20	$ 46.43	$ 51.46
Total fair value, issued	$ 40,000,000	$ 8,000,000	$ 6,000,000
RSU Stock Settled
Defined Benefit Plan Disclosure [Line Items]
Unrecognized compensation cost from stock options	$ 135,000,000
Weighted average period of recognition of unvested options	1 year 8 months 1 day
Longest weighted-average period of recognition of unvested options	2 years 8 months 1 day
Weighted-average grant date fair value, granted (in dollars per share) | $ / shares	$ 90.57	$ 46.56	$ 57.40
Total fair value, issued	$ 193,000,000	$ 144,000,000	$ 143,000,000
RSU Cash Settled
Defined Benefit Plan Disclosure [Line Items]
Unrecognized compensation cost from stock options	$ 0
Weighted-average grant date fair value, granted (in dollars per share) | $ / shares	$ 85.37	$ 57.19	$ 41.59
Total fair value, issued	$ 21,000,000	$ 20,000,000
PSU Cash Settled Program
Defined Benefit Plan Disclosure [Line Items]
Unrecognized compensation cost from stock options	$ 0
Weighted-average grant date fair value, granted (in dollars per share) | $ / shares	$ 91.58	$ 46.65	$ 58.61
Total fair value, issued	$ 88,000,000	$ 52,000,000	$ 116,000,000
PSU Stock Settled
Defined Benefit Plan Disclosure [Line Items]
Unrecognized compensation cost from stock options	$ 0
Weighted-average grant date fair value, granted (in dollars per share) | $ / shares	$ 91.58		$ 58.61
Total fair value, issued	$ 21,000,000	18,000,000	$ 13,000,000
Twenty Fourteen Omnibus Stock and Performance Incentive Plan Of Conoco Phillips
Defined Benefit Plan Disclosure [Line Items]
Share based compensation plan, number of shares authorized | shares	79
Twenty Fourteen Omnibus Stock and Performance Incentive Plan Of Conoco Phillips | Share-based Payment Arrangement, Option
Defined Benefit Plan Disclosure [Line Items]
Weighted-average remaining contractual term of outstanding options	2 years 6 months 25 days
Aggregate intrinsic value, exercised		68,000,000	23,000,000
Cash received from exercise of stock options	$ 438,000,000	59,000,000
Employee Severance
Defined Benefit Plan Disclosure [Line Items]
Restructuring reserve	31,000,000	78,000,000	24,000,000	$ 23,000,000
Insurance Contract, Rights and Obligations
Defined Benefit Plan Disclosure [Line Items]
Participating interest in annuity contract, fair value	$ 55,000,000	83,000,000
Defined Benefit Plan, Equity Securities
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets, percentage	25%
Corporate
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets, percentage	71%
Real estate
Defined Benefit Plan Disclosure [Line Items]
Target allocations for plan assets, percentage	4%
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Settlements loss (gain)	$ 0	0	0
Other Benefits | Twenty Fourteen Omnibus Stock and Performance Incentive Plan Of Conoco Phillips
Defined Benefit Plan Disclosure [Line Items]
Omnibus stock and performance incentive plan life	10 years
United States
Defined Benefit Plan Disclosure [Line Items]
Expected future employer contributions, next fiscal year	$ 90,000,000
Maximum annual contributions per employee, percentage	75%
Number of investment options | investment_option	17
Employer matching contribution, percent of employee's gross pay	1%
Employer matching contribution, percent of match	6%
Company discretionary cash contribution, percentage	6%
Company contributions in savings plan and predecessor plans except leveraged employee stock ownership plan charged to expense	$ 140,000,000	93,000,000	62,000,000
United States | Defined Contribution Plan Company Retirement Contribution
Defined Benefit Plan Disclosure [Line Items]
Employer matching contribution, percent of match	6%
Defined contribution plan, employers vesting period	3 years
Defined contribution plan, vesting percent	100%
United States | Twenty Fourteen Omnibus Stock and Performance Incentive Plan Of Conoco Phillips
Defined Benefit Plan Disclosure [Line Items]
Share based compensation plan, number of shares authorized | shares	79
United States | Twenty Fourteen Omnibus Stock and Performance Incentive Plan Of Conoco Phillips | Incentive Stock Options
Defined Benefit Plan Disclosure [Line Items]
Share based compensation plan, number of shares authorized | shares	40
United States | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Settlements loss (gain)	$ 37,000,000	102,000,000	44,000,000
Accumulated benefit obligation	1,384,000,000	1,793,000,000
United States | Pension Benefits | Level 3 Inputs | Insurance Contract, Rights and Obligations
Defined Benefit Plan Disclosure [Line Items]
Participating interest in annuity contract, fair value	55,000,000	83,000,000
Accumulated benefit obligation	89,000,000	123,000,000
United States | Pension Benefits | Corporate | Level 3 Inputs | Insurance Contract, Rights and Obligations
Defined Benefit Plan Disclosure [Line Items]
Participating interest in annuity contract, fair value	144,000,000	206,000,000
Int’l.
Defined Benefit Plan Disclosure [Line Items]
Expected future employer contributions, next fiscal year	45,000,000
Company contributions in savings plan and predecessor plans except leveraged employee stock ownership plan charged to expense	24,000,000	26,000,000	25,000,000
Int’l. | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Settlements loss (gain)	0	0	$ (1,000,000)
Accumulated benefit obligation	$ 2,542,000,000	$ 3,658,000,000
COP Pre Sixty Five Retiree | United States | Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate, next fiscal year	6.50%
Ultimate health care cost trend rate	5%
Post Sixty Five Retiree | United States | Other Benefits
Defined Benefit Plan Disclosure [Line Items]
Health care cost trend rate, next fiscal year	4.50%
Ultimate health care cost trend rate	5%
Short term supplemental unemployment benefits | Employee Severance
Defined Benefit Plan Disclosure [Line Items]
Restructuring reserve	$ 19,000,000

Employee Benefit Plans - Fair V

Employee Benefit Plans - Fair Values of Pension Plan Assets (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Defined Benefit Plan Disclosure [Line Items]
Net receivables related to security transactions	$ 5	$ 5
United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	55	68
Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	1,046	1,375
Insurance Contract, Rights and Obligations
Defined Benefit Plan Disclosure [Line Items]
Participating interest in annuity contract, fair value	55	83
Investments measured at net asset value | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	1,123	1,580
Investments measured at net asset value | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	2,875	4,808
U.S. | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	4	8
U.S. | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
International | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	36	42
International | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Mutual funds | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	14	17
Mutual funds | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	499	639
Corporate | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	1	1
Corporate | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Mutual funds | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Mutual funds | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	365	511
Cash and cash equivalents | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Cash and cash equivalents | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	36	68
Cash and cash equivalents | Investments measured at net asset value | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	10	9
Cash and cash equivalents | Investments measured at net asset value | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Derivatives | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets		0
Derivatives | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets		0
Real estate | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Real estate | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	146	157
Real estate | Investments measured at net asset value | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	34	36
Real estate | Investments measured at net asset value | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	1
Equity securities, Common/collective trusts | Investments measured at net asset value | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	265	394
Equity securities, Common/collective trusts | Investments measured at net asset value | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	192	417
Debt securities, Common/collective trusts | Investments measured at net asset value | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	759	1,073
Debt securities, Common/collective trusts | Investments measured at net asset value | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	1,637	3,015
Level 1 | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	54	62
Level 1 | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	602	815
Level 1 | Investments measured at net asset value | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	54	62
Level 1 | Investments measured at net asset value | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	602	815
Level 1 | U.S. | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	4	3
Level 1 | U.S. | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 1 | International | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	36	42
Level 1 | International | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 1 | Mutual funds | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	14	17
Level 1 | Mutual funds | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	201	236
Level 1 | Corporate | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 1 | Corporate | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 1 | Mutual funds | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 1 | Mutual funds | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	365	511
Level 1 | Cash and cash equivalents | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 1 | Cash and cash equivalents | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	36	68
Level 1 | Derivatives | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets		0
Level 1 | Derivatives | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets		0
Level 1 | Real estate | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 1 | Real estate | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	1	1
Level 2 | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	298	403
Level 2 | Investments measured at net asset value | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	1	1
Level 2 | Investments measured at net asset value | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	298	403
Level 2 | U.S. | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | U.S. | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | International | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | International | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | Mutual funds | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | Mutual funds | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	298	403
Level 2 | Corporate | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	1	1
Level 2 | Corporate | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | Mutual funds | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | Mutual funds | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | Cash and cash equivalents | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | Cash and cash equivalents | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | Derivatives | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets		0
Level 2 | Derivatives | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets		0
Level 2 | Real estate | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 2 | Real estate | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	5
Level 3 | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	146	157
Level 3 | Investments measured at net asset value | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	5
Level 3 | Investments measured at net asset value | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	146	157
Level 3 | U.S. | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	5
Level 3 | U.S. | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | International | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | International | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Mutual funds | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Mutual funds | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Corporate | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Corporate | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Mutual funds | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Mutual funds | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Cash and cash equivalents | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Cash and cash equivalents | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Derivatives | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets		0
Level 3 | Derivatives | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets		0
Level 3 | Real estate | United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	0	0
Level 3 | Real estate | Int’l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, fair value of selected plan assets	$ 146	$ 157

Employee Benefit Plans - Benefi

Employee Benefit Plans - Benefit Payments (Details) $ in Millions	Dec. 31, 2022 USD ($)
Pension Benefits | United States
Defined Benefit Plan Disclosure [Line Items]
2023	$ 216
2024	199
2025	188
2026	173
2027	171
2028–2032	685
Pension Benefits | Int’l.
Defined Benefit Plan Disclosure [Line Items]
2023	121
2024	123
2025	125
2026	126
2027	128
2028–2032	677
Other Benefits
Defined Benefit Plan Disclosure [Line Items]
2023	17
2024	15
2025	14
2026	12
2027	11
2028–2032	$ 38

Employee Benefit Plans - Severa

Employee Benefit Plans - Severance Accrual (Details) - Employee Severance - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Restructuring Reserve [Roll Forward]
Beginning balance	$ 78	$ 24	$ 23
Accruals	1	170	14
Benefit payments	(48)	(116)	(13)
Ending balance	$ 31	$ 78	$ 24

Employee Benefit Plans - Compen

Employee Benefit Plans - Compensation Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Retirement Benefits [Abstract]
Compensation cost	$ 377	$ 304	$ 159
Tax benefit	$ 95	$ 76	$ 40

Employee Benefit Plans - Stock

Employee Benefit Plans - Stock Option Activity (Details) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2022 USD ($) $ / shares shares
Options
Options, Outstanding, beginning balance (in shares) | shares	11,973,783
Options, Exercised (in shares) | shares	(7,670,208)
Options, Expired or cancelled (in shares) | shares	0
Options, Outstanding, ending balance (in shares) | shares	4,303,575
Stock option, Vested (in shares) | shares	4,303,575
Stock option, Exercisable at end of year (in shares) | shares	4,303,575
Weighted-Average Exercise Price
Weighted-Average Exercise Price, Outstanding, beginning balance (in dollars per share) | $ / shares	$ 56.46
Weighted-Average Exercise Price, exercised (in dollars per share) | $ / shares	57.12
Weighted-Average Exercise Price, Expired or canceled (in dollars per share) | $ / shares	0
Weighted-Average Exercise Price, Outstanding, ending balance (in dollars per share) | $ / shares	55.28
Weighted-Average Exercise Price, Vested (in dollars per share) | $ / shares	55.28
Weighted-Average Exercise Price, Exercisable (in dollars per share) | $ / shares	$ 55.28
Aggregate Intrinsic Value
Aggregate Intrinsic Value, Outstanding, beginning balance | $	$ 188
Aggregate Intrinsic Value, Exercised | $	(308)
Aggregate Intrinsic Value, Outstanding, ending balance | $	266
Aggregate Intrinsic Value, Vested | $	266
Aggregate Intrinsic Value, Exercisable | $	$ 266

Employee Benefit Plans - Restri

Employee Benefit Plans - Restricted Stock Unit and Performance Share Program Activity (Details) - USD ($) $ / shares in Units, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Restricted Stock Units (RSUs) | Discontinued Operations
Stock Units
Stock Units, Outstanding, beginning balance (in shares)	1,616,367
Stock Units, Granted (in shares)	73,450
Stock Units, Forfeited/Settled/Cancelled (in shares)	(1,030)
Stock Units, Issued (in shares)	(449,028)
Stock Units, Outstanding, ending balance (in shares)	1,239,759	1,616,367
Stock Units, Not Vested at end of year (in shares)	437,994
Weighted-Average Grant Date Fair Value
Weighted-Average Grant Date Fair Value, Outstanding, beginning balance (in dollars per share)	$ 47.24
Weighted-Average Grant Date Fair Value, Granted (in dollars per share)	96.20	$ 46.43	$ 51.46
Weighted-Average Grant Date Fair Value, Forfeited/Settled/Cancelled (in dollars per share)	24.61
Weighted-Average Grant Date Fair Value, Issued (in dollars per share)	48.28
Weighted-Average Grant Date Fair Value, Outstanding, ending balance (in dollars per share)	49.78	$ 47.24
Weighted-Average Grant Date Not Vested at end of year (in dollars per share)	$ 45.90
Total Fair Value, Issued	$ 40	$ 8	$ 6
RSU Stock Settled
Stock Units
Stock Units, Outstanding, beginning balance (in shares)	7,645,311
Stock Units, Granted (in shares)	2,139,168
Stock Units, Forfeited/Settled/Cancelled (in shares)	(137,011)
Stock Units, Issued (in shares)	(2,069,275)
Stock Units, Outstanding, ending balance (in shares)	7,578,193	7,645,311
Stock Units, Not Vested at end of year (in shares)	5,264,282
Weighted-Average Grant Date Fair Value
Weighted-Average Grant Date Fair Value, Outstanding, beginning balance (in dollars per share)	$ 53.81
Weighted-Average Grant Date Fair Value, Granted (in dollars per share)	90.57	$ 46.56	$ 57.40
Weighted-Average Grant Date Fair Value, Forfeited/Settled/Cancelled (in dollars per share)	71.38
Weighted-Average Grant Date Fair Value, Issued (in dollars per share)	63.57
Weighted-Average Grant Date Fair Value, Outstanding, ending balance (in dollars per share)	61.20	$ 53.81
Weighted-Average Grant Date Not Vested at end of year (in dollars per share)	$ 61.58
Total Fair Value, Issued	$ 193	$ 144	$ 143
RSU Cash Settled
Stock Units
Stock Units, Outstanding, beginning balance (in shares)	226,476
Stock Units, Granted (in shares)	531
Stock Units, Forfeited/Settled/Cancelled (in shares)	0
Stock Units, Issued (in shares)	(227,007)
Stock Units, Outstanding, ending balance (in shares)	0	226,476
Weighted-Average Grant Date Fair Value
Weighted-Average Grant Date Fair Value, Outstanding, beginning balance (in dollars per share)	$ 72.18
Weighted-Average Grant Date Fair Value, Granted (in dollars per share)	85.37	$ 57.19	$ 41.59
Weighted-Average Grant Date Fair Value, Forfeited/Settled/Cancelled (in dollars per share)	0
Weighted-Average Grant Date Fair Value, Issued (in dollars per share)	91.47
Weighted-Average Grant Date Fair Value, Outstanding, ending balance (in dollars per share)	$ 0	$ 72.18
Total Fair Value, Issued	$ 21	$ 20
PSU Stock Settled
Stock Units
Stock Units, Outstanding, beginning balance (in shares)	1,448,847
Stock Units, Granted (in shares)	1,754
Stock Units, Issued (in shares)	(218,986)
Stock Units, Outstanding, ending balance (in shares)	1,231,615	1,448,847
Weighted-Average Grant Date Fair Value
Weighted-Average Grant Date Fair Value, Outstanding, beginning balance (in dollars per share)	$ 50.69
Weighted-Average Grant Date Fair Value, Granted (in dollars per share)	91.58		$ 58.61
Weighted-Average Grant Date Fair Value, Issued (in dollars per share)	51.04
Weighted-Average Grant Date Fair Value, Outstanding, ending balance (in dollars per share)	$ 50.68	$ 50.69
Total Fair Value, Issued	$ 21	$ 18	$ 13
PSU Cash Settled Program
Stock Units
Stock Units, Outstanding, beginning balance (in shares)	117,679
Stock Units, Granted (in shares)	967,151
Stock Units, Forfeited/Settled/Cancelled (in shares)	(975,007)
Stock Units, Outstanding, ending balance (in shares)	109,823	117,679
Weighted-Average Grant Date Fair Value
Weighted-Average Grant Date Fair Value, Outstanding, beginning balance (in dollars per share)	$ 72.18
Weighted-Average Grant Date Fair Value, Granted (in dollars per share)	91.58	$ 46.65	$ 58.61
Weighted-Average Grant Date Fair Value, Forfeited/Settled/Cancelled (in dollars per share)	89.87
Weighted-Average Grant Date Fair Value, Outstanding, ending balance (in dollars per share)	$ 117.11	$ 72.18
Total Fair Value, Issued	$ 88	$ 52	$ 116

Income Taxes - Components of Pr

Income Taxes - Components of Provision (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Federal
Current	$ 1,263	$ 32	$ 3
Deferred	1,629	1,161	(625)
Foreign
Current	5,813	3,128	350
Deferred	387	66	(70)
State and local
Current	386	127	(4)
Deferred	70	119	(139)
Total tax provision (benefit)	$ 9,548	$ 4,633	$ (485)

Income Taxes - Components of De

Income Taxes - Components of Deferred Tax Liabilities and Assets (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020	Dec. 31, 2019
Deferred Tax Liabilities
PP&E and intangibles	$ 11,100	$ 10,170
Inventory	48	44
Other	190	213
Total deferred tax liabilities	11,338	10,427
Deferred Tax Assets
Benefit plan accruals	450	321
Asset retirement obligations and accrued environmental costs	2,333	2,297
Investments in joint ventures	1,917	1,684
Other financial accruals and deferrals	736	827
Loss and credit carryforwards	6,354	7,402
Other	112	399
Total deferred tax assets	11,902	12,930
Less: valuation allowance	(8,049)	(8,342)	$ (9,965)	$ (10,214)
Total deferred tax assets net of valuation allowance	3,853	4,588
Net deferred tax liabilities	$ 7,485	$ 5,839

Income Taxes - Narrative (Detai

Income Taxes - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income Taxes Information [Line Items]
Net deferred tax assets		$ 3,853	$ 4,588
Deferred income taxes		7,726	6,179
U.S. foreign tax credits		5,300
Adjustment to valuation allowance		5	(45)	$ 460
Undistributed earnings of foreign subsidiaries		4,477
Estimated tax payable on undistributed unremitted foreign income		224
Unrecognized tax benefits that would impact effective tax rate		701	1,261	1,128
Recognized federal and state tax benefit		515
Unrecognized tax benefits, income tax penalties and interest accrued		35	47	46
Interest and penalties (benefiting) charging earnings		(12)	1	4
Income tax provision (benefit)		9,548	4,633	(485)
Certain Jurisdictions Outside Of Domestic
Income Taxes Information [Line Items]
Operating loss carryforwards		1,100
Australia West
Income Taxes Information [Line Items]
Increase (decrease) in valuation allowance				178
Disposition				587
Reversal of deferred tax assets				92
Income tax provision (benefit)				(10)
Capital loss tax benefit				$ 313
Norwegian Tax Administration
Income Taxes Information [Line Items]
Adjustment to valuation allowance	$ 58
Disposition CVE Common Shares
Income Taxes Information [Line Items]
Increase (decrease) in valuation allowance			218
Impairment Of APLNG Investment
Income Taxes Information [Line Items]
Increase (decrease) in valuation allowance			206
Disposition Of Indonesia Entities
Income Taxes Information [Line Items]
U.S. foreign tax credits			29
Noncurrent Assets
Income Taxes Information [Line Items]
Net deferred tax assets		$ 241	$ 340

Income Taxes - Reconciliation o

Income Taxes - Reconciliation of Deferred Tax Asset Valuation Allowance (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Deferred Tax Asset Valuation Allowance [Roll Forward]
Beginning balance	$ 8,342	$ 9,965	$ 10,214
Charged to expense (benefit)	5	(45)	460
Other	(298)	(1,578)	(709)
Ending balance	$ 8,049	$ 8,342	$ 9,965

Income Taxes - Unrecognized Tax

Income Taxes - Unrecognized Tax Benefits (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Beginning balance	$ 1,345	$ 1,206	$ 1,177
Additions based on tax positions related to the current year	6	15	6
Additions for tax positions of prior years	6	177	67
Reductions for tax positions of prior years	(62)	(5)	(34)
Settlements	(510)	0	(9)
Lapse of statute	(75)	(48)	(1)
Ending balance	$ 710	$ 1,345	$ 1,206

Income Taxes - Effective Income

Income Taxes - Effective Income Tax Rate Reconciliation (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Income (loss) before income taxes
United States	$ 16,739	$ 8,024	$ (3,587)
Foreign	11,489	4,688	447
Income (loss) before income taxes	28,228	12,712	(3,140)
Federal statutory income tax	5,928	2,670	(659)
Non-U.S. effective tax rates	3,866	1,915	194
Australia disposition	0	0	(349)
Recovery of outside basis	(30)	(55)	(22)
Adjustment to tax reserves	(551)	(11)	18
Adjustment to valuation allowance	5	(45)	460
State income tax	405	194	(112)
Enhanced oil recovery credit	(37)	(99)	(6)
Other	(38)	64	(9)
Total tax provision (benefit)	$ 9,548	$ 4,633	$ (485)
Income (loss) before income taxes, United States, Percent of Pre-Tax Income (Loss)	59.30%	63.10%	114.20%
Income (loss) before income taxes, Foreign, Percent of Pre-Tax Income (Loss)	40.70%	36.90%	(14.20%)
Income (loss) before income taxes, Percent of Pre-Tax Income (Loss)	100%	100%	100%
Federal statutory income tax, Percent of Pre-Tax Income (Loss)	21%	21%	21%
Non-U.S. effective tax rates, Percent of Pre-Tax Income (Loss)	13.70%	15.10%	(6.20%)
Australia disposition, Percent of Pre-Tax Income (Loss)	0%	0%	11.10%
Recovery of outside basis, Percent of Pre-Tax Income (Loss)	(0.10%)	(0.40%)	0.70%
Adjustment to tax reserves, Percent of Pre-Tax Income (Loss)	(2.00%)	(0.10%)	(0.60%)
Adjustment to valuation allowances, Percent of Pre-Tax Income (Loss)	0%	(0.40%)	(14.60%)
State income tax, Percent of Pre-Tax Income (Loss)	1.40%	1.50%	3.60%
Enhanced oil recovery credit, Percent of Pre-Tax Income (Loss)	(0.10%)	(0.80%)	0.20%
Other, Percent of Pre-Tax Income (Loss)	(0.10%)	0.50%	0.30%
Total, Percent of Pre-Tax Income (Loss)	33.80%	36.40%	15.50%

Accumulated Other Comprehensi_3

Accumulated Other Comprehensive Loss - Components of Accumulated Other Comprehensive Loss in the Equity Section of the Balance Sheet (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning Balance	$ 45,406	$ 29,849	$ 35,050
Ending Balance	48,003	45,406	29,849
Defined Benefit Plans
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning Balance	(31)	(425)	(350)
Other comprehensive income (loss)	(417)	394	(75)
Ending Balance	(448)	(31)	(425)
Net Unrealized Gain/(Loss) on Securities
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning Balance	0	2	0
Other comprehensive income (loss)	(11)	(2)	2
Ending Balance	(11)	0	2
Foreign Currency Translation
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning Balance	(4,919)	(4,795)	(5,007)
Other comprehensive income (loss)	(622)	(124)	212
Ending Balance	(5,541)	(4,919)	(4,795)
Accumulated Other Comprehensive Loss
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Beginning Balance	(4,950)	(5,218)	(5,357)
Other comprehensive income (loss)	(1,050)	268	139
Ending Balance	$ (6,000)	$ (4,950)	$ (5,218)

Accumulated Other Comprehensi_4

Accumulated Other Comprehensive Loss - Items Reclassified out of Accumulated Other Comprehensive Income (Loss) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Defined Benefit Plans	$ 26	$ 109
Above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of:	$ 7	$ 31

Cash Flow Information (Details)

Cash Flow Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Supplemental Cash Flow Information [Abstract]
Increase (decrease) in PP&E related to an increase (decrease) in asset retirement obligations	$ 825	$ 442	$ (116)
Interest	873	924	785
Income taxes	7,368	856	905
Short-term investments purchased	(5,046)	(5,554)	(12,435)
Short-term investments sold	3,102	8,810	12,015
Investments and long-term receivables purchased	(775)	(279)	(325)
Investments and long-term receivables sold	90	114	87
Net Sales (Purchases) of Investments	$ (2,629)	$ 3,091	$ (658)

Other Financial Information - O

Other Financial Information - Other Financial Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Interest and Debt Expense
Debt	$ 791	$ 887	$ 788
Other	72	59	73
Interest costs incurred	863	946	861
Capitalized	(58)	(62)	(55)
Expensed	805	884	806
Other Income (Loss)
Interest income	195	33	100
Gain (loss) on investment in Cenovus Energy	251	1,040	(855)
Other, net	58	130	246
Other nonoperating income (expense)	504	1,203	(509)
Research and Development Expenditures—expensed	71	62	75
Shipping and Handling Costs	7,006	5,694	4,344
Foreign Currency Transaction (Gains) Losses—after-tax	(80)	(16)	(62)
Operating Segments | Alaska
Other Income (Loss)
Interest income	0	0	0
Foreign Currency Transaction (Gains) Losses—after-tax	0	0	0
Operating Segments | Lower 48
Other Income (Loss)
Foreign Currency Transaction (Gains) Losses—after-tax	0	0	0
Operating Segments | Canada
Other Income (Loss)
Foreign Currency Transaction (Gains) Losses—after-tax	(20)	(1)	(7)
Operating Segments | Europe, Middle East and North Africa
Other Income (Loss)
Interest income	1	2	5
Foreign Currency Transaction (Gains) Losses—after-tax	(110)	(11)	(15)
Operating Segments | Asia Pacific
Other Income (Loss)
Interest income	9	9	7
Foreign Currency Transaction (Gains) Losses—after-tax	30	2	(11)
Operating Segments | Other International
Other Income (Loss)
Interest income	0	0	0
Foreign Currency Transaction (Gains) Losses—after-tax	(1)	1	2
Corporate and Other
Interest and Debt Expense
Expensed	805	884	806
Other Income (Loss)
Interest income	185	22	88
Foreign Currency Transaction (Gains) Losses—after-tax	21	(7)	(31)
Shipping and Handling Costs
Other Income (Loss)
Shipping and Handling Costs	$ 1,595	$ 1,047	$ 857

Other Financial Information - P

Other Financial Information - Property Plant And Equipment (Details) - USD ($) $ in Millions	Dec. 31, 2022	Dec. 31, 2021
Other Income and Expenses [Abstract]
Proved properties	$ 119,609	$ 114,274
Capitalized costs, unproved properties	7,325	10,993
Other	4,562	4,379
Gross properties, plants and equipment	131,496	129,646
Less: Accumulated depreciation, depletion and amortization	(66,630)	(64,735)
Net properties, plants and equipment	$ 64,866	$ 64,911

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Related Party Transactions [Abstract]
Operating revenues and other income	$ 88	$ 88	$ 79
Purchases	1	5	0
Operating expenses and selling, general and administrative expenses	189	196	63
Net interest income	$ (1)	$ (2)	$ (5)

Sales and Other Operating Rev_3

Sales and Other Operating Revenues - Disaggregation of Revenue (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Revenue from contracts with customers	$ 61,049	$ 34,590	$ 13,662
Total Revenues and Other Income	78,494	45,828	18,784
Physical contracts meeting the definition of a derivative
Revenue from contracts outside the scope of ASC Topic 606	17,150	11,500	5,177
Financial derivative contracts
Revenue from contracts outside the scope of ASC Topic 606	295	(262)	(55)
Crude oil
Revenue from contracts outside the scope of ASC Topic 606	495	757	395
Natural gas
Revenue from contracts outside the scope of ASC Topic 606	15,368	10,034	4,339
Other
Revenue from contracts outside the scope of ASC Topic 606	1,287	709	443
Lower 48 | Physical contracts meeting the definition of a derivative
Revenue from contracts outside the scope of ASC Topic 606	13,919	9,050	3,966
Canada | Physical contracts meeting the definition of a derivative
Revenue from contracts outside the scope of ASC Topic 606	2,717	1,457	727
Europe, Middle East and North Africa
Total Revenues and Other Income	11,271	5,902	1,919
Europe, Middle East and North Africa | Physical contracts meeting the definition of a derivative
Revenue from contracts outside the scope of ASC Topic 606	$ 514	$ 993	$ 484

Sales and Other Operating Rev_4

Sales and Other Operating Revenues - Narrative (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Accounts receivables, after allowance for credit loss	$ 5,241	$ 5,268
Revenue recognized	57
Outstanding contract liability	$ 19

Earnings Per Share - Earnings P

Earnings Per Share - Earnings Per Share, Basic and Diluted (Details) - USD ($) $ / shares in Units, shares in Thousands, $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Basic earnings per share
Net Income (Loss) attributable to ConocoPhillips	$ 18,680	$ 8,079	$ (2,701)
Less: Dividends and undistributed earnings allocated to participating securities	60	19	6
Net Income (Loss) available to common shareholders	$ 18,620	$ 8,060	$ (2,707)
Average common shares outstanding (in shares)	1,274,028	1,324,194	1,078,030
Net income (loss) attributable to ConocoPhillips per share, basic (in dollars per share)	$ 14.62	$ 6.09	$ (2.51)
Diluted earnings per share
Net Income (Loss) available to common shareholders	$ 18,620	$ 8,060	$ (2,707)
Add: Dilutive impact of options and unvested non-participating RSU/PSUs	4,000	4,000	0
Average diluted shares outstanding (in shares)	1,278,163	1,328,151	1,078,030
Net income (loss) attributable to ConocoPhillips per share, diluted (in dollars per share)	$ 14.57	$ 6.07	$ (2.51)

Segment Disclosures and Relat_3

Segment Disclosures and Related Information - Narrative (Details)	12 Months Ended
	Dec. 31, 2022 segment
Segment Reporting [Abstract]
Number of operating segments	6

Segment Disclosures and Relat_4

Segment Disclosures and Related Information - Sales and Other Operating Revenues (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 78,494	$ 45,828	$ 18,784
Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	78,494	45,828	18,784
Corporate and Other
Segment Reporting Information [Line Items]
Sales and other operating revenues	96	75	18
Alaska
Segment Reporting Information [Line Items]
Sales and other operating revenues	7,905	5,480	3,408
Alaska | Intersegment eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues	0	0	(11)
Alaska | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	7,905	5,480	3,397
Lower 48
Segment Reporting Information [Line Items]
Sales and other operating revenues	52,921	29,306	9,872
Lower 48 | Intersegment eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues	(18)	(12)	(51)
Lower 48 | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	52,903	29,294	9,821
Canada
Segment Reporting Information [Line Items]
Sales and other operating revenues	6,159	4,077	1,666
Canada | Intersegment eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues	(2,445)	(1,583)	(405)
Canada | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	3,714	2,494	1,261
Europe, Middle East and North Africa
Segment Reporting Information [Line Items]
Sales and other operating revenues	11,271	5,902	1,919
Europe, Middle East and North Africa | Intersegment eliminations
Segment Reporting Information [Line Items]
Sales and other operating revenues	(1)	0	(2)
Europe, Middle East and North Africa | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	11,270	5,902	1,917
Asia Pacific | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	2,606	2,579	2,363
Other International | Operating Segments
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 0	$ 4	$ 7

Segment Disclosures and Relat_5

Segment Disclosures and Related Information - Depreciation, Depletion, Amortization and Impairments, Equity in Earnings of Affiliates and Income Tax Provision (Benefit) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Consolidated depreciation, depletion, amortization and impairments	$ 7,492	$ 7,882	$ 6,334
Consolidated equity in earnings of affiliates	2,081	832	432
Consolidated income tax provision (benefit)	9,548	4,633	(485)
Corporate and Other
Segment Reporting Information [Line Items]
Consolidated depreciation, depletion, amortization and impairments	44	76	54
Consolidated equity in earnings of affiliates	0	0	0
Consolidated income tax provision (benefit)	(609)	(282)	(76)
Alaska | Operating Segments
Segment Reporting Information [Line Items]
Consolidated depreciation, depletion, amortization and impairments	941	1,002	996
Consolidated equity in earnings of affiliates	4	5	(7)
Consolidated income tax provision (benefit)	885	402	(256)
Lower 48 | Operating Segments
Segment Reporting Information [Line Items]
Consolidated depreciation, depletion, amortization and impairments	4,854	4,067	3,358
Consolidated equity in earnings of affiliates	(14)	(18)	(11)
Consolidated income tax provision (benefit)	3,088	1,390	(378)
Canada | Operating Segments
Segment Reporting Information [Line Items]
Consolidated depreciation, depletion, amortization and impairments	400	392	342
Consolidated equity in earnings of affiliates	0	0	0
Consolidated income tax provision (benefit)	206	150	(185)
Europe, Middle East and North Africa | Operating Segments
Segment Reporting Information [Line Items]
Consolidated depreciation, depletion, amortization and impairments	735	862	775
Consolidated equity in earnings of affiliates	780	502	311
Consolidated income tax provision (benefit)	5,445	2,543	136
Asia Pacific | Operating Segments
Segment Reporting Information [Line Items]
Consolidated depreciation, depletion, amortization and impairments	518	1,483	809
Consolidated equity in earnings of affiliates	1,310	343	137
Consolidated income tax provision (benefit)	480	483	294
Other International | Operating Segments
Segment Reporting Information [Line Items]
Consolidated depreciation, depletion, amortization and impairments	0	0	0
Consolidated equity in earnings of affiliates	1	0	2
Consolidated income tax provision (benefit)	$ 53	$ (53)	$ (20)

Segment Disclosures and Relat_6

Segment Disclosures and Related Information - Net Income (Loss) Attributable to ConocoPhillips, Investments In and Advances To Affiliates and Total Assets (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Consolidated net income (loss) attributable to ConocoPhillips	$ 18,680	$ 8,079	$ (2,701)
Consolidated investments in and advances to affiliates	7,493	6,701	7,710
Consolidated total assets	93,829	90,661	62,618
Corporate and Other
Segment Reporting Information [Line Items]
Consolidated net income (loss) attributable to ConocoPhillips	(330)	(210)	(1,880)
Consolidated investments in and advances to affiliates	0	0	0
Consolidated total assets	11,008	7,745	8,987
Alaska | Operating Segments
Segment Reporting Information [Line Items]
Consolidated net income (loss) attributable to ConocoPhillips	2,352	1,386	(719)
Consolidated investments in and advances to affiliates	55	58	62
Consolidated total assets	15,126	14,812	14,623
Lower 48 | Operating Segments
Segment Reporting Information [Line Items]
Consolidated net income (loss) attributable to ConocoPhillips	11,015	4,932	(1,122)
Consolidated investments in and advances to affiliates	235	242	25
Consolidated total assets	42,950	41,699	11,932
Canada | Operating Segments
Segment Reporting Information [Line Items]
Consolidated net income (loss) attributable to ConocoPhillips	714	458	(326)
Consolidated investments in and advances to affiliates	0	0	0
Consolidated total assets	6,971	7,439	6,863
Europe, Middle East and North Africa | Operating Segments
Segment Reporting Information [Line Items]
Consolidated net income (loss) attributable to ConocoPhillips	2,244	1,167	448
Consolidated investments in and advances to affiliates	1,049	797	918
Consolidated total assets	8,263	9,125	8,756
Asia Pacific | Operating Segments
Segment Reporting Information [Line Items]
Consolidated net income (loss) attributable to ConocoPhillips	2,736	453	962
Consolidated investments in and advances to affiliates	6,154	5,603	6,705
Consolidated total assets	9,511	9,840	11,231
Other International | Operating Segments
Segment Reporting Information [Line Items]
Consolidated net income (loss) attributable to ConocoPhillips	(51)	(107)	(64)
Consolidated investments in and advances to affiliates	0	1	0
Consolidated total assets	$ 0	$ 1	$ 226

Segment Disclosures and Relat_7

Segment Disclosures and Related Information - Capital Expenditures and Investments and Interest Income and Expense (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Consolidated capital expenditures and investments	$ 10,159	$ 5,324	$ 4,715
Interest income	195	33	100
Interest and debt expense	805	884	806
Corporate and Other
Segment Reporting Information [Line Items]
Consolidated capital expenditures and investments	30	53	40
Interest income	185	22	88
Interest and debt expense	805	884	806
Alaska | Operating Segments
Segment Reporting Information [Line Items]
Consolidated capital expenditures and investments	1,091	982	1,038
Interest income	0	0	0
Lower 48 | Operating Segments
Segment Reporting Information [Line Items]
Consolidated capital expenditures and investments	5,630	3,129	1,881
Interest income	0	0	0
Canada | Operating Segments
Segment Reporting Information [Line Items]
Consolidated capital expenditures and investments	530	203	651
Interest income	0	0	0
Europe, Middle East and North Africa | Operating Segments
Segment Reporting Information [Line Items]
Consolidated capital expenditures and investments	998	534	600
Interest income	1	2	5
Asia Pacific | Operating Segments
Segment Reporting Information [Line Items]
Consolidated capital expenditures and investments	1,880	390	384
Interest income	9	9	7
Other International | Operating Segments
Segment Reporting Information [Line Items]
Consolidated capital expenditures and investments	0	33	121
Interest income	$ 0	$ 0	$ 0

Segment Disclosures and Relat_8

Segment Disclosures and Related Information - Sales and Other Operating Revenues by Product (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	$ 78,494	$ 45,828	$ 18,784
Natural gas
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	26,941	16,904	6,427
Natural gas liquids
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	3,650	1,668	528
Crude oil
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	41,492	23,648	9,736
Other
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	$ 6,411	$ 3,608	$ 2,093

Segment Disclosures and Relat_9

Segment Disclosures and Related Information - Geographic Information (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2022	Dec. 31, 2021	Dec. 31, 2020
Segment Reporting Information [Line Items]
Sales and other operating revenues	$ 78,494	$ 45,828	$ 18,784
Long-Lived Assets	72,359	71,612	47,603
United States
Segment Reporting Information [Line Items]
Sales and other operating revenues	60,899	34,847	13,230
Long-Lived Assets	51,200	50,580	24,034
Australia and Timor-Leste
Segment Reporting Information [Line Items]
Sales and other operating revenues	0	0	605
Long-Lived Assets	6,158	5,579	6,676
Canada
Segment Reporting Information [Line Items]
Sales and other operating revenues	3,714	2,494	1,261
Long-Lived Assets	6,269	6,608	6,385
China
Segment Reporting Information [Line Items]
Sales and other operating revenues	1,135	724	460
Long-Lived Assets	1,538	1,476	1,491
Indonesia
Segment Reporting Information [Line Items]
Sales and other operating revenues	159	879	689
Long-Lived Assets	0	28	464
Libya
Segment Reporting Information [Line Items]
Sales and other operating revenues	1,582	1,102	155
Long-Lived Assets	714	659	670
Malaysia
Segment Reporting Information [Line Items]
Sales and other operating revenues	1,312	975	610
Long-Lived Assets	1,107	1,252	1,501
Norway
Segment Reporting Information [Line Items]
Sales and other operating revenues	3,415	2,563	1,426
Long-Lived Assets	4,369	4,681	5,294
United Kingdom
Segment Reporting Information [Line Items]
Sales and other operating revenues	6,273	2,236	336
Long-Lived Assets	1	1	1
Other foreign countries
Segment Reporting Information [Line Items]
Sales and other operating revenues	5	8	12
Long-Lived Assets	$ 1,003	$ 748	$ 1,087