10-Q

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

FORM 10-Q

(Mark One)

☒ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended June 30, 2022

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from ___________________ to ___________________

Commission file number: 001-32395

ConocoPhillips

(Exact name of registrant as specified in its charter)

Delaware	01-0562944
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)

925 N. Eldridge Parkway, Houston, TX 77079

(Address of principal executive offices) (Zip Code)

281-293-1000

(Registrant's telephone number, including area code)

Securities registered pursuant to Section 12(b) of the Act:

Title of each class	Trading symbols	Name of each exchange on which registered
Common Stock, $.01 Par Value	COP	New York Stock Exchange
7% Debentures due 2029	CUSIP—718507BK1	New York Stock Exchange

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days. Yes ☒ No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (§232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files). Yes ☒ No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company” and “emerging growth company” in Rule 12b-2 of the Exchange Act.

Large accelerated filer ☒        Accelerated filer ☐        Non-accelerated filer ☐        Smaller reporting company ☐

Emerging growth company ☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act). Yes ☐ No ☒

The registrant had 1,273,033,365 shares of common stock, $.01 par value, outstanding at June 30, 2022.

Table of Contents

	Page
Commonly Used Abbreviations	1
Part I—Financial Information
Item 1. Financial Statements
Consolidated Income Statement	2
Consolidated Statement of Comprehensive Income	3
Consolidated Balance Sheet	4
Consolidated Statement of Cash Flows	5
Notes to Consolidated Financial Statements	6
Item 2. Management’s Discussion and Analysis of Financial Condition and Results of Operations	31
Item 3. Quantitative and Qualitative Disclosures About Market Risk	55
Item 4. Controls and Procedures	55
Part II—Other Information
Item 1. Legal Proceedings	55
Item 1A. Risk Factors	55
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	56
Item 6. Exhibits	57
Signature	58

Commonly Used Abbreviations Table of Contents

Commonly Used Abbreviations

The following industry-specific, accounting and other terms, and abbreviations may be commonly used in this report.

Currencies		Accounting
$ or USD	U.S. dollar	ARO	asset retirement obligation
CAD	Canadian dollar	ASC	accounting standards codification
EUR	Euro	ASU	accounting standards update
GBP	British pound	DD&A	depreciation, depletion and amortization
Units of Measurement		FASB	Financial Accounting Standards Board
BBL	barrel
BCF	billion cubic feet	FIFO	first-in, first-out
BOE	barrels of oil equivalent	G&A	general and administrative
MBD	thousands of barrels per day	GAAP	generally accepted accounting principles
MCF	thousand cubic feet
MBOD	thousand barrels of oil per day	LIFO	last-in, first-out
MM	million	NPNS	normal purchase normal sale
MMBOE	million barrels of oil equivalent	PP&E	properties, plants and equipment
MMBOD	million barrels of oil per day	VIE	variable interest entity
MBOED	thousands of barrels of oil equivalent per day
MMBOED	millions of barrels of oil equivalent per day	Miscellaneous
MMBTU	million British thermal units	DE&I	diversity, equity and inclusion
MMCFD	million cubic feet per day	EPA	Environmental Protection Agency
		ESG	Environmental, Social and Corporate Governance
Industry		EU	European Union
BLM	Bureau of Land Management	FERC	Federal Energy Regulatory Commission
CBM	coalbed methane
CCUS	carbon capture utilization and	GHG	greenhouse gas
	storage	HSE	health, safety and environment
E&P	exploration and production	ICC	International Chamber of Commerce
FEED	front-end engineering and design	ICSID	World Bank’s International
FPS	floating production system		Centre for Settlement of
FPSO	floating production, storage and		Investment Disputes
	offloading	IRS	Internal Revenue Service
G&G	geological and geophysical	OTC	over-the-counter
JOA	joint operating agreement	NYSE	New York Stock Exchange
LNG	liquefied natural gas	SEC	U.S. Securities and Exchange
NGLs	natural gas liquids		Commission
OPEC	Organization of Petroleum	TSR	total shareholder return
	Exporting Countries	U.K.	United Kingdom
PSC	production sharing contract	U.S.	United States of America
PUDs	proved undeveloped reserves	VROC	variable return of cash
SAGD	steam-assisted gravity drainage
WCS	Western Canada Select
WTI	West Texas Intermediate

1 ConocoPhillips      2022 Q2 10-Q

Financial Statements Table of Contents

PART I. Financial Information

Item 1.    Financial Statements

Consolidated Income Statement ConocoPhillips

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenues and Other Income
Sales and other operating revenues	$	21,161	9,556	38,923	19,382
Equity in earnings of affiliates	524		139	950	261
Gain on dispositions	262		59	1,079	292
Other income	42		457	328	835
Total Revenues and Other Income	21,989		10,211	41,280	20,770
Costs and Expenses
Purchased commodities	9,234		2,998	15,985	7,481
Production and operating expenses	1,741		1,379	3,322	2,762
Selling, general and administrative expenses	96		117	283	428
Exploration expenses	143		57	212	141
Depreciation, depletion and amortization	1,810		1,867	3,633	3,753
Impairments	2		2	4	(1)
Taxes other than income taxes	1,020		381	1,834	751
Accretion on discounted liabilities	61		63	122	125
Interest and debt expense	211		220	428	446
Foreign currency transaction (gain) loss	(70)		10	(46)	29
Other expenses	86		37	(50)	61
Total Costs and Expenses	14,334		7,131	25,727	15,976
Income before income taxes	7,655		3,080	15,553	4,794
Income tax provision	2,510		989	4,649	1,721
Net Income	$	5,145	2,091	10,904	3,073
Net Income Per Share of Common Stock (dollars)
Basic	$	3.98	1.55	8.39	2.32
Diluted	3.96		1.55	8.36	2.31
Average Common Shares Outstanding (in thousands)
Basic	1,289,791		1,348,637	1,295,827	1,324,639
Diluted	1,295,844		1,353,201	1,301,126	1,329,507

See Notes to Consolidated Financial Statements.

ConocoPhillips      2022 Q2 10-Q 2

Financial Statements Table of Contents

Consolidated Statement of Comprehensive Income ConocoPhillips

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income	$	5,145	2,091	10,904	3,073
Other comprehensive income
Defined benefit plans
Reclassification adjustment for amortization of prior service credit included in net income	(10)		(10)	(20)	(19)
Net change	(10)		(10)	(20)	(19)
Net actuarial gain (loss) arising during the period	(82)		30	(82)	105
Reclassification adjustment for amortization of net actuarial losses included in net income	25		63	41	88
Net change	(57)		93	(41)	193
Income taxes on defined benefit plans	14		(19)	12	(40)
Defined benefit plans, net of tax	(53)		64	(49)	134
Unrealized holding loss on securities	(5)		—	(9)	(1)
Income taxes on unrealized holding loss on securities	1		—	2	—
Unrealized holding loss on securities, net of tax	(4)		—	(7)	(1)
Foreign currency translation adjustments	(448)		96	(307)	165
Foreign currency translation adjustments, net of tax	(448)		96	(307)	165
Other Comprehensive Income (Loss), Net of Tax	(505)		160	(363)	298
Comprehensive Income	$	4,640	2,251	10,541	3,371

See Notes to Consolidated Financial Statements.

3 ConocoPhillips      2022 Q2 10-Q

Financial Statements Table of Contents

Consolidated Balance Sheet ConocoPhillips

	Millions of Dollars
	June 30 2022		December 31 2021
Assets
Cash and cash equivalents	$	6,909	5,028
Short-term investments	1,272		446
Accounts and notes receivable (net of allowance of $2 and $2, respectively)	8,081		6,543
Accounts and notes receivable—related parties	72		127
Investment in Cenovus Energy	—		1,117
Inventories	1,234		1,208
Prepaid expenses and other current assets	1,292		1,581
Total Current Assets	18,860		16,050
Investments and long-term receivables	8,203		7,113
Net properties, plants and equipment (net of accumulated DD&A of $65,212 and $64,735, respectively)	64,008		64,911
Other assets	2,622		2,587
Total Assets	$	93,693	90,661
Liabilities
Accounts payable	$	5,845	5,002
Accounts payable—related parties	28		23
Short-term debt	676		1,200
Accrued income and other taxes	2,759		2,862
Employee benefit obligations	529		755
Other accruals	2,379		2,179
Total Current Liabilities	12,216		12,021
Long-term debt	16,295		18,734
Asset retirement obligations and accrued environmental costs	5,737		5,754
Deferred income taxes	6,694		6,179
Employee benefit obligations	1,080		1,153
Other liabilities and deferred credits	1,469		1,414
Total Liabilities	43,491		45,255
Equity
Common stock (2,500,000,000 shares authorized at $0.01 par value)
Issued (2022—2,100,027,414 shares; 2021—2,091,562,747 shares)
Par value	21		21
Capital in excess of par	61,045		60,581
Treasury stock (at cost: 2022—826,994,049 shares; 2021—789,319,875 shares)	(54,644)		(50,920)
Accumulated other comprehensive loss	(5,313)		(4,950)
Retained earnings	49,093		40,674
Total Equity	50,202		45,406
Total Liabilities and Equity	$	93,693	90,661

See Notes to Consolidated Financial Statements.

ConocoPhillips      2022 Q2 10-Q 4

Financial Statements Table of Contents

Consolidated Statement of Cash Flows ConocoPhillips

	Millions of Dollars
	Six Months Ended June 30
	2022		2021
Cash Flows From Operating Activities
Net income	$	10,904	3,073
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	3,633		3,753
Impairments	4		(1)
Dry hole costs and leasehold impairments	104		7
Accretion on discounted liabilities	122		125
Deferred taxes	868		567
Undistributed equity earnings	591		317
Gain on dispositions	(1,079)		(292)
Gain on investment in Cenovus Energy	(251)		(726)
Other	(37)		(688)
Working capital adjustments
Increase in accounts and notes receivable	(1,861)		(794)
Increase in inventories	(53)		(89)
Increase in prepaid expenses and other current assets	(283)		(388)
Increase in accounts payable	635		323
Increase (decrease) in taxes and other accruals	(315)		1,144
Net Cash Provided by Operating Activities	12,982		6,331
Cash Flows From Investing Activities
Capital expenditures and investments	(5,129)		(2,465)
Working capital changes associated with investing activities	496		2
Acquisition of businesses, net of cash acquired	37		382
Proceeds from asset dispositions	2,951		160
Net (purchase) sale of investments	(1,104)		1,302
Collection of advances/loans—related parties	55		52
Other	(8)		86
Net Cash Used in Investing Activities	(2,702)		(481)
Cash Flows From Financing Activities
Issuance of debt	2,897		—
Repayment of debt	(5,829)		(44)
Issuance of company common stock	350		(25)
Repurchase of company common stock	(3,725)		(981)
Dividends paid	(1,852)		(1,171)
Other	(56)		3
Net Cash Used in Financing Activities	(8,215)		(2,218)
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash	(237)		9
Net Change in Cash, Cash Equivalents and Restricted Cash	1,828		3,641
Cash, cash equivalents and restricted cash at beginning of period	5,398		3,315
Cash, Cash Equivalents and Restricted Cash at End of Period	$	7,226	6,956

Restricted cash of $317 million is included in the "Other assets" line of our Consolidated Balance Sheet as of June 30, 2022.

Restricted cash of $152 million and $218 million are included in the "Prepaid expenses and other current assets" and "Other assets" lines, respectively, of our Consolidated Balance Sheet as of December 31, 2021.

See Notes to Consolidated Financial Statements.

5 ConocoPhillips      2022 Q2 10-Q

Notes to Consolidated Financial Statements Table of Contents

Notes to Consolidated Financial Statements

Note 1—Basis of Presentation

The interim-period financial information presented in the financial statements included in this report is unaudited and, in the opinion of management, includes all known accruals and adjustments necessary for a fair presentation of the consolidated financial position of ConocoPhillips, its results of operations and cash flows for such periods. All such adjustments are of a normal and recurring nature unless otherwise disclosed. Certain notes and other information have been condensed or omitted from the interim financial statements included in this report. Therefore, these financial statements should be read in conjunction with the consolidated financial statements and notes included in our 2021 Annual Report on Form 10-K.

Note 2—Inventories

	Millions of Dollars
	June 30 2022		December 31 2021
Crude oil and natural gas	$	653	647
Materials and supplies	581		561
Total Inventories	$	1,234	1,208
Inventories valued on the LIFO basis	$	326	395

Note 3—Acquisitions and Dispositions

Acquisition of Shell Enterprise LLC's (Shell) Permian Assets

In December 2021, we completed our acquisition of Shell's assets in the Permian based Delaware Basin in an all-cash transaction for $8.6 billion after customary adjustments. Assets acquired include approximately 225,000 net acres and producing properties located entirely in Texas. The acquisition was accounted for as a business combination 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.

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.

ConocoPhillips      2022 Q2 10-Q 6

Notes to Consolidated Financial Statements Table of Contents

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.

Supplemental Pro Forma (unaudited)

The following table summarizes the unaudited supplemental pro forma financial information for the three- and six-month periods ended June 30, 2021, as if we had completed the acquisition of Shell's Permian assets on January 1, 2020:

	Millions of Dollars
	Three Months Ended June 30, 2021				Six Months Ended June 30, 2021
Supplemental Pro Forma (unaudited)	As Reported		Pro forma Shell	Pro forma Combined	As Reported	Pro forma Shell	Pro forma Combined
Total Revenues and Other Income	10,211		799	11,010	20,770	1,395	22,165
Income before income taxes	3,080		297	3,377	4,794	416	5,210
Net Income	2,091		227	2,318	3,073	318	3,391
Earnings per share ($ per share):
Basic net income	$	1.55		1.71	2.32		2.56
Diluted net income	1.55			1.71	2.31		2.55

The unaudited supplemental pro forma financial information is presented for illustration and comparative purposes only and is not necessarily indicative of the operating results that would have occurred had the transaction 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 three- and six-month periods ended June 30, 2021, is a result of combining the consolidated income statement of ConocoPhillips with the results of 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 transaction. The pro forma results include adjustments made 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.

7 ConocoPhillips      2022 Q2 10-Q

Notes to Consolidated Financial Statements Table of Contents

Acquisition of Concho Resources Inc. (Concho)

In January 2021, we completed our acquisition of Concho, an independent oil and gas exploration and production company in an all-stock transaction. In conjunction with this acquisition, we commenced, and completed in 2021, a company-wide restructuring program, the scope of which included combining the operations of the two companies as well as other global restructuring activities for which we recognized non-recurring restructuring and transaction costs. Further information regarding the Concho acquisition can be found in the following footnotes: Note 7—Changes in Equity; Note 9—Contingencies and Commitments; Note 10—Derivative and Financial Instruments; and Note 13—Cash Flow Information and should be read in conjunction with the notes included in our Annual Report on Form 10-K.

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 increases our ownership in APLNG to 47.5 percent, with Origin Energy and Sinopec owning

27.5 percent and 25 percent, respectively. APLNG is reported as an equity investment in our Asia Pacific segment.

Assets Sold

In April 2022, we sold our interests in certain noncore assets in the Lower 48 segment for net proceeds of $370 million and recognized a $80 million before-tax and $63 million after-tax gain. At the time of disposition, our interests in these assets had a net carrying value of $290 million, consisting primarily of $401 million of PP&E and $111 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 $264 million for the six-month period ended June 30, 2022 and 2021, respectively. Results of operations for the Indonesia interests sold were reported in our Asia Pacific segment.

For the three- and six-months ended June 30, 2022, we recorded contingent payments of $174 million and $424 million, respectively, relating to the previous dispositions of our interest in the Foster Creek Christina Lake Partnership and western Canada gas assets as well as our San Juan assets. The contingent payments are recorded as gain on disposition in our consolidated income statement and are reflected within our Canada and Lower 48 segments. For the three- and six-months ended June 30, 2021, we recorded contingent payments of $68 million and $94 million, respectively.

Planned Dispositions

In July 2022, we entered into agreements to sell our interests in certain noncore assets in the Lower 48 segment for $265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022.

ConocoPhillips      2022 Q2 10-Q 8

Notes to Consolidated Financial Statements Table of Contents

Note 4—Investments, Loans and Long-Term Receivables

APLNG

APLNG executed project agreements for an $8.5 billion project finance facility in 2012 which became non-recourse following financial completion in 2017. Following restructuring efforts, 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 June 30, 2022, a balance of $5.5 billion was outstanding on these facilities.

See Note 8.

In February 2022, we completed the acquisition of an additional 10 percent interest in APLNG from Origin Energy for approximately $1.4 billion resulting from the exercise of our preemption right. This increases our ownership in APLNG to 47.5 percent, with Origin Energy and Sinopec owning 27.5 percent and 25 percent, respectively.

At June 30, 2022, the carrying value of our equity method investment in APLNG was $6.4 billion. The balance is included in the “Investments and long-term receivables” line on our consolidated balance sheet.

Loans

As part of our normal ongoing business operations, we enter into numerous agreements with other parties to pursue business opportunities. Included in such activity are loans made to certain affiliated and non-affiliated companies. At June 30, 2022, significant loans to affiliated companies included $59 million in project financing to Qatar Liquefied Gas Company Limited (3), which is included within the “Accounts and notes receivable—related parties” line on our consolidated balance sheet.

Note 5—Investment in Cenovus Energy

At December 31, 2021, we held 91 million common shares of Cenovus Energy (CVE), which approximated 4.5% of their issued and outstanding common shares. 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” 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 11.

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022		2021
Total Net gain on equity securities	$	—	418	251		726
Less: Net gain on equity securities sold during the period	—		31	251		60
Unrealized gain on equity securities still held at the reporting date	$	—	387	$	—	666

9 ConocoPhillips      2022 Q2 10-Q

Notes to Consolidated Financial Statements Table of Contents

Note 6—Debt

	Millions of Dollars
	June 30 2022		December 31 2021
2.4% Notes due 2022	$	329	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
2.4% 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% 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	645		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% – 1.09% during 2022 and 0.04% – 0.15% during 2021	265		265
Industrial Development Bonds due 2035 at 0.07% – 1.09% during 2022 and 0.04% – 0.12% during 2021	18		18
Other	33		35
Debt at face value	16,208		17,766
Finance leases	1,284		1,261
Net unamortized premiums, discounts and debt issuance costs	(521)		907
Total debt	16,971		19,934
Short-term debt	(676)		(1,200)
Long-term debt	$	16,295	18,734

ConocoPhillips      2022 Q2 10-Q 10

Notes to Consolidated Financial Statements Table of Contents

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% 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

On March 8, 2022, we issued the following new notes consisting of:

•2.125% Notes due 2024 with principal of $900 million

•2.4% Notes due 2025 with principal of $900 million

•3.8% Notes 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.

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Notes to Consolidated Financial Statements Table of Contents

Credit facility borrowings may bear interest at a margin above rates offered by certain designated banks in the London interbank market or at a margin above the overnight federal funds rate or prime rates offered by certain designated banks in the U.S. The 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 June 30, 2022. At December 31, 2021, we had no commercial paper outstanding and no direct borrowings or letters of credit issued.

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: “A3” with a “positive” 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 June 30, 2022, 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.

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Notes to Consolidated Financial Statements Table of Contents

Note 7—Changes in Equity

	Millions of Dollars
	Common Stock
	Par Value		Capital in Excess of Par	Treasury Stock	Accum. Other Comprehensive Income (Loss)	Retained Earnings	Total
For the three months ended June 30, 2022
Balances at March 31, 2022	$	21	60,907	(52,344)	(4,808)	45,442	49,218
Net income						5,145	5,145
Other comprehensive income					(505)		(505)
Dividends declared
Ordinary ($0.46 per common share)						(598)	(598)
Variable return of cash ($0.70 per common share)						(896)	(896)
Repurchase of company common stock				(2,300)			(2,300)
Distributed under benefit plans			138				138
Other							—
Balances at June 30, 2022	$	21	61,045	(54,644)	(5,313)	49,093	50,202
For the six months ended June 30, 2022
Balances at December 31, 2021	$	21	60,581	(50,920)	(4,950)	40,674	45,406
Net income						10,904	10,904
Other comprehensive income					(363)		(363)
Dividends declared
Ordinary ($0.92 per common share)						(1,201)	(1,201)
Variable return of cash ($1.00 per common share)						(1,286)	(1,286)
Repurchase of company common stock				(3,725)			(3,725)
Distributed under benefit plans			464				464
Other				1		2	3
Balances at June 30, 2022	$	21	61,045	(54,644)	(5,313)	49,093	50,202

	Millions of Dollars
	Common Stock
	Par Value		Capital in Excess of Par	Treasury Stock	Accum. Other Comprehensive Income (Loss)	Retained Earnings	Total
For the three months ended June 30, 2021
Balances at March 31, 2021	$	21	60,278	(47,672)	(5,080)	35,608	43,155
Net income						2,091	2,091
Other comprehensive income					160		160
Dividends declared
Ordinary ($0.43 per common share)						(583)	(583)
Repurchase of company common stock				(606)			(606)
Distributed under benefit plans			59				59
Balances at June 30, 2021	$	21	60,337	(48,278)	(4,920)	37,116	44,276
For the six months ended June 30, 2021
Balances at December 31, 2020	$	18	47,133	(47,297)	(5,218)	35,213	29,849
Net income						3,073	3,073
Other comprehensive loss					298		298
Dividends declared
Ordinary ($0.86 per common share)						(1,171)	(1,171)
Acquisition of Concho	3		13,122				13,125
Repurchase of company common stock				(981)			(981)
Distributed under benefit plans			82				82
Other						1	1
Balances at June 30, 2021	$	21	60,337	(48,278)	(4,920)	37,116	44,276

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Notes to Consolidated Financial Statements Table of Contents

Note 8—Guarantees

At June 30, 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 June 30, 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 June 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 is 9 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 June 30, 2022, the carrying value of this guarantee was $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 $820 million ($1.4 billion in the event of intentional or reckless breach) and would become payable if APLNG fails to meet its obligations under these agreements and the obligations cannot otherwise be mitigated. Future payments are considered unlikely, as the payments, or cost of volume delivery, would only be triggered if APLNG does not have enough natural gas to meet these sales commitments and if the co-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 15 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 June 30, 2022, the carrying value of these guarantees was approximately $20 million.

Other Guarantees

We have other guarantees with maximum future potential payment amounts totaling approximately $720 million, which consist primarily of guarantees of the residual value of leased office buildings, guarantees of the residual value of corporate aircrafts, and a guarantee for our portion of a joint venture’s project finance reserve accounts. These guarantees have remaining terms of one to five years and would become payable if certain asset values are lower than guaranteed amounts at the end of the lease or contract term, business conditions decline at guaranteed entities, or as a result of nonperformance of contractual terms by guaranteed parties. At June 30, 2022, the carrying value of these guarantees was $8 million.

Indemnifications

Over the years, we have entered into agreements to sell ownership interests in certain legal entities, joint ventures and assets that gave rise to qualifying indemnifications. These agreements include indemnifications for taxes and environmental liabilities. The carrying amount recorded for these indemnification obligations at June 30, 2022, was

$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 9 for additional information about environmental liabilities.

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Notes to Consolidated Financial Statements Table of Contents

Note 9—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.

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.

At June 30, 2022, our balance sheet included a total environmental accrual of $178 million, compared with $187 million at December 31, 2021, for remediation activities in the U.S. and Canada. We expect to incur a substantial amount of these expenditures within the next 30 years. In the future, we may be involved in additional environmental assessments, cleanups and proceedings.

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Notes to Consolidated Financial Statements Table of Contents

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 June 30, 2022, we had performance obligations secured by letters of credit of $320 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.

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 $771 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.

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Notes to Consolidated Financial Statements Table of Contents

Beginning in 2017, governmental and other entities in several states in the U.S. have filed lawsuits against oil and gas companies, including ConocoPhillips, seeking compensatory damages and equitable relief to abate alleged climate change impacts. Additional lawsuits with similar allegations are expected to be filed. The amounts claimed by plaintiffs are unspecified and the legal and factual issues 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. 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 is challenging the BSEE order but 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 final investment decision 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.

Note 10—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.

17 ConocoPhillips      2022 Q2 10-Q

Notes to Consolidated Financial Statements Table of Contents

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
	June 30 2022		December 31 2021
Assets
Prepaid expenses and other current assets	$	1,790	1,168
Other assets	262		75
Liabilities
Other accruals	1,824		1,160
Other liabilities and deferred credits	232		63

The gains (losses) from commodity derivatives incurred and the line items where they appear on our consolidated income statement were:

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Sales and other operating revenues	$	(13)	(100)	(420)	(379)
Other income	1		(1)	2	16
Purchased commodities	(55)		132	346	145

During the first quarter of 2021, we recognized a $305 million loss on settlement of derivative contracts acquired through the Concho transaction. This loss is recorded within the “Sales and other operating revenues” line on our consolidated income statement. In connection with this settlement, we issued a cash payment of $692 million in the first quarter of 2021 and $69 million in the second quarter of 2021 which are included within “Cash Flows From Operating Activities” on our consolidated statement of cash flows.

The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts:

	Open Position Long (Short)
	June 30 2022	December 31 2021
Commodity
Natural gas and power (billions of cubic feet equivalent)
Fixed price	(14)	4
Basis	(1)	(22)

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Notes to Consolidated Financial Statements Table of Contents

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 June 30, 2022, and December 31, 2021:

	Millions of Dollars
	Carrying Amount
	Cash and Cash Equivalents			Short-Term Investments
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Cash	$	505	670
Demand Deposits	1,690		1,554
Time Deposits
1 to 90 days	4,555		2,363	524	217
91 to 180 days				112	4
Within one year				47	4
One year through five years
U.S. Government Obligations
1 to 90 days	39		431	—	—
	$	6,789	5,018	683	225

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The following investments in debt securities classified as available for sale are carried at fair value on our consolidated balance sheet at June 30, 2022 and December 31, 2021:

	Millions of Dollars
	Carrying Amount
	Cash and Cash Equivalents			Short-Term Investments		Investments and Long-Term Receivables
	June 30 2022		December 31 2021	June 30 2022	December 31 2021	June 30 2022	December 31 2021
Major Security Type
Corporate Bonds	$	—	3	299	128	298	173
Commercial Paper	120		7	215	82
U.S. Government Obligations	—		—	68	—	94	2
U.S. Government Agency Obligations				5	2	5	8
Foreign Government Obligations				2	7	4	2
Asset-backed Securities				—	2	100	63
	$	120	10	589	221	501	248

Cash and Cash Equivalents and Short-Term Investments have remaining maturities within one year.

Investments and Long-Term Receivables have remaining maturities greater than one year through seven years.

The following table summarizes the amortized cost basis and fair value of investments in debt securities classified as available for sale:

	Millions of Dollars
	Amortized Cost Basis			Fair Value
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Major Security Type
Corporate Bonds	$	604	305	597	304
Commercial Paper	335		88	335	89
U.S. Government Obligations	163		2	162	2
U.S. Government Agency Obligations	10		10	10	10
Foreign Government Obligations	6		9	6	9
Asset-backed Securities	100		65	100	65
	$	1,218	479	1,210	479

As of June 30, 2022 and December 31, 2021, total unrealized losses for debt securities classified as available for sale with net losses were negligible. Additionally, as of June 30, 2022 and December 31, 2021, investments in these debt securities in an unrealized loss position for which an allowance for credit losses has not been recorded were negligible.

For the three- and six-month periods ended June 30, 2022, proceeds from sales and redemptions of investments in debt securities classified as available for sale were $86 million and $201 million, respectively. For the three- and six-month periods ended June 30, 2021, proceeds from sales and redemptions of investments in debt securities classified as available for sale were $173 million and $320 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.

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Notes to Consolidated Financial Statements Table of Contents

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, and foreign government obligations.

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 oil and gas 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.

The aggregate fair value of all derivative instruments with such credit risk-related contingent features that were in a liability position at June 30, 2022 and December 31, 2021 was $326 million and $281 million, respectively. For these instruments, collateral posted at June 30, 2022 was $6 million and no collateral was posted at December 31, 2021. If our credit rating had been downgraded below investment grade at June 30, 2022, we would have been required to post

$238 million of additional collateral, either with cash or letters of credit.

Note 11—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 the six-month period ended June 30, 2022, nor during the year ended December 31, 2021.

21 ConocoPhillips      2022 Q2 10-Q

Notes to Consolidated Financial Statements Table of Contents

Recurring Fair Value Measurement

Financial assets and liabilities reported at fair value on a recurring basis includes 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
	June 30, 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	162		1,048	—	1,210	2	477	—	479
Commodity derivatives	957		1,037	58	2,052	562	619	62	1,243
Total assets	$	1,119	2,085	58	3,262	1,681	1,096	62	2,839
Liabilities
Commodity derivatives	$	1,004	867	185	2,056	593	543	87	1,223
Total liabilities	$	1,004	867	185	2,056	593	543	87	1,223

ConocoPhillips      2022 Q2 10-Q 22

Notes to Consolidated Financial Statements Table of Contents

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 Recognized		Amounts Not Subject to Right of Setoff	Gross Amounts	Gross Amounts Offset	Net Amounts Presented	Cash Collateral	Net Amounts
June 30, 2022
Assets	$	2,052	27	2,025	1,302	723	—	723
Liabilities	2,056		16	2,040	1,302	738	48	690
December 31, 2021
Assets	$	1,243	85	1,158	650	508	—	508
Liabilities	1,223		82	1,141	650	491	36	455

At June 30, 2022 and December 31, 2021, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff.

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 5 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 10.

•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 4.

•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.

23 ConocoPhillips      2022 Q2 10-Q

Notes to Consolidated Financial Statements Table of Contents

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
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Financial assets
Investment in CVE common shares	$	—	1,117	—	1,117
Commodity derivatives	750		593	750	593
Investments in debt securities	1,210		479	1,210	479
Loans and advances—related parties	59		114	59	114
Financial liabilities
Total debt, excluding finance leases	15,687		18,673	16,547	22,451
Commodity derivatives	706		537	706	537

Note 12—Accumulated Other Comprehensive Loss

Accumulated other comprehensive loss in the equity section of our consolidated balance sheet includes:

	Millions of Dollars
	Defined Benefit Plans		Net Unrealized Loss on Securities	Foreign Currency Translation	Accumulated Other Comprehensive Loss
December 31, 2021	$	(31)	—	(4,919)	(4,950)
Other comprehensive loss	(49)		(7)	(307)	(363)
June 30, 2022	$	(80)	(7)	(5,226)	(5,313)

The following table summarizes reclassifications out of accumulated other comprehensive loss and into net income (loss):

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Defined benefit plans	$	12	42	16	54

The above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of $3 million and $11 million for the three-month periods ended June 30, 2022 and June 30, 2021, respectively, and $5 million and $15 million for the six-month periods ended

June 30, 2022 and June 30, 2021, respectively. See Note 14.

ConocoPhillips      2022 Q2 10-Q 24

Notes to Consolidated Financial Statements Table of Contents

Note 13—Cash Flow Information

	Millions of Dollars
	Six Months Ended June 30
Cash Payments	2022		2021
Interest	$	486	464
Income taxes	3,942		107
Net Sales (Purchases) of Investments
Short-term investments purchased	$	(1,253)	(5,439)
Short-term investments sold	613		6,842
Long-term investments purchased	(510)		(149)
Long-term investments sold	46		48
	$	(1,104)	1,302

In the first quarter of 2021, we acquired Concho in an all-stock transaction for $13.1 billion. In connection with this transaction, we acquired cash of $382 million, which is included in "Cash Flows From Investing Activities" on our consolidated statement of cash flows.

Note 14—Employee Benefit Plans

Pension and Postretirement Plans

	Millions of Dollars
	Pension Benefits					Other Benefits
	2022			2021		2022	2021
	U.S.		Int'l.	U.S.	Int'l.
Components of Net Periodic Benefit Cost
Three Months Ended June 30
Service cost	$	16	13	18	16	1	1
Interest cost	12		21	15	20	1	1
Expected return on plan assets	(13)		(34)	(20)	(30)	—	—
Amortization of prior service credit	—		—	—	—	(10)	(10)
Recognized net actuarial loss	5		2	12	8	—	1
Settlements	18		—	42	—	—	—
Net periodic benefit cost	$	38	2	67	14	(8)	(7)
Six Months Ended June 30
Service cost	$	32	26	39	31	1	1
Interest cost	24		42	28	40	2	2
Expected return on plan assets	(26)		(68)	(44)	(60)	—	—
Amortization of prior service credit	—		—	—	—	(20)	(19)
Recognized net actuarial loss	11		4	27	16	—	1
Settlements	22		—	44	—	—	—
Curtailments	—		—	12	—	—	—
Special Termination Benefits	—		—	9	—	—	—
Net periodic benefit cost	$	63	4	115	27	(17)	(15)

25 ConocoPhillips      2022 Q2 10-Q

Notes to Consolidated Financial Statements Table of Contents

The components of net periodic benefit cost, other than the service cost component, are included in the "Other expenses" line of our consolidated income statement.

During the first six months of 2022, we contributed $44 million to our domestic benefit plans and $77 million to our international benefit plans. We expect our total contributions in 2022 to be approximately $95 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $90 million to our international qualified and nonqualified pension and postretirement benefit plans.

During the three-month period ended June 30, 2022, lump-sum benefit payments exceeded the sum of service and interest costs for the year for the U.S. qualified pension plan and a U.S. nonqualified supplemental retirement plan. As a result, we recognized a proportionate share of prior actuarial losses from other comprehensive income as pension settlement expense of $18 million. In conjunction with the recognition of pension settlement expense, the fair market values of the pension plan assets were updated and the pension benefit obligations of the U.S. qualified pension plan and the U.S. nonqualified supplemental retirement plan were remeasured at June 30, 2022. At the measurement date, the net pension liability increased by $82 million, primarily a result of lower than premised return on assets, partially offset by an increase in the discount rate, resulting in a corresponding decrease to other comprehensive income.

The relevant discount rates are summarized in the following table:

	June 30 2022		December 31 2021
Relevant discount rates
U.S. qualified pension plan	4.85	%	2.85
U.S. nonqualified pension plan	4.70		2.50

Note 15—Related Party Transactions

Our related parties primarily include equity method investments and certain trusts for the benefit of employees.

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
Significant Transactions with Equity Affiliates	2022		2021	2022	2021
Operating revenues and other income	$	21	24	43	40
Purchases	—		3	—	3
Operating expenses and selling, general and administrative expenses	44		63	90	89
Net interest (income) expense*	$	—	—	(1)	(1)

*We paid interest to, or received interest from, various affiliates. See Note 4 for information related to loans to equity affiliates.

ConocoPhillips      2022 Q2 10-Q 26

Notes to Consolidated Financial Statements Table of Contents

Note 16—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
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from contracts with customers	$	16,728	7,753	31,234	14,914
Revenue from contracts outside the scope of ASC Topic 606
Physical contracts meeting the definition of a derivative	4,411		1,754	7,551	4,728
Financial derivative contracts	22		49	138	(260)
Consolidated sales and other operating revenues	$	21,161	9,556	38,923	19,382

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 17—Segment Disclosures and Related Information:

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from Outside the Scope of ASC Topic 606 by Segment
Lower 48	$	3,483	1,345	5,927	3,811
Canada	807		207	1,367	510
Europe, Middle East and North Africa	121		202	257	407
Physical contracts meeting the definition of a derivative	$	4,411	1,754	7,551	4,728

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from Outside the Scope of ASC Topic 606 by Product
Crude oil	$	64	178	283	302
Natural gas	4,254		1,504	7,027	4,231
Other	93		72	241	195
Physical contracts meeting the definition of a derivative	$	4,411	1,754	7,551	4,728

Practical Expedients

Typically, our commodity sales contracts are less than 12 months in duration; however, in certain specific cases they 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.

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Notes to Consolidated Financial Statements Table of Contents

Receivables and Contract Liabilities

Receivables from Contracts with Customers

At June 30, 2022, the “Accounts and notes receivable” line on our consolidated balance sheet includes trade receivables of $6,554 million compared with $5,268 million at December 31, 2021, and includes 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 to 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.

	Millions of Dollars
Contract Liabilities
At December 31, 2021	$	50
Contractual payments received	25
Revenue recognized	(56)
At June 30, 2022	$	19
Amounts Recognized in the Consolidated Balance Sheet at June 30, 2022
Noncurrent liabilities	$	19

For the six-month period ended June 30, 2022, we recognized revenue of $56 million in the "Sales and other operating revenues" line on our consolidated income statement. No revenue was recognized during the three-month period ended June 30, 2022. We expect to recognize the contract liabilities as of June 30, 2022, as revenue during 2026.

Note 17—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 income and expense; premiums on early retirement of debt; corporate overhead and certain technology activities, including licensing revenues; and unrealized holding gains or losses on equity securities. Corporate assets include all cash and cash equivalents and short-term investments.

We evaluate performance and allocate resources based on net income (loss). Intersegment sales are at prices that approximate market.

ConocoPhillips      2022 Q2 10-Q 28

Notes to Consolidated Financial Statements Table of Contents

Analysis of Results by Operating Segment

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Sales and Other Operating Revenues
Alaska	$	2,349	1,418	4,267	2,551
Lower 48	14,458		5,889	26,015	12,402
Intersegment eliminations	(6)		(2)	(13)	(4)
Lower 48	14,452		5,887	26,002	12,398
Canada	1,794		802	3,314	1,669
Intersegment eliminations	(726)		(352)	(1,377)	(657)
Canada	1,068		450	1,937	1,012
Europe, Middle East and North Africa	2,652		1,165	5,241	2,143
Asia Pacific	638		630	1,388	1,207
Other International	—		2	—	3
Corporate and Other	2		4	88	68
Consolidated sales and other operating revenues	$	21,161	9,556	38,923	19,382
Sales and Other Operating Revenues by Geographic Location(1)
United States	$	16,802	7,308	30,355	15,015
Canada	1,069		450	1,938	1,012
China	301		171	574	326
Indonesia	—		207	159	403
Libya	351		290	782	520
Malaysia	336		252	654	478
Norway	737		618	1,669	1,030
United Kingdom	1,564		257	2,790	593
Other foreign countries	1		3	2	5
Worldwide consolidated	$	21,161	9,556	38,923	19,382
Sales and Other Operating Revenues by Product
Crude oil	$	11,494	5,797	21,364	10,292
Natural gas	7,267		2,812	13,265	7,323
Natural gas liquids	1,042		325	1,921	562
Other(2)	1,358		622	2,373	1,205
Consolidated sales and other operating revenues by product	$	21,161	9,556	38,923	19,382

(1)Sales and other operating revenues are attributable to countries based on the location of the selling operation.

(2)Includes LNG and bitumen.

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income (Loss)
Alaska	$	687	371	1,271	530
Lower 48	3,581		1,175	6,371	1,643
Canada	316		102	607	112
Europe, Middle East and North Africa	385		207	797	360
Asia Pacific	525		175	1,661	492
Other International	—		(5)	—	(9)
Corporate and Other	(349)		66	197	(55)
Consolidated net income	$	5,145	2,091	10,904	3,073

29 ConocoPhillips      2022 Q2 10-Q

Notes to Consolidated Financial Statements Table of Contents

	Millions of Dollars
	June 30 2022		December 31 2021
Total Assets
Alaska	$	14,835	14,812
Lower 48	43,478		41,699
Canada	7,358		7,439
Europe, Middle East and North Africa	8,406		9,125
Asia Pacific	9,997		9,840
Other International	4		1
Corporate and Other	9,615		7,745
Consolidated total assets	$	93,693	90,661

Note 18—Income Taxes

Our effective tax rate for the three-month periods ended June 30, 2022 and 2021 was 32.8 percent and 32.1 percent, respectively, and our effective tax rate for the six-month periods ended June 30, 2022 and 2021 was 29.9 percent and 35.9 percent, respectively. Our effective tax rate for the first six-months of 2022 was impacted by the shift of income among our taxing jurisdictions, the release of tax reserves related to the closing of an IRS audit, a change to our valuation allowance, and the impact of the interest deduction related to our debt exchange, as described below.

In the first quarter of 2022, the IRS closed the 2017 audit of our U.S. 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.

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 quarter to reflect changes to our ability to realize certain deferred tax assets under the new law.

For the three- and six-month periods of 2022, our valuation allowance increased by $58 million and $5 million, respectively, compared to a decrease of $87 million and $151 million for the same periods of 2021. The increase in the three- and six-month periods of 2022 relate to the Norway tax law change described above. In addition, our six-month periods of 2022 and of 2021 include impacts from changes in our valuation allowance related to the fair value measurement of our CVE common shares and our expectation of the tax impact related to incremental capital gains and losses.

Our 2022 and 2021 effective tax rates were adversely impacted by $37 million and $75 million, respectively, due to incremental interest deductions from debt exchanges in both periods offsetting U.S. foreign source revenue that would otherwise have been offset by foreign tax credits. See Note 6.

The Company has ongoing income tax audits in a number of jurisdictions. The government agents in charge of these audits regularly request additional time to complete audits, which we generally grant, and conversely occasionally close audits unpredictably. Within the next twelve months we may have audit periods close that could significantly impact our total unrecognized tax benefits. The amount of such change is not estimable but could be significant when compared with our total unrecognized tax benefits.

ConocoPhillips      2022 Q2 10-Q 30

Management’s Discussion and Analysis Table of Contents

Item 2.    Management’s Discussion and Analysis of Financial Condition and Results of Operations

Management’s Discussion and Analysis is the company’s analysis of its financial performance and of significant trends that may affect future performance. It should be read in conjunction with the financial statements and notes. It contains forward-looking statements including, without limitation, statements relating to the company’s plans, strategies, objectives, expectations and intentions that are made pursuant to the “safe harbor” provisions of the Private Securities Litigation Reform Act of 1995. The words “anticipate,” “believe,” “budget,” “continue,” “could,” “effort,” “estimate,” “expect,” “forecast,” “goal,” “guidance,” “intend,” “may,” “objective,” “outlook,” “plan,” “potential,” “predict,” “projection,” “seek,” “should,” “target,” “will,” “would” and similar expressions identify forward-looking statements. The company does not undertake to update, revise or correct any of the forward-looking information unless required to do so under the federal securities laws. Readers are cautioned that such forward-looking statements should be read in conjunction with the company’s disclosures under the heading: “CAUTIONARY STATEMENT FOR THE PURPOSES OF THE ‘SAFE HARBOR’ PROVISIONS OF THE PRIVATE SECURITIES LITIGATION REFORM ACT OF 1995,” beginning on page 53.

The terms “earnings” and “loss” as used in Management’s Discussion and Analysis refer to net income (loss).

Business Environment and Executive Overview

ConocoPhillips is the world’s largest independent E&P company with operations and activities in 13 countries. Our diverse, low cost of supply portfolio includes resource-rich unconventional plays in North America; conventional assets in North America, Europe, and Asia; LNG developments; oil sands in Canada; and an inventory of global conventional and unconventional exploration prospects. Headquartered in Houston, Texas, at June 30, 2022, we employed approximately 9,400 people worldwide and had total assets of $94 billion.

Overview

Commodity prices continued to increase during the second quarter of 2022, in part due to the continued impacts associated with the Russian invasion of Ukraine and sanctions levied against Russia as a result of the conflict. We anticipate that prices will continue to be cyclical and volatile, and our view is that a successful business strategy in the E&P industry must be resilient in lower price environments, while also retaining full upside exposure during periods of higher prices. As such, we are unhedged, remain highly disciplined in our investment decisions and continue to monitor market fundamentals including the impacts associated with the conflict in Ukraine, OPEC plus supply updates, global demand for our products, oil and gas inventory levels, inflation, supply chain disruptions and the fluctuating global COVID-19 impacts.

The macro-environment, including the energy transition, also continues to evolve. We believe ConocoPhillips is playing a valued role in the energy transition. We are guided by our triple mandate that simultaneously calls for us to reliably and responsibly deliver oil and gas production to meet energy transition pathway demand, deliver competitive returns on and of capital, and do so with a resilient and sustainable portfolio enabling us to achieve our net-zero operating emissions ambition. Our triple mandate is supported by financial principles and capital allocation priorities designed to allow us to deliver superior returns through the price cycles. Our financial principles consist of maintaining balance sheet strength, providing peer-leading distributions, making disciplined investments and demonstrating ESG leadership, all of which are in service to generating competitive financial returns through the price cycles.

In the second quarter, total company production was 1,692 MBOED, resulting in cash provided by operating activities of $7.9 billion, with $1 billion returned to shareholders through our ordinary dividend and a VROC and $2.3 billion through share repurchases. We ended the quarter with cash, cash equivalents and short-term investments totaling $8.2 billion.

In May 2022, we announced an increase to our 2022 expected distributions through our three-tier return of capital framework to $10 billion for the year. Additionally, in August we increased our targeted distributions further, to a new total of $15 billion for the year. This framework includes our ordinary dividend, share repurchases and the VROC tier that was introduced last December. In August, we declared our third quarter ordinary dividend of $0.46 per share and a fourth quarter VROC payment of $1.40 per share.

31 ConocoPhillips      2022 Q2 10-Q

Management’s Discussion and Analysis Table of Contents

Demonstrating our commitment to enhance balance sheet strength, in May 2022, we retired $1,250 million principal amount of our 4.95 percent Notes due 2026 and $500 million principal amount of floating rate notes. Both retirements were sourced from available cash. Additionally, in the first quarter we executed a debt refinancing comprised of concurrent transactions including new debt issuances, a cash tender offer and debt exchange offers. In aggregate, these transactions reduced the company's total debt by $3 billion. These activities facilitate our ability to achieve our previously announced $5 billion debt reduction target by the end of 2026, while also reducing the company's annual cash interest expense. See Note 6.

In 2022, we have taken several steps to expand our global LNG business. In the first quarter, we increased our equity share in Asia Pacific LNG (APLNG). In the second quarter, we signed an agreement for a new joint venture with QatarEnergy that will participate with a 12.5 percent interest in the North Field East LNG project. Subject to regulatory approvals, we will hold a 25 percent interest in this joint venture. Domestically, in July 2022, we announced a Heads of Agreement (HOA) with Sempra to potentially acquire a 30 percent direct equity holding in Port Arthur Liquefaction Holdings, LLC and an LNG offtake equivalent to approximately 5 million tonnes per annum from the Port Arthur LNG project. The HOA is a preliminary, non-binding arrangement, with development of the Port Arthur LNG project subject to concluding definitive agreements and resolving a number of risks and uncertainties, including, among others, signing engineering and construction contracts, obtaining financing and reaching a final investment decision between the parties.

As part of our ongoing portfolio high-grading and optimization efforts, in April 2022, we completed the sale of certain noncore assets in the Lower 48 segment for $370 million after customary adjustments. In July 2022, we entered into agreements to sell our interests in additional noncore assets in the Lower 48 segment for $265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022. See Note 3.

Operationally, we remain focused on safely executing the business. Production was 1,692 MBOED in the second quarter of 2022, an increase of 104 MBOED from the same period a year ago. After adjusting for closed acquisitions and dispositions and the conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis, second-quarter 2022 production decreased by 69 MBOED or 4 percent from the same period a year ago. Organic growth from Lower 48 and other development programs more than offset decline; however, production was lower overall primarily due to planned and unplanned downtime.

We re-invested $2 billion into the business in the form of capital expenditures and investments during the second quarter of 2022, with over half of the expenditures focused on flexible, short-cycle unconventional plays in the Lower 48 segment, where our production has access to both domestic and export markets.

In further support of our commitment to ESG leadership and excellence, in July 2022, we announced that ConocoPhillips joined the Oil and Gas Methane Partnership (OGMP) 2.0 initiative. The initiative's mission is to improve industry transparency in methane emissions reporting and encourage progress in reducing those emissions. We believe that applying the rigorous OGMP 2.0 reporting standards across our global assets will be a vital step towards meeting our Paris-aligned climate-risk commitments, including our net-zero ambition for operational emissions by 2050, and will allow us to credibly demonstrate how we are delivering against our methane improvement objectives and targets.

ConocoPhillips      2022 Q2 10-Q 32

Management’s Discussion and Analysis Table of Contents

Business Environment

Commodity prices are the most significant factor impacting our profitability and related returns on and of capital to our shareholders. Dynamics that could influence world energy markets and commodity prices are global economic health, supply or demand disruptions or fears thereof caused by civil unrest, global pandemics, military conflicts, actions taken by OPEC plus and other major oil producing countries, environmental laws, tax regulations, governmental policies and weather-related disruptions. Our strategy is to create value through price cycles by delivering on the financial, operational and ESG priorities that underpin our value proposition.

Our earnings and operating cash flows generally correlate with price levels for crude oil and natural gas, which are subject to factors external to the company and over which we have no control. The following graph depicts the trend in average benchmark prices for WTI crude oil, Brent crude oil and Henry Hub natural gas:

Brent crude oil prices averaged $113.78 per barrel in the second quarter of 2022, an increase of 65 percent compared with $68.83 per barrel in the second quarter of 2021. WTI at Cushing crude oil prices averaged $108.41 per barrel in the second quarter of 2022, an increase of 64 percent compared with $66.07 per barrel in the second quarter of 2021. Oil prices increased as a result of the ongoing global economic recovery following COVID-related impacts as well as supply constraints due to Russia's invasion of Ukraine, OPEC plus adherence to agreed production quotas, other disruptions and supply chain bottlenecks limiting growth.

Henry Hub natural gas prices averaged $7.17 per MMBTU in the second quarter of 2022, an increase of 153 percent compared with $2.83 per MMBTU in the second quarter of 2021. Henry Hub prices have increased due to low inventories, healthy domestic demand and strong exports via pipelines and LNG.

Our realized bitumen price averaged $75.42 per barrel in the second quarter of 2022, an increase of 101 percent compared with $37.60 per barrel in the second quarter of 2021. The increase in the second quarter of 2022 was driven by higher blend prices for Surmont sales, largely attributed to a strengthening of WTI price. We continue to optimize bitumen price realizations through the utilization of downstream transportation solutions and implementation of alternate blend capability which results in lower diluent costs.

For the second quarter of 2022 our total average realized price increased to $88.57 per BOE compared with

$50.03 per BOE in the second quarter of 2021.

33 ConocoPhillips      2022 Q2 10-Q

Management’s Discussion and Analysis Table of Contents

Key Operating and Financial Summary

Significant items during the second quarter of 2022 and recent announcements included the following:

•Announced a $5 billion increase in expected 2022 returns of capital to shareholders to a total of $15 billion.

•Distributed $3.3 billion to shareholders through a three-tier framework, including $1.0 billion in cash through the ordinary dividend and VROC and $2.3 billion through share repurchases.

•Expanded global LNG portfolio through participation in QatarEnergy's North Field East LNG project and announced a non-binding Heads of Agreement with Sempra Infrastructure with opportunities to participate in large-scale LNG projects, an LNG offtake of approximately 5 million tonnes per annum and related carbon capture activities.

•As part of our ongoing commitment to ESG excellence and leadership, we joined the OGMP 2.0 initiative.

•Generated cash provided by operating activities of $7.9 billion.

•Delivered second-quarter production of 1,692 MBOED while successfully completing planned maintenance turnarounds.

•Continued progress toward the company's $5 billion debt reduction target through $1.8 billion of debt retirements during the quarter, now totaling $3 billion since announcing the target.

•Completed $0.4 billion of noncore asset sales during the quarter.

•Ended the quarter with cash, cash equivalents and restricted cash of $7.2 billion and short-term investments of $1.3 billion.

Outlook

Capital and Production

Third-quarter 2022 production is expected to be 1.70 to 1.76 MBOED, reflecting the impacts of seasonal turnarounds planned primarily in Alaska and the Asia Pacific region. Full-year production is expected to be approximately

1.74 MMBOED reflecting uncertainty in Libya and modest updates across the portfolio.

Guidance regarding capital is unchanged.

Depreciation, Depletion and Amortization

Full-year guidance for depreciation, depletion and amortization has decreased to $7.6 billion.

ConocoPhillips      2022 Q2 10-Q 34

Results of Operations Table of Contents

Results of Operations

Unless otherwise indicated, discussion of results for the three- and six-month periods ended June 30, 2022, is based on a comparison with the corresponding period of 2021.

Consolidated Results

A summary of the company's net income (loss) by business segment follows:

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Alaska	$	687	371	1,271	530
Lower 48	3,581		1,175	6,371	1,643
Canada	316		102	607	112
Europe, Middle East and North Africa	385		207	797	360
Asia Pacific	525		175	1,661	492
Other International	—		(5)	—	(9)
Corporate and Other	(349)		66	197	(55)
Net income	$	5,145	2,091	10,904	3,073

Net income in the second quarter of 2022 increased $3,054 million. Second quarter earnings were positively impacted by:

•Higher realized commodity prices.

•Higher sales volumes, primarily due to our Shell Permian acquisition, partly offset by assets divested. See Note 3.

•Higher equity in earnings of affiliates, primarily due to higher LNG sales prices.

•Gain on dispositions primarily due the divestiture of noncore assets in the Lower 48 segment and recognizing higher contingent payments related to prior dispositions in our Canada and Lower 48 segments. See Note 3.

Second quarter 2022 earnings were negatively impacted by:

•Higher production and operating expenses and taxes other than income taxes, primarily due to higher prices and production volumes.

•Higher income tax provision.

•Absence of mark to market gains associated with Cenovus Energy (CVE) shares. See Note 5.

Net income in the six-month period ended June 30, 2022, increased $7,831 million. In addition to the items mentioned above, earnings in the six-month period were positively impacted by:

•Previously unrecognized $515 million tax benefit related to the closing of an IRS audit in the first quarter.

See Note 18.

•Gain on dispositions primarily due to a $462 million after-tax gain related to the divestiture of our Indonesia assets. See Note 3.

•Absence of restructuring and transaction expenses of $243 million after-tax related to our Concho acquisition.

•Absence of realized losses on hedges of $233 million after-tax related to derivative positions acquired in our Concho acquisition. See Note 10.

•Lower DD&A expenses caused by lower rates driven by price-related reserve revisions due to higher commodity prices, partially offset by higher production volumes.

•After-tax gain of $62 million associated with refinancing transactions. See Note 6.

In addition to the items mentioned above, earnings in the six-month period were negatively impacted by:

•Absence of $194 million after-tax gain recognized in conjunction with our Australia-West divestiture. See Note 9.

See the “Segment Results” section for additional information.

35 ConocoPhillips      2022 Q2 10-Q

Results of Operations Table of Contents

Income Statement Analysis

Unless otherwise indicated, all results in Income Statement Analysis are before-tax.

Sales and other operating revenues for the three- and six-month periods of 2022 increased $11,605 million and

$19,541 million, respectively, mainly due to higher realized commodity prices and higher sales volumes.

Equity in earnings of affiliates for the three- and six-month periods of 2022 increased $385 million and $689 million, respectively, primarily due to higher earnings driven by higher LNG and crude prices as well as higher sales volumes inclusive of the additional 10 percent interest in APLNG we acquired in the first quarter of 2022. See Note 3.

Gain on dispositions in the second quarter of 2022 increased due to a gain of $80 million for the sale of noncore assets in the Lower 48 segment. For the six-month period of 2022, we recognized a gain of $534 million from our Indonesia divestiture. For both the three- and six-month periods of 2022, we recognized higher contingent payments associated with previous dispositions in our Canada and Lower 48 segments than the same periods of 2021. Offsetting the increase in gains in the six-month period of 2022 was the absence of a $200 million gain associated with our Australia-West divestiture recognized in the first quarter of 2021. See Note 3.

Other income for the three- and six-month periods of 2022 decreased $415 million and $507 million, respectively, primarily due to the absence of mark to market gains associated with our CVE common shares which were fully divested in the first quarter of 2022. See Note 5.

Purchased commodities for the three- and six-month periods of 2022 increased $6,236 million and $8,504 million, respectively, primarily due to higher gas and crude prices and volumes.

Production and operating expenses for the three- and six-month periods of 2022 increased $362 million and $560 million, respectively, primarily due to higher production volumes.

Selling, general and administrative expenses decreased $145 million in the six-month period primarily due to the absence of transaction and restructuring expenses associated with our Concho acquisition in 2021.

DD&A for the three- and six-month periods of 2022 decreased $57 million and $120 million, respectively, mainly due to lower rates from positive price-related reserve revisions and the absence of DD&A from disposed assets offset by higher overall production volumes primarily associated with our Shell Permian acquisition.

Taxes other than income taxes for the three- and six-month periods of 2022 increased $639 million and $1,083 million, respectively, caused by higher commodity prices and higher production volumes.

Other expenses for the second quarter of 2022 increased $49 million primarily related to premiums paid to repurchase debt. For the six-month period of 2022, other expenses decreased $111 million primarily related to a gain of $127 million associated with extinguishment of debt from the first quarter of 2022. See Note 6.

See Note 18—Income Taxes for information regarding our Income tax provision and effective tax rate.

ConocoPhillips      2022 Q2 10-Q 36

Results of Operations Table of Contents

Summary Operating Statistics

	Three Months Ended June 30		Six Months Ended June 30
	2022	2021	2022	2021
Average Net Production
Crude oil (MBD)
Consolidated operations	857	836	880	820
Equity affiliates	14	13	13	13
Total crude oil	871	849	893	833
Natural gas liquids (MBD)
Consolidated operations	236	120	227	113
Equity affiliates	8	8	7	8
Total natural gas liquids	244	128	234	121
Bitumen (MBD)	59	68	63	69
Natural gas (MMCFD)
Consolidated operations	1,872	2,209	1,999	2,142
Equity affiliates	1,235	1,051	1,181	1,066
Total natural gas	3,107	3,260	3,180	3,208
Total Production (MBOED)	1,692	1,588	1,720	1,558

	Dollars Per Unit
Average Sales Prices
Crude oil (per bbl)
Consolidated operations	$	111.49	65.54	102.97	61.60
Equity affiliates	111.97		64.10	105.20	62.03
Total crude oil	111.50		65.51	103.00	61.60
Natural gas liquids (per bbl)
Consolidated operations	42.20		25.62	41.61	25.06
Equity affiliates	72.44		44.12	69.99	46.53
Total natural gas liquids	43.26		26.87	42.57	26.68
Bitumen (per bbl)	75.42		37.60	70.25	34.09
Natural gas (per MCF)
Consolidated operations	10.19		4.25	9.46	4.56
Equity affiliates	10.08		3.97	9.51	3.76
Total natural gas	10.15		4.16	9.48	4.29

	Millions of Dollars
Exploration Expenses
General administrative, geological and geophysical,    lease rental and other	$	46	56	108	134
Leasehold impairment	10		1	16	1
Dry holes	87		—	88	6
	$	143	57	212	141

37 ConocoPhillips      2022 Q2 10-Q

Results of Operations Table of Contents

We explore for, produce, transport and market crude oil, bitumen, natural gas, LNG and NGLs on a worldwide basis. In the quarter ending June 30, 2022, our operations were producing in the U.S., Norway, Canada, Australia, China, Malaysia, Qatar and Libya.

Total production of 1,692 MBOED increased 104 MBOED or 7 percent in the second quarter of 2022 and 162 MBOED or 10 percent in the six-month period of 2022, primarily due to:

•New wells online in the Lower 48, Alaska, Malaysia and Canada.

•Higher volumes in the Lower 48 due to our Shell Permian acquisition.

•Conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis.

Production increases in the second quarter and in the six-month period of 2022 were partly offset due to:

•Normal field decline.

•Divestitures of Indonesia and noncore assets in the Lower 48 segment.

Production for the second quarter of 2022 was 1,692 MBOED, an increase of 104 MBOED from the same period a year ago. After adjusting for closed acquisitions and dispositions and the conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis, second-quarter 2022 production decreased by 69 MBOED or 4 percent from the same period a year ago. Organic growth from Lower 48 and other development programs more than offset decline; however, production was lower overall primarily due to planned and unplanned downtime.

Production for the first six months of 2022 was 1,720 MBOED, an increase of 162 MBOED from the same period a year ago. After adjusting for closed acquisitions and dispositions, the conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis, and 2021 Winter Storm Uri impacts, production decreased

53 MBOED or 3 percent from the same period a year ago. Organic growth from Lower 48 and other development programs more than offset decline; however, production was lower overall primarily due to planned and unplanned downtime.

ConocoPhillips      2022 Q2 10-Q 38

Results of Operations Table of Contents

Segment Results

Alaska

	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income ($MM)	$	687	371	1,271	530
Average Net Production
Crude oil (MBD)	177		184	180	187
Natural gas liquids (MBD)	16		15	17	16
Natural gas (MMCFD)	34		11	34	10
Total Production (MBOED)	199		201	203	205
Average Sales Prices
Crude oil ($ per bbl)	$	114.77	67.87	105.26	63.93
Natural gas ($ per MCF)	3.34		4.53	3.66	3.17

The Alaska segment primarily explores for, produces, transports and markets crude oil, NGLs and natural gas. As of June 30, 2022, Alaska contributed 18 percent of our consolidated liquids production and two percent of our consolidated natural gas production.

Net Income

Earnings from Alaska increased $316 million and $741 million in the three- and six-month periods of 2022, respectively. Increases to earnings include:

•Higher realized crude oil prices.

Offsets to the earnings increase include:

•Higher taxes other than income taxes associated with higher realized crude oil prices.

In addition to the items detailed above, in the six-month period of 2022, earnings also increased due to:

•Lower DD&A expenses primarily driven by lower rates from price-related reserve revisions and lower production.

Production

Average production decreased slightly in the three- and six-month periods of 2022, respectively. Decreases to production include:

•Normal field decline.

•Higher downtime and lower base performance primarily in our Greater Kuparuk Area.

Offsets to the production decreases include:

•New wells online at our Western North Slope assets.

•Higher gas volumes in our Greater Prudhoe Area.

39 ConocoPhillips      2022 Q2 10-Q

Results of Operations Table of Contents

Lower 48

	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income ($MM)	$	3,581	1,175	6,371	1,643
Average Net Production
Crude oil (MBD)	528		454	533	435
Natural gas liquids (MBD)*	214		97	203	89
Natural gas (MMCFD)*	1,411		1,459	1,419	1,389
Total Production (MBOED)	977		794	972	755
Average Sales Prices
Crude oil ($ per bbl)	$	109.14	64.13	101.34	60.17
Natural gas liquids ($ per bbl)	42.00		24.62	41.26	24.34
Natural gas ($ per MCF)	6.85		3.27	5.74	3.88

*2022 includes the conversion of previously acquired Concho two-stream contracts to three-stream initiated in the fourth quarter of 2021.

The Lower 48 segment consists of operations located in the U.S. Lower 48 states, as well as producing properties in the Gulf of Mexico. As of June 30, 2022, the Lower 48 contributed 67 percent of our consolidated liquids production and

71 percent of our consolidated natural gas production.

Net Income

Earnings from the Lower 48 increased $2,406 million and $4,728 million in the three- and six-month periods of 2022, respectively. Increases to earnings include:

•Higher realized prices.

•Higher sales volumes of crude oil and NGLs primarily related to our Shell Permian Acquisition. See Note 3.

•After-tax gains on disposition of $63 million related to the sale of certain noncore assets as well as contingent payments of $16 million and $32 million in the three- and six-month periods of 2022, respectively, associated with previous asset sales. See Note 3.

Offsets to the earnings increase include:

•Higher production and operating expenses, taxes other than income taxes and DD&A expenses primarily due to higher production volumes. Partially offsetting the increase in DD&A expenses were lower rates from price-related reserve revisions.

In addition to the items detailed above, in the six-month period of 2022, earnings also increased due to the absence of realized losses on hedges related to derivative positions acquired in our Concho acquisition. See Note 10.

Production

Average production increased 183 MBOED and 217 MBOED in the three- and six-month periods of 2022, respectively. Increases to production include:

•New wells online from our development programs in Permian, Eagle Ford and Bakken.

•Higher volumes due to our Shell Permian acquisition. See Note 3.

•Conversion of previously acquired Concho contracted volumes from a two-stream to a three-stream basis.

Offsets to the production increases include:

•Normal field decline.

Completed and Planned Dispositions

On April 1, 2022, we completed our divestiture of certain noncore assets for $370 million, after customary adjustments. Production from these assets averaged approximately 10 MBOED in the three-months ended March 31, 2022. In July 2022, we entered into agreements to sell our interests in certain noncore assets in the Lower 48 segment for $265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022. See Note 3.

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Results of Operations Table of Contents

Canada

	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income ($MM)	$	316	102	607	112
Average Net Production
Crude oil (MBD)	5		9	6	10
Natural gas liquids (MBD)	3		4	3	4
Bitumen (MBD)	59		68	63	69
Natural gas (MMCFD)	66		84	65	87
Total Production (MBOED)	78		95	83	98
Average Sales Prices
Crude oil ($ per bbl)	$	94.79	56.87	88.04	51.66
Natural gas liquids ($ per bbl)	44.93		27.14	43.44	26.19
Bitumen ($ per bbl)	75.42		37.60	70.25	34.09
Natural gas ($ per MCF)	4.47		2.26	3.88	2.32

Average sales prices include unutilized transportation costs.

Our Canadian operations mainly consist of the Surmont oil sands development in Alberta and the liquids-rich Montney unconventional play in British Columbia. As of June 30, 2022, Canada contributed one percent of our consolidated liquids production and three percent of our consolidated natural gas production.

Net Income

Earnings from Canada increased $214 million and $495 million in the three- and six-month periods of 2022, respectively. Increases to earnings include:

•Higher realized prices.

•Higher after-tax gains on disposition related to contingent payments of $118 million and $294 million in the three- and six-month periods of 2022, respectively, associated with the prior sale of certain assets to CVE, compared with $52 million and $72 million in the same periods of 2021, respectively. See Note 3.

Offsetting the earnings increases were lower sales volumes.

Production

Average production decreased 17 MBOED and 15 MBOED in the three- and six-month periods of 2022, respectively. Decreases to production include:

•Normal field decline.

•Planned turnaround at the Surmont Central Processing Facility 1 during the second quarter of 2022.

•Higher royalty rates across the segment due to higher commodity prices.

41 ConocoPhillips      2022 Q2 10-Q

Results of Operations Table of Contents

Europe, Middle East and North Africa

	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income ($MM)	$	385	207	797	360
Consolidated Operations
Average Net Production
Crude oil (MBD)	90		120	101	118
Natural gas liquids (MBD)	3		4	4	4
Natural gas (MMCFD)	306		297	318	303
Total Production (MBOED)	144		173	158	172
Average Sales Prices
Crude oil ($ per bbl)	$	115.61	66.34	103.21	62.48
Natural gas liquids ($ per bbl)	68.00		39.49	60.49	38.21
Natural gas ($ per MCF)	28.32		7.17	28.77	6.58

The Europe, Middle East and North Africa segment consists of operations principally located in the Norwegian sector of the North Sea and the Norwegian Sea, Qatar, Libya and commercial operations in the U.K. During the current period, we have increased our capacity and supply arrangements on future gas purchases, which are primarily offset by future gas sales contracts, primarily in Europe. As of June 30, 2022, our Europe, Middle East and North Africa operations contributed nine percent of our consolidated liquids production and 16 percent of our consolidated natural gas production.

Net Income

Earnings from Europe, Middle East and North Africa increased by $178 million and $437 million in the three- and

six-month periods of 2022, respectively. Increases to earnings include:

•Higher realized prices.

•Higher LNG sales prices, reflected in equity in earnings of affiliates.

•Foreign exchange gains as the USD strengthened against the Norwegian Kroner.

Offsetting the earnings increases include:

•Lower sales volumes primarily due to turnaround activity in Norway in the second quarter.

•Changes to the Petroleum Tax System in Norway. See Note 18.

In addition to the items detailed above, in the six-month period of 2022, earnings impacts include:

•Increase due to lower DD&A expenses primarily driven by lower volumes and lower rates from price-related reserve revisions.

•Decrease due to lower sales volumes primarily due to turnaround activity in Qatar in the first quarter, reflected in equity in earnings of affiliates.

ConocoPhillips      2022 Q2 10-Q 42

Results of Operations Table of Contents

Consolidated Production

Average consolidated production decreased 29 MBOED and 15 MBOED in the three- and six-month periods of 2022, respectively. Decreases to production include:

•Fieldwide turnarounds in the Greater Ekofisk Area of Norway in the second quarter of 2022.

•Normal field decline.

•Curtailed production in Libya due to the force majeure at the Es Sider export terminal in June.

Offsets to the production decreases include:

•New wells online and improved performance in Norway.

Force Majeure in Libya

Production ceased the last week of June 2022, due to a forced shutdown of the Es Sider export terminal after a period of civil unrest. Force majeure was lifted on July 15, 2022, and production has resumed.

Exploration Activity

Three wells from our 2022 four well exploration and appraisal campaign in Norway have been drilled and determined to be dry holes, increasing exploration expenses by approximately $76 million including the Slagugle appraisal well, which is in an area we are continuing to evaluate.

43 ConocoPhillips      2022 Q2 10-Q

Results of Operations Table of Contents

Asia Pacific

	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income ($MM)	$	525	175	1,661	492
Consolidated Operations
Average Net Production
Crude oil (MBD)	57		69	60	70
Natural gas (MMCFD)	55		358	163	353
Total Production (MBOED)	66		129	87	129
Average Sales Prices
Crude oil ($ per bbl)	$	117.14	67.72	110.89	64.01
Natural gas ($ per MCF)	4.17		6.32	6.53	6.10

The Asia Pacific segment has operations in China, Malaysia, Australia and commercial operations in Singapore and Japan. As of June 30, 2022, Asia Pacific contributed five percent of our consolidated liquids production and eight percent of our consolidated natural gas production.

Net Income

Earnings from Asia Pacific increased $350 million and $1,169 million in the three- and six-month periods of 2022, respectively. Increases to earnings include:

•Higher equity in earnings of affiliates reflecting higher LNG sales prices as well as our increased interest in APLNG.

•Higher realized crude oil prices.

•Lower DD&A expenses associated with lower production volumes due to the divestiture of our Indonesia assets and lower rates from positive price-related reserve revisions.

Offsets to the earnings increase include:

•Lower sales volumes primarily due to the divestiture of our Indonesia assets.

•Higher taxes other than income taxes primarily due to higher realized crude oil prices.

In addition to the items detailed above, in the six-month period of 2022, earnings impacts include:

•Increase due to an after-tax gain of $534 million associated with the divestiture of our Indonesia assets. See Note 3.

•Decrease due to absence of an after-tax gain of $200 million recognized in the first quarter of 2021 related to a contingent payment from our Australia-West divestiture in 2020. See Note 9.

Consolidated Production

Average consolidated production decreased 63 MBOED and 42 MBOED in the three- and six-month periods of 2022, respectively. Decreases to production include:

•Divestiture of our Indonesia assets in the first quarter of 2022.

•Normal field decline.

•Decrease in crude oil entitlement percentage and PSC adjustments in Malaysia.

Offsets to the production decreases includes Bohai Bay development activity in China.

Asset Acquisitions and Dispositions

In the first quarter of 2022, we completed the acquisition of an additional 10 percent interest in APLNG increasing our ownership to 47.5 percent. Also in the first quarter, we completed the divestiture of our subsidiaries that held our Indonesia assets and operations. Production from the disposed assets averaged approximately 33 MBOED in the

three-months ended March 31, 2022. See Note 3.

ConocoPhillips      2022 Q2 10-Q 44

Results of Operations Table of Contents

Other International

	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Loss ($MM)	$	—	(5)	—	(9)

The Other International segment consists of exploration and appraisal activities in Colombia as well as contingencies associated with prior operations in other countries. As a result of recent acquisitions, we refocused our exploration program and announced our intent to pursue managed exits from certain areas.

Earnings from our Other International operations improved $5 million in the second quarter of 2022 and $9 million in the six-month period ended June 30, 2022, compared with the same periods of 2021.

Corporate and Other

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income (Loss)
Net interest expense	$	(164)	(181)	(382)	(451)
Corporate general and administrative expenses	(16)		(65)	(95)	(194)
Technology	(9)		(4)	49	37
Other income (expense)	(160)		316	625	553
	$	(349)	66	197	(55)

Net interest expense consists of interest and financing expense, net of interest income and capitalized interest. Net interest expense improved by $17 million and $69 million in the three- and six-month periods of 2022, respectively, primarily as a result of our debt reduction transactions. Improvement in the six-month period also includes the absence of a prior year tax adjustment.

Corporate G&A expenses include compensation programs and staff costs. These expenses decreased by $49 million and $99 million in the three- and six-month periods ended June 30, 2022, respectively, due to mark to market adjustments associated with certain compensation programs. Additionally, in the six-month period of 2022 Corporate G&A expenses decreased due to the absence of restructuring expenses associated with our 2021 acquisition of Concho Resources Inc.

Technology includes our investment in new technologies or businesses, as well as licensing revenues. Activities are focused on both conventional and tight oil reservoirs, shale gas, heavy oil, oil sands, enhanced oil recovery, as well as LNG. See Note 16.

Other income (expense) or “Other” includes certain corporate tax-related items, foreign currency transaction gains and losses, environmental costs associated with sites no longer in operation, other costs not directly associated with an operating segment, gains/losses on the early retirement of debt, holding gains or losses on equity securities, and pension settlement expense. In the second quarter of 2022, “Other” decreased $476 million primarily due to the absence of unrealized gains associated with our CVE common shares which were fully divested in the first quarter of 2022 and premiums paid to repurchase debt. For the six-month period of 2022, "Other" increased $72 million. In addition to the items mentioned previously, during the first quarter of 2022, the IRS closed the 2017 audit of our U.S. federal income tax return, resulting in $474 million federal tax benefit. Also in the first quarter, we recognized an after-tax gain of $62 million associated with the debt restructuring transactions, partly offset by a $101 million tax impact associated with the disposition of our Indonesia assets. See Note 5 for information on our CVE common shares, Note 18 for information about the tax benefit, Note 6 for information regarding debt and Note 3 for information on our Indonesia divestiture.

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Capital Resources and Liquidity Table of Contents

Capital Resources and Liquidity

Financial Indicators

	Millions of Dollars
	June 30 2022			December 31 2021
Cash and cash equivalents	$	6,909		5,028
Short-term investments	1,272			446
Total debt	16,971			19,934
Total equity	50,202			45,406
Percent of total debt to capital*	25		%	31
Percent of floating-rate debt to total debt	2		%	4

*Capital includes total debt and total equity.

To meet our short- and long-term liquidity requirements, we look to a variety of funding sources, including cash generated from operating activities, our commercial paper and credit facility programs, and our ability to sell securities using our shelf registration statement. During the first six months of 2022, the primary uses of our available cash were

$5.1 billion to support our ongoing capital expenditures and investments program, $3.7 billion to repurchase common stock, $2.9 billion net to reduce debt as part of refinancing transactions and retirements, $1.9 billion to pay dividends, including the ordinary dividend and a VROC, and $1.1 billion net purchases of investments.

At June 30, 2022, we had total liquidity of $13.7 billion, including cash and cash equivalents of $6.9 billion, short-term investments of $1.3 billion, and available borrowing capacity under our credit facility of $5.5 billion. We believe current cash balances and cash generated by operating activities, together with access to external sources of funds as described below in the “Significant Changes in Capital” section, will be sufficient to meet our funding requirements in the near- and long-term, including our capital spending program, acquisitions, dividend payments and debt obligations.

Significant Changes in Capital

Operating Activities

Cash provided by operating activities was $13.0 billion for the first six months of 2022, compared with $6.3 billion for the corresponding period of 2021. The increase in cash provided by operating activities is primarily due to higher realized commodity prices, higher sales volumes mostly due to our acquisition of Shell Permian assets, and the absence of the 2021 settlement of all oil and gas hedging positions acquired from Concho. The increase in cash provided by operating activities was partly offset by the timing of Libya tax and royalty payments occurring in the first quarter of 2022 as well as U.S. tax payments in the second quarter.

Our short- and long-term operating cash flows are highly dependent upon prices for crude oil, bitumen, natural gas, LNG and NGLs. Prices and margins in our industry have historically been volatile and are driven by market conditions over which we have no control. Absent other mitigating factors, as these prices and margins fluctuate, we would expect a corresponding change in our operating cash flows.

The level of production volumes, as well as product and location mix, impacts our cash flows. Future production is subject to numerous uncertainties, including, among others, the volatile crude oil and natural gas price environment, which may impact investment decisions; the effects of price changes on production sharing and variable-royalty contracts; acquisition and disposition of fields; field production decline rates; new technologies; operating efficiencies; timing of startups and major turnarounds; political instability; impacts of a global pandemic; weather-related disruptions; and the addition of proved reserves through exploratory success and their timely and cost-effective development. While we actively manage for these factors, production levels can cause variability in cash flows, although generally this variability has not been as significant as that caused by commodity prices.

To maintain or grow our production volumes, we must continue to add to our proved reserve base. See the “Capital Expenditures and Investments” section.

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Capital Resources and Liquidity Table of Contents

Investing Activities

For the first six months of 2022, we invested $5.1 billion in capital expenditures and investments; $1.4 billion of which was acquisition capital for the additional 10 percent interest in APLNG, and the remainder funding our operating capital program. Our 2022 operating plan capital expenditures are currently expected to be $7.8 billion. This guidance excludes $1.4 billion of capital associated with increasing our APLNG interest. Our 2021 capital expenditures and investments were $5.3 billion. See the “Capital Expenditures and Investments” section.

In May 2021, we initiated the monetization of our investment in CVE common shares with the plan to direct proceeds toward our existing share repurchase program. We began disposing of our CVE shares in May 2021, and by the end of the first quarter, we fully divested of our investment, recognizing proceeds of $1.4 billion in the first quarter of 2022. Since inception, we have generated total proceeds of $2.5 billion. See Note 5. Other proceeds from dispositions received in the current year include our divestitures in Asia Pacific and Lower 48 segments for approximately $1.1 billion after customary adjustments and $362 million in contingent payments associated with prior divestitures. See Note 3.

In April 2022, we completed the sale of certain noncore assets in the Lower 48 segment for $370 million after customary adjustments. In July 2022, we entered into agreements to sell our interests in additional noncore assets in the Lower 48 segment for $265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022.

We invest in short-term investments as part of our cash investment strategy, the primary objective of which is to protect principal, maintain liquidity and provide yield and total returns; these investments include time deposits, commercial paper, as well as debt securities classified as available for sale. Funds for short-term needs to support our operating plan and provide resiliency to react to short-term price volatility are invested in highly liquid instruments with maturities within the year. Funds we consider available to maintain resiliency in longer term price downturns and to capture opportunities outside a given operating plan may be invested in instruments with maturities greater than one year.

Investing activities in the first six months of 2022 included net purchases of $1,104 million of investments. We had net purchases of $640 million of short-term instruments and $464 million of long-term instruments. See Note 13.

Financing Activities

In February 2022, we refinanced our revolving credit facility from a total aggregate principal amount of $6.0 billion to $5.5 billion with an expiration date of February 2027. The 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. 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 June 30, 2022.

Our debt balance at June 30, 2022, was $17.0 billion compared with $19.9 billion at December 31, 2021. The current portion of debt, including payments for finance leases, is $0.7 billion. Payments will be made using current cash balances and cash generated by operating activities. In the second quarter of 2022, we repurchased notes and retired floating rate debt and in the first quarter of 2022, we executed a debt refinancing comprised of concurrent transactions including new debt issuances, a cash tender offer and debt exchange offers. In aggregate, the transactions reduced the company's total debt by $3.0 billion. The refinancing facilitates our ability to achieve our previously announced $5 billion debt reduction target by the end of 2026 while also reducing the company's annual cash interest expense.

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: “A3” with a “positive” outlook

See Note 6 for additional information on debt, revolving credit facility and credit ratings.

Certain of our project-related contracts, commercial contracts and derivative instruments contain provisions requiring us to post collateral. Many of these contracts and instruments permit us to post either cash or letters of credit as collateral. At June 30, 2022 and December 31, 2021, we had direct bank letters of credit of $320 million and $337 million, respectively, which secured performance obligations related to various purchase commitments incident to the ordinary conduct of business. In the event of credit ratings downgrades, we may be required to post additional letters of credit.

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Capital Resources and Liquidity Table of Contents

Shelf Registration

We have a universal shelf registration statement on file with the SEC under which we have the ability to issue and sell an indeterminate number of various types of debt and equity securities.

Capital Requirements

For information about our capital expenditures and investments, see the “Capital Expenditures and Investments” section.

In 2021, as part of our objective to maintain a strong balance sheet, we announced our intention to reduce our total debt by $5 billion by 2026. In the first half of 2022, we executed concurrent debt refinancing transactions, repurchased existing notes, and retired floating rates notes upon natural maturity, that in aggregate reduced the company's total debt by

$3 billion and progressed the achievement of our debt reduction target while also lowering our annual cash interest expense and extending the weighted average maturity of our debt portfolio. See Note 6.

In December 2021, we announced our expected 2022 return of capital program and the initiation of a three-tier return of capital framework. The framework is structured to deliver a compelling, growing ordinary dividend and through-cycle share repurchases. In addition to the ordinary dividend and share repurchases, beginning in December 2021, the framework includes the addition of a discretionary VROC tier. The VROC will provide a flexible tool for meeting our commitment of returning greater than 30 percent of cash from operating activities during periods where commodity prices are meaningfully higher than our planning price range. Our expected 2022 total capital return is $15 billion, an increase of $5 billion from our previously announced target.

In the first six months of 2022, we paid ordinary dividends of $0.92 per common share. In addition, we paid VROC dividends of $0.50 per common share for dividends declared in the fourth quarter of 2021 and the first quarter of 2022. In the first six months of 2021, we paid ordinary dividends of $0.86 per common share. On August 4, 2022, we declared both a third-quarter ordinary dividend and a fourth-quarter VROC. The ordinary dividend is $0.46 per share payable September 1, 2022, to shareholders of record on August 16, 2022. The VROC is $1.40 per share, payable October 14, 2022 to shareholders of record on September 29, 2022

In late 2016, we initiated our current share repurchase program with Board of Director’s authorization of $25 billion of our common stock. As of June 30, 2022, share repurchases since the inception of our current program totaled 285 million shares and $17.9 billion. In the six months ended June 30, 2022, we repurchased 37.7 million shares for a cost of

$3.7 billion. Repurchases are made at management’s discretion, at prevailing prices, subject to market conditions and other factors.

See Part I—Item 1A—Risk Factors – “Our ability to execute our capital return program is subject to certain considerations” in our 2021 Annual Report on Form 10-K.

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Capital Resources and Liquidity Table of Contents

Capital Expenditures and Investments

	Millions of Dollars
	Six Months Ended June 30
	2022	2021
Alaska	471	463
Lower 48	2,347	1,480
Canada	247	68
Europe, Middle East and North Africa	364	257
Asia Pacific	1,664	148
Other International	—	18
Corporate and Other	36	31
Capital expenditures and investments	5,129	2,465

During the first six months of 2022, capital expenditures and investments supported key operating activities and acquisitions, primarily:

•Development activities in the Lower 48, primarily Permian, Eagle Ford and Bakken.

•Appraisal and development activities in Alaska related to the Western North Slope and development activities in the Greater Kuparuk Area.

•Appraisal and development activities in the Montney and optimization of oil sands development in Canada.

•Development, exploration, and appraisal activities across assets in Norway.

•Continued development activities in Malaysia and China.

•Acquisition capital associated with 10 percent additional interest in APLNG.

Our 2022 operating plan capital expenditures is currently expected to be $7.8 billion compared with $5.3 billion in 2021.

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Guarantor Summarized Financial Information

We have various cross guarantees among our Obligor group; ConocoPhillips, ConocoPhillips Company and Burlington Resources LLC, with respect to publicly held debt securities. ConocoPhillips Company is 100 percent owned by ConocoPhillips. Burlington Resources LLC is 100 percent owned by ConocoPhillips Company. ConocoPhillips and/or ConocoPhillips Company have fully and unconditionally guaranteed the payment obligations of Burlington Resources LLC, with respect to its publicly held debt securities. Similarly, ConocoPhillips has fully and unconditionally guaranteed the payment obligations of ConocoPhillips Company with respect to its publicly held debt securities. In addition, ConocoPhillips Company has fully and unconditionally guaranteed the payment obligations of ConocoPhillips with respect to its publicly held debt securities. All guarantees are joint and several.

The following tables present summarized financial information for the Obligor Group, as defined below:

•The Obligor Group will reflect guarantors and issuers of guaranteed securities consisting of ConocoPhillips, ConocoPhillips Company and Burlington Resources LLC.

•Consolidating adjustments for elimination of investments in and transactions between the collective guarantors and issuers of guaranteed securities are reflected in the balances of the summarized financial information.

•Non-Obligated Subsidiaries are excluded from the presentation.

Transactions and balances reflecting activity between the Obligors and Non-Obligated Subsidiaries are presented below:

Summarized Income Statement Data

	Millions of Dollars
	Six Months Ended June 30, 2022
Revenues and Other Income	$	27,937
Income before income taxes*	10,478
Net Income	10,904

*Includes approximately $5.1 billion of purchased commodities expense for transactions with Non-Obligated Subsidiaries.

Summarized Balance Sheet Data

	Millions of Dollars
	June 30, 2022		December 31, 2021
Current assets	$	10,013	7,689
Amounts due from Non-Obligated Subsidiaries, current	2,268		1,927
Noncurrent assets	78,542		69,841
Amounts due from Non-Obligated Subsidiaries, noncurrent	8,343		7,281
Current liabilities	9,240		8,005
Amounts due to Non-Obligated Subsidiaries, current	4,624		3,477
Noncurrent liabilities	35,671		30,677
Amounts due to Non-Obligated Subsidiaries, noncurrent	20,343		13,007

Contingencies

We are subject to legal proceedings, claims, and liabilities that arise in the ordinary course of business. We accrue for losses associated with legal claims when such losses are considered probable and the amounts can be reasonably estimated. See Note 9.

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Capital Resources and Liquidity Table of Contents

Legal and Tax Matters

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.

Environmental

We are subject to the same numerous international, federal, state and local environmental laws and regulations as other companies in our industry. For a discussion of the most significant of these environmental laws and regulations, including those with associated remediation obligations, see the “Environmental” section in Management’s Discussion and Analysis of Financial Condition and Results of Operations on pages 58–60 of our 2021 Annual Report on Form 10-K.

We occasionally receive requests for information or notices of potential liability from the EPA and state environmental agencies alleging that we are a potentially responsible party under the Federal Comprehensive Environmental Response, Compensation and Liability Act (CERCLA) or an equivalent state statute. On occasion, we also have been made a party to cost recovery litigation by those agencies or by private parties. These requests, notices and lawsuits assert potential liability for remediation costs at various sites that typically are not owned by us, but allegedly contain waste attributable to our past operations. As of June 30, 2022, there were 15 sites around the U.S. in which we were identified as a potentially responsible party under CERCLA and comparable state laws.

At June 30, 2022, our balance sheet included a total environmental accrual of $178 million, compared with $187 million at December 31, 2021, for remediation activities in the U.S. and Canada. We expect to incur a substantial amount of these expenditures within the next 30 years.

Notwithstanding any of the foregoing, and as with other companies engaged in similar businesses, environmental costs and liabilities are inherent concerns in our operations and products, and there can be no assurance that material costs and liabilities will not be incurred. However, we currently do not expect any material adverse effect upon our results of operations or financial position as a result of compliance with current environmental laws and regulations.

See Part I—Item 1A—Risk Factors – "We expect to continue to incur substantial capital expenditures and operating costs as a result of our compliance with existing and future environmental laws and regulations" in our 2021 Annual Report on Form 10-K and Note 9 for information on environmental litigation.

Climate Change

Continuing political and social attention to the issue of global climate change has resulted in a broad range of proposed or promulgated state, national and international laws focusing on GHG reduction. These proposed or promulgated laws apply or could apply in countries where we have interests or may have interests in the future. Laws in this field continue to evolve, and while it is not possible to accurately estimate either a timetable for implementation or our future compliance costs relating to implementation, such laws, if enacted, could have a material impact on our results of operations and financial condition. For examples of legislation or precursors for possible regulation and factors on which the ultimate impact on our financial performance will depend, see the “Climate Change” section in Management’s Discussion and Analysis of Financial Condition and Results of Operations on pages 61–63 of our 2021 Annual Report on Form 10-K.

See Part I—Item 1A—Risk Factors – "Existing and future laws, regulations and internal initiatives relating to global climate changes, such as limitations on GHG emissions may impact or limit our business plans, result in significant expenditures, promote alternative uses of energy or reduce demand for our products" in our 2021 Annual Report on Form 10-K and Note 9 for information on climate change litigation.

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Company Response to Climate-Related Risks

The company has responded by putting in place a Sustainable Development Risk Management Standard covering the assessment and registration of significant and high sustainable development risks based on their consequence and likelihood of occurrence. We have developed a company-wide Climate Change Action Plan with the goal of tracking mitigation activities for each climate-related risk included in the corporate Sustainable Development Risk Register.

The risks addressed in our Climate Change Action Plan fall into four broad categories:

•GHG-related legislation and regulation.

•GHG emissions management.

•Physical climate-related impacts.

•Climate-related disclosure and reporting.

We announced in October 2020 the adoption of a Paris-aligned climate risk framework with the objective of implementing a coherent set of choices designed to facilitate the success of our existing exploration and production business through the energy transition. Given the uncertainties remaining about how the energy transition will evolve, the strategy aims to be robust across a range of potential future outcomes.

We announced in July 2022 that ConocoPhillips has joined the OGMP 2.0 initiative. The initiative's mission is to improve industry transparency in methane emissions reporting and encourage progress in reducing those emissions. We believe that applying the rigorous OGMP 2.0 reporting standards across our global assets will be a vital step towards meeting our Paris-aligned climate-risk commitments, including our net-zero ambition for operational emissions by 2050, and will allow us to credibly demonstrate how we are delivering against our methane improvement objectives and targets.

In 2022, we published our Plan for the Net-Zero Energy Transition (the ‘Plan’) focusing on meeting energy transition pathway demand, delivering competitive returns on and of capital and achieving our net-zero operational emissions ambitions.

Our Plan describes how we will:

•Build a resilient asset portfolio: Focus on low cost of supply and low GHG intensity resources.

•Commit to near, medium, and long-term targets: Reducing operational (Scope 1 and 2) emissions over which we have ownership and control with an ambition to become a net-zero company for Scope 1 and 2 emissions by 2050. These targets include:

•Strengthening our previously announced operational GHG emissions intensity reduction target to 40-50% by 2030 and expanding it to apply to both a gross operated and net equity basis.

•Meeting a further 10% reduction target for methane emissions intensity by 2025 from our 2019 baseline.

•Aiming to achieve zero routine flaring by 2025.

•Address end-use emissions: Advocate for a well-designed, economy-wide price on carbon that would help shift consumer demand from high-carbon to low-carbon energy sources.

•Pursue transition opportunities: Evaluate potential investments in emerging energy transition and low-carbon technologies.

•In 2021, we established a multi-disciplinary Low-Carbon Technologies organization to identify and evaluate business opportunities that address end-use emissions and early-stage low-carbon technology opportunities that would leverage our existing expertise and adjacencies.

•In the 2022 capital budget, we allocated $200 million to advance energy transition activities, the majority of which will address Scope 1 and 2 emissions reduction projects across our global operations, with the rest allocated for early-stage low-carbon technology opportunities.

•Track the energy transition: Utilize a comprehensive scenario planning process to calibrate and understand alternative energy transition pathways.

•Maintain capital discipline: Use scenario analyses and a fully-burdened cost of supply, including an appropriate cost of carbon, as the primary basis for capital allocation.

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Cautionary Statement for the Purposes of the “Safe Harbor” Provisions of the Private Securities Litigation Reform Act of 1995

This report includes forward-looking statements within the meaning of Section 27A of the Securities Act of 1933 and Section 21E of the Securities Exchange Act of 1934. All statements other than statements of historical fact included or incorporated by reference in this report, including, without limitation, statements regarding our future financial position, business strategy, budgets, projected revenues, projected costs and plans, objectives of management for future operations are forward-looking statements. Examples of forward-looking statements contained in this report include our expected production growth and outlook on the business environment generally, our expected capital budget and capital expenditures, and discussions concerning future dividends. You can often identify our forward-looking statements by the words “anticipate,” “believe,” “budget,” “continue,” “could,” “effort,” “estimate,” “expect,” “forecast,” “intend,” “goal,” “guidance,” “may,” “objective,” “outlook,” “plan,” “potential,” “predict,” “projection,” “seek,” “should,” “target,” “will,” “would” and similar expressions.

We based the forward-looking statements on our current expectations, estimates and projections about ourselves and the industries in which we operate in general. We caution you these statements are not guarantees of future performance as they involve assumptions that, while made in good faith, may prove to be incorrect, and involve risks and uncertainties we cannot predict. In addition, we based many of these forward-looking statements on assumptions about future events that may prove to be inaccurate. Accordingly, our actual outcomes and results may differ materially from what we have expressed or forecast in the forward-looking statements. Any differences could result from a variety of factors and uncertainties, including, but not limited to, the following:

•The impact of public health crises, including pandemics (such as COVID-19) and epidemics and any related company or government policies or actions.

•Global and regional changes in the demand, supply, prices, differentials or other market conditions affecting oil and gas, including changes as a result of any ongoing military conflict, including the conflict between Russia and Ukraine, and the global response to such conflict, or from a public health crisis or from the imposition or lifting of crude oil production quotas or other actions that might be imposed by OPEC and other producing countries and the resulting company or third-party actions in response to such changes.

•Fluctuations in crude oil, bitumen, natural gas, LNG and NGLs prices, including a prolonged decline in these prices relative to historical or future expected levels.

•The impact of significant declines in prices for crude oil, bitumen, natural gas, LNG and NGLs, which may result in recognition of impairment charges on our long-lived assets, leaseholds and nonconsolidated equity investments.

•The potential for insufficient liquidity or other factors, such as those described herein, that could impact our ability to repurchase shares and declare and pay dividends, whether fixed or variable.

•Potential failures or delays in achieving expected reserve or production levels from existing and future oil and gas developments, including due to operating hazards, drilling risks and the inherent uncertainties in predicting reserves and reservoir performance.

•Reductions in reserves replacement rates, whether as a result of the significant declines in commodity prices or otherwise.

•Unsuccessful exploratory drilling activities or the inability to obtain access to exploratory acreage.

•Unexpected changes in costs, inflationary pressures or technical requirements for constructing, modifying or operating E&P facilities.

•Legislative and regulatory initiatives addressing environmental concerns, including initiatives addressing the impact of global climate change or further regulating hydraulic fracturing, methane emissions, flaring or water disposal.

•Lack of, or disruptions in, adequate and reliable transportation for our crude oil, bitumen, natural gas, LNG and NGLs.

•Inability to timely obtain or maintain permits, including those necessary for construction, drilling and/or development, or inability to make capital expenditures required to maintain compliance with any necessary permits or applicable laws or regulations.

•Failure to complete definitive agreements and feasibility studies for, and to complete construction of, announced and future E&P and LNG development in a timely manner (if at all) or on budget.

53 ConocoPhillips      2022 Q2 10-Q

•Potential disruption or interruption of our operations due to accidents, extraordinary weather events, supply chain disruptions, civil unrest, political events, war, terrorism, cyber attacks, and information technology failures, constraints or disruptions.

•Changes in international monetary conditions and foreign currency exchange rate fluctuations.

•Changes in international trade relationships, including the imposition of trade restrictions or tariffs relating to crude oil, bitumen, natural gas, LNG, NGLs and any materials or products (such as aluminum and steel) used in the operation of our business, including any sanctions imposed as a result of any ongoing military conflict, including the conflict between Russia and Ukraine.

•Substantial investment in and development use of, competing or alternative energy sources, including as a result of existing or future environmental rules and regulations.

•Liability for remedial actions, including removal and reclamation obligations, under existing and future environmental regulations and litigation.

•Significant operational or investment changes imposed by existing or future environmental statutes and regulations, including international agreements and national or regional legislation and regulatory measures to limit or reduce GHG emissions.

•Liability resulting from litigation, including litigation directly or indirectly related to the transaction with Concho Resources Inc., or our failure to comply with applicable laws and regulations.

•General domestic and international economic and political developments, including armed hostilities; expropriation of assets; changes in governmental policies relating to crude oil, bitumen, natural gas, LNG and NGLs pricing; regulation or taxation; and other political, economic or diplomatic developments, including as a result of any ongoing military conflict, including the conflict between Russia and Ukraine.

•Volatility in the commodity futures markets.

•Changes in tax and other laws, regulations (including alternative energy mandates), or royalty rules applicable to our business.

•Competition and consolidation in the oil and gas E&P industry.

•Any limitations on our access to capital or increase in our cost of capital, including as a result of illiquidity or uncertainty in domestic or international financial markets or investment sentiment.

•Our inability to execute, or delays in the completion of, any asset dispositions or acquisitions we elect to pursue.

•Potential failure to obtain, or delays in obtaining, any necessary regulatory approvals for pending or future asset dispositions or acquisitions, or that such approvals may require modification to the terms of the transactions or the operation of our remaining business.

•Potential disruption of our operations as a result of pending or future asset dispositions or acquisitions, including the diversion of management time and attention.

•Our inability to deploy the net proceeds from any asset dispositions that are pending or that we elect to undertake in the future in the manner and timeframe we currently anticipate, if at all.

•The operation and financing of our joint ventures.

•The ability of our customers and other contractual counterparties to satisfy their obligations to us, including our ability to collect payments when due from the government of Venezuela or PDVSA.

•Our inability to realize anticipated cost savings and capital expenditure reductions.

•The inadequacy of storage capacity for our products, and ensuing curtailments, whether voluntary or involuntary, required to mitigate this physical constraint.

•The risk that we will be unable to retain and hire key personnel.

•Unanticipated integration issues relating to the acquisition of assets from Shell, such as potential disruptions of our ongoing business and higher than anticipated integration costs.

•Uncertainty as to the long-term value of our common stock.

•The diversion of management time on integration-related matters.

•The factors generally described in Part I—Item 1A in our 2021 Annual Report on Form 10-K and any additional risks described in our other filings with the SEC.

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Item 3.    Quantitative and Qualitative Disclosures about Market Risk

Information about market risks for the six months ended June 30, 2022 does not differ materially from that discussed under Item 7A in our 2021 Annual Report on Form 10-K.

Item 4.    Controls and Procedures

We maintain disclosure controls and procedures designed to ensure information required to be disclosed in reports we file or submit under the Securities Exchange Act of 1934, as amended (the Act), is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms, and that such information is accumulated and communicated to management, including our principal executive and principal financial officers, as appropriate, to allow timely decisions regarding required disclosure. At June 30, 2022, with the participation of our management, our Chairman and Chief Executive Officer (principal executive officer) and our Executive Vice President and Chief Financial Officer (principal financial officer) carried out an evaluation, pursuant to Rule 13a-15(b) of the Act, of ConocoPhillips’ disclosure controls and procedures (as defined in Rule 13a-15(e) of the Act). Based upon that evaluation, our Chairman and Chief Executive Officer and our Executive Vice President and Chief Financial Officer concluded our disclosure controls and procedures were operating effectively at June 30, 2022.

There have been no changes in our internal control over financial reporting, as defined in Rule 13a-15(f) of the Act, in the period covered by this report that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting.

PART II. Other Information

Item 1.    Legal Proceedings

The interim-period financial information presented in the financial statements included in this report is unaudited. There are no new material legal proceedings or material developments with respect to matters previously disclosed in Item 3 of our 2021 Annual Report on Form 10-K.

Item 1A.    Risk Factors

There have been no material changes from the risk factors disclosed in Item 1A of our 2021 Annual Report on Form 10-K.

55 ConocoPhillips      2022 Q2 10-Q

Item 2.    Unregistered Sales of Equity Securities and Use of Proceeds

Issuer Purchases of Equity Securities

					Millions of Dollars
Period	Total Number of  Shares Purchased*	Average Price Paid  per Share		Total Number of  Shares Purchased as Part of Publicly Announced Plans or  Programs	Approximate Dollar Value of Shares That May Yet Be Purchased Under the Plans or  Programs
April 1 - 30, 2022	3,253,879	$	99.13	3,253,879	$	9,113
May 1 - 31, 2022	5,554,477	103.29		5,554,477	8,539
June 1 - 30, 2022	13,139,706	106.83		13,139,706	7,136
	21,948,062			21,948,062

*There were no repurchases of common stock from company employees in connection with the company's broad-based employee incentive plans.

In late 2016, we initiated our current share repurchase program, which has a total program authorization of $25 billion of our common stock. As of June 30, 2022, we had repurchased $17.9 billion of shares. Repurchases are made at management’s discretion, at prevailing prices, subject to market conditions and other factors. Except as limited by applicable legal requirements, repurchases may be increased, decreased or discontinued at any time without prior notice. Shares of stock repurchased under the plan are held as treasury shares. See Part I—Item 1A—Risk Factors – “Our ability to execute our capital return program is subject to certain considerations” in our 2021 Annual Report on Form 10-K.

ConocoPhillips      2022 Q2 10-Q 56

Item 6.     Exhibits

10.1*	Letter agreement with Timothy A. Leach, dated April 28, 2022.
31.1*	Certification of Chief Executive Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.
31.2*	Certification of Chief Financial Officer pursuant to Rule 13a-14(a) under the Securities Exchange Act of 1934.
32*	Certifications pursuant to 18 U.S.C. Section 1350.
101.INS*	Inline XBRL Instance Document.
101.SCH*	Inline XBRL Schema Document.
101.CAL*	Inline XBRL Calculation Linkbase Document.
101.LAB*	Inline XBRL Labels Linkbase Document.
101.PRE*	Inline XBRL Presentation Linkbase Document.
101.DEF*	Inline XBRL Definition Linkbase Document.
104*	Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101).

* Filed herewith.

57 ConocoPhillips      2022 Q2 10-Q

Signature

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

	CONOCOPHILLIPS
	/s/ Kontessa S. Haynes-Welsh
	Kontessa S. Haynes-Welsh
	Chief Accounting Officer
August 4, 2022

ConocoPhillips      2022 Q2 10-Q 58

EX-10.1

                                         Exhibit 10.1

Ryan M. Lance Chairman and Chief Executive Officer 925 N. Eldridge Parkway Houston, TX 77079

April 28, 2022

Timothy A. Leach
600 West Illinois Avenue
Midland, TX 79701

Dear Tim,

I am pleased to inform you of the terms of your continued employment, effective as of May 1, 2022 (the “Effective Date”). This offer is contingent upon execution of this letter (“Letter Agreement”) and execution of the Non-Compete, Non-Solicitation, and Confidentiality Agreement (“Non-Compete Agreement”) appended hereto as Appendix A. The details of the offer are as follows:

From the Effective Date, your title, salary, and principal work locations will be:

Job Title:    Advisor to the Chief Executive Officer (and Member of the Executive Leadership Team)

Salary:    $700,008 / year

Locations:    Houston, Texas and Midland, Texas

You will be directly reporting to me. Under the Charter of the Human Resources and Compensation Committee (“HRCC”) of the Board, because you are considered a Senior Officer of the company, your salary and other elements of compensation are subject to approval by that Committee and will remain subject to periodic review by that Committee. The Committee is expected to meet to approve this offer on April 28, 2022.

Salary and Incentive Award

Subsequent changes to your salary will be based on your performance and our compensation programs.

In addition to your base salary, you will continue to be eligible to participate in the Variable Cash Incentive Program (VCIP). This is an annual program, which if approved, could result in you receiving an award. The Human Resources and Compensation Committee generally approves the awards after the completion of the plan year. Individual awards may be based upon company, unit, and/or individual performance. The awards can range from 0% to 200% of the target. Your target award for the 2022 plan year from the Effective Date will be 83% of your eligible earnings paid during the year.

Executive Programs

In addition to your base salary and VCIP, you will continue to be eligible to participate in the following executive level compensation programs:

Executive Restricted Stock Unit (ERSU) Program: This is an annual program, which, if approved, could result in you receiving an award of time-vested restricted stock units that settle in unrestricted stock three years following the grant date subject to the award terms and conditions. The Human Resources and Compensation Committee generally approves the awards annually in February. Beginning in 2023, you would have a target award base of 110% of your base salary on the last day you worked in the calendar year immediately prior to the grant date of each award. Your awards will not provide for proration if you retire on or after a date six months after the grant date of an award.

                                         Exhibit 10.1

Performance Share Program (PSP): This is a program where target awards are contingent shares of ConocoPhillips stock that are earned based on the Company’s performance over a three-year period, and approved awards will be paid out in restricted stock units, also known as performance share units, and settle in cash per the current program rules. Awards may be adjusted further based on individual performance. The awards can range from 0% to 200% of the target. Beginning in 2023, you would have a target award base of 205% of your base salary on the last day you worked in the calendar year immediately prior to the grant date of each award. The target award for the PSP 22 grant made in February 2022 will not be adjusted because of the change in your Salary Grade Level or base salary, and terms and conditions of the PSP 22 grant, any subsequent PSP 23 grant that may be approved, and any subsequent PSP 24 grant that may be approved will not provide for proration of the targets if you retire with less than 36 months in each applicable Performance Period or if you complete less than twelve full months of employment in the Performance Period, although the terms and conditions of those grants will continue to provide for other standard forfeiture provisions, the final approved payout by the HRCC, and the same payout timing as other participants.

Executive Severance Plan and Key Employee Change in Control Severance Plan: These plans provide severance benefits in the event of a company-initiated termination. In addition to cash payments and other benefits, eligible executives get favored “layoff” treatment with regard to outstanding equity awards.

Indemnification: You shall be eligible for indemnification and covered by D&O insurance to the same extent as applicable for other members of the company’s senior management.

Employee Benefits

You shall remain eligible for the employee benefits of ConocoPhillips. In addition to eligibility in the employee benefits plans, I confirm the following additional benefits:

Executive Defined Contribution Plans: The company provides three plans of nonqualified deferred compensation for which you will continue to be eligible under their terms and conditions. The first, the Key Employee Deferred Compensation Plan, allows salary, VCIP, and PSP deferrals. The second, the Defined Contribution Make-Up Plan, provides the “match” lost due to Internal Revenue Code limits on the amount of compensation that can be taken into account under our 401(k) plan. The third, the Company Retirement Contribution Make-Up Plan, provides accruals lost due to Internal Revenue Code limits on the amount of compensation that can be taken into account under the Company Retirement Contribution feature of our 401(k) plan.

Executive Life Insurance: The company will continue to provide, at no cost to you, group term life insurance coverage equal to one times annual salary as basic life insurance protection. We will also provide, at no cost to you, an additional one times your annual salary in further coverage. Under the company’s life insurance arrangements, you may also purchase supplemental coverage up to an additional eight times your annual salary.

Vacation: With regard to vacation benefit, you will continue to be eligible for six (6) weeks (240 hours) of vacation.

Further Conditions

By accepting this Letter Agreement, you also agree to the following conditions:

Effective as of immediately prior to the Effective Date, you hereby waive the right to terminate employment for “Good Reason” as a result of the position, annual base salary or target annual cash incentive opportunity, and other terms set forth in this Letter Agreement, or for any circumstances existing prior to the Effective Date, for purposes of any outstanding ConocoPhillips equity awards; however, in the event of the termination of your employment by ConocoPhillips without Cause (within the meaning of the applicable award agreement) or by you for circumstances occurring in the future that are not otherwise contemplated by this Letter Agreement and that constitute “Good Reason” (as defined below), such awards shall be eligible to vest in accordance with the terms of the applicable award agreements.

2    

                                         Exhibit 10.1

For all purposes, including any outstanding equity awards issued prior to the Effective Date, the term “Good Reason” shall have the meaning set forth in the ConocoPhillips Key Employee Change in Control Severance Plan, except that with regard to the Inducement Grant Agreement of January 15, 2021, the definition of “Good Reason” contained therein shall apply to that award, and except, further, with respect to any outstanding equity award issued prior to January 15, 2021, the definition of “Good Reason” applicable thereto shall apply to that award, and all outstanding equity awards issued prior to the Effective Date shall be subject to the waiver described above. If you retire on or after December 31, 2024, you will retain all your outstanding ERSUs granted six months or more prior to your retirement and your outstanding PSUs granted prior to December 31, 2024, which will be paid on their applicable schedule. Both ERSUs and PSUs will remain subject to their other applicable terms (including performance in case of PSUs).

Non-Compete Agreement

By accepting this Letter Agreement, you also agree to execute and deliver the Non-Compete Agreement, appended hereto as Appendix A.

Governing Law

This Letter Agreement shall be governed by the laws of the State of Texas. Disputes arising under this Letter Agreement shall be resolved in state and Federal courts located in Houston, Texas.

If you have any further questions about the contents of this offer, please contact me. I’m looking forward to continuing to work with you.

Sincerely,

Ryan M. Lance

Please sign below acknowledging your acceptance of the terms of continued employment with ConocoPhillips.

Signature: ______________________________________________ Date: ____________________

3    

APPENDIX A Exhibit 10.1

NON-COMPETE, NON-SOLICITATION, AND CONFIDENTIALITY AGREEMENT

This Non-Compete, Non-Solicitation, and Confidentiality Agreement (“Agreement”) is entered into by and between ConocoPhillips, a Delaware corporation (“Company”), on behalf of itself, its current, past, and future subsidiaries, and other corporate or partnership affiliates, and its or their successors or assigns (collectively referred to herein as, “Company Group”), and Timothy A. Leach (“Employee”) (Company and Employee are collectively referred to as the “Parties”), on April 28, 2022, and effective as of May 1, 2022 (the “Effective Date”).

In consideration of the compensation described in Section 4.01 of this Agreement, which Employee acknowledges to be good and valuable consideration for Employee’s obligations hereunder, Company and Employee hereby agree as follows:

ARTICLE I

CONFIDENTIALITY

Section 1.01. Non-disclosure of Confidential Information.

(a)  Employee and Company agree that, during the course of Employee’s employment with any member of Company Group and/or service on the Board of Directors of Company (collectively, “Service”) , Employee will or has had and will continue to have access to, and will or has gained and will continue to gain knowledge with respect to, “Confidential Information” (as defined below). Employee agrees that he shall not, without the prior written consent of Company, during the period of his Service and thereafter for so long as it remains Confidential Information, use or disclose, or knowingly permit any unauthorized Person (as defined in Section 13(d) of the Securities Exchange Act of 1934) to use, disclose, or gain access to, any Confidential Information; provided, however, that Employee may disclose Confidential Information (x) as required by law or (y) as ordered by a court, provided that in any event described in the preceding clause (x) or (y), (A) Employee shall promptly notify Company in writing, and consult with and assist Company in seeking a protective order or request for another appropriate remedy, (B) in the event that such protective order or remedy is not obtained, or if Company waives compliance with the terms of the preceding clause (A), Employee shall disclose only that portion of the Confidential Information that, in the opinion of his legal counsel, is legally required to be disclosed and shall exercise reasonable best efforts to assure that confidential treatment shall be accorded to such Confidential Information by the receiving person, and (C) to the extent permitted by applicable law, Company shall be given an opportunity to review the Confidential Information prior to disclosure thereof.

(b) Without limiting the foregoing, Employee agrees to keep confidential the existence of, and any information concerning, any dispute between Employee and Company Group, except that Employee may disclose information concerning such dispute to the court that is considering such dispute and to Employee’s legal counsel, provided that such counsel agrees not to disclose any such information other than as necessary to the prosecution or defense of such dispute.

(c) For purposes of this Agreement, “Confidential Information” means information, observations, and data concerning the business and affairs of Company Group, including all business information (whether or not in written form) that relates to Company Group, or their directors, officers, employees, customers, suppliers, or contractors or any other third parties with respect to which Company Group has a business relationship or owes a duty of confidentiality, or their respective businesses or products, and that is not known to the public generally other than as a result of Employee’s breach of these terms, including technical information or reports; trade secrets; unwritten knowledge and “know-how”; operating instructions; training manuals; customer lists; customer buying records and habits; product sales records and documents; product development, marketing and sales strategies; market surveys; marketing plans; profitability analyses; product cost; long-range plans; information relating to pricing, competitive strategies and new product development, including processes, formulas, designs, drawings, engineering, and technology; information relating to any forms of compensation or other personnel-related information; contracts; and supplier lists. Confidential Information shall not include such information known to Employee prior to his involvement with Company Group or information rightfully obtained from a third party (other than pursuant to a breach by Employee of these terms or any other duty of confidentiality).

(d) Employee’s obligations under this Agreement shall supplement, rather than supplant, his common-law duties of confidentiality and loyalty owed to Company or any member of Company Group.

4    

APPENDIX A Exhibit 10.1

ARTICLE II

RETURN OF PROPERTY

Section 2.01. Return of Property. Employee acknowledges that all documents, records, files, lists, equipment, computer, software, or other property (including intellectual property) relating to the businesses of Company Group, in whatever form (including electronic), and all copies thereof, that have been or are received or created by Employee while an employee of Company Group, including Confidential Information, are and shall remain the property of Company Group, and Employee shall immediately return such property to Company Group upon the date of Employee’s termination and, in any event, at Company’s request. Employee further agrees that any property situated on the premises of, and owned by, Company Group, including disks and other storage media, filing cabinets, or other work areas, is subject to inspection by Company Group personnel at any time with or without notice.

ARTICLE III

NON-COMPETITION, NON-SOLICITATION, AND NON-DISPARAGEMENT

Section 3.01. Acknowledgments.

(a) Employee recognizes and acknowledges the competitive and proprietary aspects of Company Group’s business. Employee acknowledges that a business will be deemed “Competitive” with Company Group if it performs any of the services or manufactures or sells any of the products provided or offered by Company Group.

(b) Employee further acknowledges that, during the course of Employee’s Service, Company Group has and will continue to furnish, disclose, or make available to Employee Confidential Information related to Company Group’s business and that Company Group has and will continue to provide Employee with unique and specialized training, experiences, and opportunities. Employee also acknowledges that such Confidential Information and such training, experiences, and opportunities have been developed and will be developed by Company Group through the expenditure of substantial time, effort, and money and that all such Confidential Information and training, experiences, and opportunities could be used by Employee to compete with Company Group. Employee also acknowledges that if Employee becomes employed by or affiliated with a competitor of Company Group in violation of Employee’s obligations to Company Group, it is inevitable that Employee would disclose the Confidential Information to such competitor and would use such Confidential Information, knowingly or unknowingly, on behalf of such competitor. Further, in the course of Employee’s Service, Employee has been and will be introduced to and collaborate with customers and other business partners of Company Group. Employee acknowledges that any and all “goodwill” created through such relationships belongs exclusively to Company Group, including, without limitation, any goodwill created as a result of direct or indirect contacts or relationships between Employee and any customers or other contacts of the Company.

(c) Employee further acknowledges and agrees that Company Group exclusively owns and shall exclusively own all rights, title, and interest to and in any and all accounts, clients, and/or customers that Employee sources, generates, solicits, and/or brings to Company Group. Employee further acknowledges and agrees that all business written or serviced for all customers, clients, and/or accounts of Company Group, including, but not limited to, any customers, clients and/or accounts that Employee is responsible for generating business from on behalf of Company, shall be written, renewed, and serviced only through the facilities of Company Group and in the name of Company Group and shall be owned exclusively by Company Group, including, but not limited to, the complete and entire goodwill relationship with the clients, customers, and/or accounts with whom Employee shall transact business.

Section 3.02. Non-Competition. Because of Employer Group’s legitimate business interest as described in this Agreement and the good and valuable consideration offered to Employee pursuant to this Agreement, the sufficiency of which is acknowledged, Employee agrees and covenants that during the Restricted Period, Employee shall not engage in Prohibited Activity within any jurisdiction or marketing area within the Permian Basin area in the United States (“Restricted Territory”). Employee acknowledges that Company Group is engaged in business or marketing activities or has specific plans to expand into jurisdictions or marketing areas in the Restricted Territory.

“Restricted Period” is the term of Employee’s Service and a period of two (2) years from the date Employee’s Service ends for any reason whatsoever.

5    

APPENDIX A Exhibit 10.1

“Prohibited Activity” is activity in which Employee contributes Employee’s knowledge, directly or indirectly, in whole or in part, as an employee, employer, owner, operator, manager, advisor, consultant, contractor, agent, partner, director, officer, or any other similar capacity to an entity engaged in the same or similar business as Company Group, including those engaged in the business of exploring for, producing, transporting and marketing crude oil, bitumen, natural gas, liquefied natural gas and natural gas liquids within the Restricted Territory. Prohibited Activity also includes activity that may require or inevitably require disclosure of trade secrets, proprietary information, or Confidential Information.

Nothing in this Agreement shall prohibit Employee from purchasing or owning less than two percent (2%) of the publicly traded securities of any corporation or partnership, provided that such ownership represents a passive investment and that Employee is not a controlling person of, or a member of a group that controls, such corporation or partnership.

This Section does not, in any way, restrict or impede Employee from exercising protected rights to the extent that such rights cannot be waived by agreement or from complying with any applicable law or regulation or a valid order of a court of competent jurisdiction or an authorized government agency, provided that such compliance does not exceed that required by the law, regulation, or order. Employee shall promptly provide written notice of any such order to Company.

Section 3.03. Non-Solicitation. Because of Employer Group’s legitimate business interest as described in this Agreement and the good and valuable consideration offered to Employee pursuant to this Agreement, the sufficiency of which is acknowledged, during the Restricted Period (as defined in Section 3.02 above), Employee will not, without the prior written consent of Company, engage in any of the following activities either individually or on behalf of any other person or entity, directly or indirectly:

(a) Solicit, divert, or appropriate or attempt to solicit, divert, or appropriate any customer, client, or other business partner of Company Group (or any person or entity which was a customer, client, or business partner of Company Group at any time during the six (6) month period preceding such actual or attempted solicitation, diversion, or appropriation), or any prospective customer, client, or business partner with respect to which Company Group has developed or made a presentation (or similar offering of services) during the six (6) month period preceding such actual or attempted solicitation, for the purpose of competing with Company Group or reducing Company Group’s relationship with any customers, clients, or other business partners of Company Group.

(b) Solicit, entice, or persuade or attempt to solicit, entice, or persuade any employee of or consultant to Company Group to end or reduce such individual’s relationship with Company Group, or employ, hire, cause to be employed or engaged, or solicit the employment or the engagement as a consultant of any employee of or consultant to Company Group while such individual is affiliated with Company Group or within six (6) months after such individual ceases to be affiliated with Company Group.

(c) Solicit, entice, or persuade or attempt to solicit, entice, or persuade any third party with whom Employer Group has a contractual or business relationship (including business referral sources, centers of business influence, investors, and/or strategic business partners) to sever, modify, reduce, or in any way alter their business or contractual relationship with Company Group.

Section 3.04. Non-Disparagement. Employee agrees and covenants that Employee will not at any time make, publish, or communicate to any person or entity or in any public forum any defamatory or disparaging remarks, comments, or statements concerning Company Group or its businesses, or any of its employees, officers, and existing and prospective customers, suppliers, investors, and other associated third parties.

This Section does not, in any way, restrict or impede Employee from exercising protected rights to the extent that such rights cannot be waived by agreement or from complying with any applicable law or regulation or a valid order of a court of competent jurisdiction or an authorized government agency, provided that such compliance does not exceed that required by the law, regulation, or order. Employee shall promptly provide written notice of any such order to Company.

Section 3.05. Effect of Breach. In the event Employee breaches any of the terms described in this Article III, Employee acknowledges and agrees that Employee will forfeit any remaining payment in Section 4.01 and will promptly repay to the Company any amounts previously received under Section 4.01.

6    

APPENDIX A Exhibit 10.1

ARTICLE IV

COMPENSATION AND REMEDIES

Section 4.01. Compensation. In consideration for the covenants entered into by Employee in this Agreement, the Company shall pay Employee $3,000,000 in two payments of $1,500,000, with the first payment made on May 1, 2023, and the second payment made on May 1, 2024.

Section 4.02. Conditions and Forfeiture. In order to receive the compensation described in Section 4.01, Employee must, on each payment date, either be (i) actively in Service and in compliance with the covenants set forth in this Agreement that apply during the course of Employee’s Service, or (ii) if no longer actively in Service, must be in compliance with the covenants set forth in this Agreement that apply for a period of time following Employee’s termination of Service. If neither of conditions described in the preceding sentence are met on a payment date, no further payments shall be due hereunder. If Employee is found to be in breach of any of the covenants under this Agreement, then, pursuant to Section 4.03 below, Employee shall repay to Company the compensation already paid to Employee under Section 4.01.

Section 4.03. Remedies (No Injunctive Relief). Employee acknowledges that a violation by him of any of the covenants contained in this Agreement would cause irreparable damage to Company Group in an amount that would be material and readily ascertainable. Accordingly, Employee agrees that, notwithstanding any provision of this Agreement to which it is appended to the contrary, in the event of a violation by Employee of any of the covenants contained in this Agreement, Company Group shall be entitled (without the necessity of showing economic loss or other actual damage) to (i) cease payment of the compensation and benefits contemplated by this Agreement, to the extent not previously paid or provided, and (ii) the prompt return by Employee of any compensation previously paid or provided under Section 4.01. The preceding sentence shall be the Company’s only remedy for breach. In the event that a court of competent jurisdiction determines that any provision of this Agreement is invalid or more restrictive than permitted under the governing law of such jurisdiction, then, only as to enforcement of this Agreement within the jurisdiction of such court, such provision shall be interpreted and enforced as if it provided for the maximum restriction permitted under such governing law.

Section 4.04. Reasonable Limitations; Acknowledgment. Employee acknowledges and agrees that the scope of the provisions set forth in this Agreement, including but not limited to, the scope of activities prohibited and the time limitations provided therein, are acceptable and reasonable, and Employee is in full agreement with all of such provisions and willing to be abide by such provisions. Employee further acknowledges that: (i) the amount of Employee’s compensation reflects Employee’s obligations and Company Group’s rights under this Agreement; (ii) Employee has no expectation of any additional compensation, royalties, or other payment of any kind not otherwise referenced herein in connection herewith; and (iii) Employee will not be subject to undue hardship by reason of Employee’s full compliance with the terms and conditions of this Agreement or Company’s enforcement thereof.

ARTICLE V

MISCELLANEOUS

Section 5.01. Agreement Enforceable Upon Material Job Change. Employee acknowledges and agrees that if Employee should transfer between or among any affiliates of Company, wherever situated, or be promoted, demoted, reassigned to functions other than Employee’s present functions, or have Employee’s job duties changed, altered, or modified in any way, all terms of this Agreement shall continue to apply with full force.

7    

APPENDIX A Exhibit 10.1

Section 5.02. Notices. All notices, requests, consents, and other communications hereunder will be in writing, will be addressed to the receiving party’s address set forth below, or to such other address as a party may designate by notice hereunder, and will be either delivered by hand, sent by overnight courier, or sent by registered mail, return receipt requested, postage prepaid. All notices, requests, consents, and other communications hereunder will be deemed to have been given either (i) if by hand, at the time of the delivery thereof to the receiving party at the address of such party set forth below, (ii) if sent by overnight courier, on the next business day following the day such notice is delivered to the courier service, or (iii) if sent by registered mail, on the fifth business day following the day such mailing is made.

If to Company, addressed to it at:

ConocoPhillips

925 N. Eldridge Parkway

Houston, Texas 77079

Telephone: 281-293-2029

Fax: 918-662-8757

Attention: General Counsel

If to Employee, to his most recent address on file with Company

Section 5.03. Cooperation. During Employee’s Service and thereafter, Employee shall cooperate with Company Group and be reasonably available to Company Group with respect to continuing and/or future matters related to Employee’s Service period, whether such matters are business-related, legal, regulatory, or otherwise (including, without limitation, Employee appearing at Company’s request to give testimony without requiring service of a subpoena or other legal process, volunteering to Company Group all pertinent information and turning over to Company Group all relevant documents which are or may come into Employee’s possession). Following Employee’s termination of Service, Company Group shall reimburse Employee for all reasonable out of pocket expenses incurred by Employee in rendering such services that are approved by Company Group.

Section 5.04. Entire Agreement. This Agreement embodies the entire agreement and understanding between the parties hereto with respect to the subject matter hereof and supersedes all prior oral or written agreements and understandings relating to the subject matter hereof. No statement, representation, warranty, covenant, or agreement of any kind not expressly set forth in this Agreement will affect, or be used to interpret, change, or restrict, the express terms and provisions of this Agreement.

Section 5.05. Modifications and Amendments. The terms and provisions of this Agreement may be modified or amended only by written agreement executed by the Parties.

Section 5.06. Waivers and Consents. The terms and provisions of this Agreement may be waived, or consent for the departure therefrom granted, only by written document executed by the Party waiving or consenting to such terms or provisions. No such waiver or consent will be deemed to be or will constitute a waiver or consent with respect to any other terms or provisions of this Agreement, whether or not similar. Each such waiver or consent will be effective only in the specific instance and for the purpose for which it was given, and will not constitute a continuing waiver or consent.

Section 5.07. Benefit. All statements, representations, warranties, covenants, and agreements in this Agreement will be binding on the Parties and will inure to the benefit of the respective successors and permitted assigns of each Party. Nothing in this Agreement will be construed to create any rights or obligations except between Company Group and Employee, and no person or entity outside of Company Group will be regarded as a third-party beneficiary of this Agreement.

Section 5.08. Governing Law. This Agreement shall be deemed to have been made in the State of Texas, and the validity, interpretation, and performance of this Agreement shall be governed by, and construed in accordance with, the internal law of Texas, without giving effect to conflict of law principles, and specifically excluding any conflict or choice of law rule or principle that might otherwise refer construction or interpretation of this Agreement to the substantive law of another jurisdiction.

Section 5.09. Waiver of Jury Trial. Any action, demand, claim, or counterclaim arising under or relating to this Agreement will be resolved by a judge alone and each of Company and Employee waives any right to a jury trial thereof.

8    

APPENDIX A Exhibit 10.1

Section 5.10. Severability. The parties intend this Agreement to be enforced as written. However, (i) if any portion or provision of this Agreement is to any extent declared illegal or unenforceable by a duly-authorized court having jurisdiction, then the remainder of this Agreement, or the application of such portion or provision in circumstances other than those as to which it is so declared illegal or unenforceable, will not be affected thereby, and each portion and provision of this Agreement will be valid and enforceable to the fullest extent permitted by law, and (ii) if any provision, or part thereof, is held to be unenforceable because of the duration of such provision or the geographic area covered thereby, the court making such determination will have the power to reduce the duration and/or geographic area of such provision, and/or to delete specific words and phrases (“blue-pencilling”), and in its reduced or blue-pencilled form such provision will then be enforceable and will be enforced.

Section 5.11. Headings and Captions. The headings and captions of the various subdivisions of this Agreement are for convenience of reference only and will in no way modify or affect the meaning or construction of any of the terms or provisions hereof.

Section 5.12. No Waiver of Rights, Powers, and Remedies. No failure or delay by a Party in exercising any right, power, or remedy under this Agreement, and no course of dealing between the Parties or in any trade or industry, will operate as a waiver of any such right, power, or remedy of the Party. No single or partial exercise of any right, power, or remedy under this Agreement by a party hereto, nor any abandonment or discontinuance of steps to enforce any such right, power, or remedy, will preclude such Party from any other or further exercise thereof or the exercise of any other right, power, or remedy hereunder. The election of any remedy by a Party will not constitute a waiver of the right of such Party to pursue other available remedies. No notice to or demand on a Party not expressly required under this Agreement will entitle the party receiving such notice or demand to any other or further notice or demand in similar or other circumstances or constitute a waiver of the rights of the Party giving such notice or demand to any other or further action in any circumstances without such notice or demand.

Section 5.13. Employment at Will. Employee understands that neither this Agreement nor any other document that Employee has signed with Company Group constitutes an implied or written employment contract or guarantee of continued employment and that Employee’s employment with Company Group is on an “at-will” basis.

Section 5.14. Counterparts. This Agreement may be executed in two or more counterparts, and by different Parties hereto on separate counterparts, each of which will be deemed an original, but all of which together will constitute one and the same instrument.

Section 5.15. Opportunity to Review. Employee hereby acknowledges that Employee has had adequate opportunity to review these terms and conditions and to reflect upon and consider the terms and conditions of this Agreement, and that Employee has had the opportunity to consult with counsel.

Section 5.16. Survival. This entire Agreement, and Employee’s obligations hereunder, shall survive any termination or cessation of Employee’s Service with Company Group (for any or no reason).

IN WITNESS WHEREOF, the parties have executed this Agreement on the date and in the place first written above.

EMPLOYEE

Timothy A. Leach

CONOCOPHILLIPS

By: Ryan M. Lance

Title: Chairman and Chief Executive Officer

9    

EX-31.1

Exhibit 31.1

CERTIFICATION

I, Ryan M. Lance, certify that:

1.I have reviewed this quarterly report on Form 10-Q of ConocoPhillips;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

August 4, 2022

/s/ Ryan M. Lance

Ryan M. Lance

Chairman and

Chief Executive Officer

EX-31.2

Exhibit 31.2

CERTIFICATION

I, William L. Bullock, Jr., certify that:

1.I have reviewed this quarterly report on Form 10-Q of ConocoPhillips;

2.Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3.Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4.The registrant’s other certifying officer and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a)Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b)Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c)Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d)Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5.The registrant’s other certifying officer and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a)All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b)Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

August 4, 2022

/s/ William L. Bullock, Jr.

William L. Bullock, Jr.

Executive Vice President and

Chief Financial Officer

EX-32

Exhibit 32

CERTIFICATIONS PURSUANT TO 18 U.S.C. SECTION 1350

In connection with the Quarterly Report of ConocoPhillips (the Company) on Form 10-Q for the period ended June 30, 2022, as filed with the U.S. Securities and Exchange Commission on the date hereof (the Report), each of the undersigned hereby certifies, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that to their knowledge:

(1)The Report fully complies with the requirements of Sections 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2)The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

August 4, 2022

/s/ Ryan M. Lance

Ryan M. Lance

Chairman and

Chief Executive Officer

/s/ William L. Bullock, Jr.

William L. Bullock, Jr.

Executive Vice President and

Chief Financial Officer

XML

Cover	6 Months Ended
	Jun. 30, 2022 shares
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Transition Report	false
Entity Registrant Name	ConocoPhillips
Document Period End Date	Jun. 30, 2022
Document Fiscal Year Focus	2022
Document Fiscal Period Focus	Q2
Current Fiscal Year End Date	--12-31
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 Current Reporting Status	Yes
Entity Interactive Data Current	Yes
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding	1,273,033,365
Entity Central Index Key	0001163165
Amendment Flag	false
Entity File Number	001-32395
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

XML

Consolidated Income Statement - USD ($) shares in Thousands, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Revenues and Other Income
Sales and other operating revenues	$ 21,161	$ 9,556	$ 38,923	$ 19,382
Equity in earnings of affiliates	524	139	950	261
Gain on dispositions	262	59	1,079	292
Other income	42	457	328	835
Total Revenues and Other Income	21,989	10,211	41,280	20,770
Costs and Expenses
Purchased commodities	9,234	2,998	15,985	7,481
Production and operating expenses	1,741	1,379	3,322	2,762
Selling, general and administrative expenses	96	117	283	428
Exploration expenses	143	57	212	141
Depreciation, depletion and amortization	1,810	1,867	3,633	3,753
Impairments	2	2	4	(1)
Taxes other than income taxes	1,020	381	1,834	751
Accretion on discounted liabilities	61	63	122	125
Interest and debt expense	211	220	428	446
Foreign currency transaction (gain) loss	(70)	10	(46)	29
Other expenses	86	37	(50)	61
Total Costs and Expenses	14,334	7,131	25,727	15,976
Income before income taxes	7,655	3,080	15,553	4,794
Income tax provision	2,510	989	4,649	1,721
Net Income	$ 5,145	$ 2,091	$ 10,904	$ 3,073
Net Income Per Share of Common Stock (dollars)
Basic (in dollars per share)	$ 3.98	$ 1.55	$ 8.39	$ 2.32
Diluted (in dollars per share)	$ 3.96	$ 1.55	$ 8.36	$ 2.31
Average Common Shares Outstanding (in thousands)
Basic (in shares)	1,289,791	1,348,637	1,295,827	1,324,639
Diluted (in shares)	1,295,844	1,353,201	1,301,126	1,329,507

XML

Consolidated Statement of Comprehensive Income - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Statement of Comprehensive Income [Abstract]
Net Income	$ 5,145	$ 2,091	$ 10,904	$ 3,073
Defined benefit plans
Reclassification adjustment for amortization of prior service credit included in net income	(10)	(10)	(20)	(19)
Net change	(10)	(10)	(20)	(19)
Net actuarial gain (loss) arising during the period	(82)	30	(82)	105
Reclassification adjustment for amortization of net actuarial losses included in net income	25	63	41	88
Net change	(57)	93	(41)	193
Income taxes on defined benefit plans	14	(19)	12	(40)
Defined benefit plans, net of tax	(53)	64	(49)	134
Unrealized holding loss on securities	(5)	0	(9)	(1)
Income taxes on unrealized holding loss on securities	1	0	2	0
Unrealized holding loss on securities, net of tax	(4)	0	(7)	(1)
Foreign currency translation adjustments	(448)	96	(307)	165
Foreign currency translation adjustments, net of tax	(448)	96	(307)	165
Other Comprehensive Income (Loss), Net of Tax	(505)	160	(363)	298
Comprehensive Income	$ 4,640	$ 2,251	$ 10,541	$ 3,371

XML

Consolidated Balance Sheet - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Assets
Cash and cash equivalents	$ 6,909	$ 5,028
Short-term investments	1,272	446
Accounts and notes receivable (net of allowance of $2 and $2, respectively)	8,081	6,543
Accounts and notes receivable—related parties	72	127
Investment in Cenovus Energy	0	1,117
Inventories	1,234	1,208
Prepaid expenses and other current assets	1,292	1,581
Total Current Assets	18,860	16,050
Investments and long-term receivables	8,203	7,113
Net properties, plants and equipment (net of accumulated DD&A of $65,212 and $64,735, respectively)	64,008	64,911
Other assets	2,622	2,587
Total Assets	93,693	90,661
Liabilities
Accounts payable	5,845	5,002
Accounts payable—related parties	28	23
Short-term debt	676	1,200
Accrued income and other taxes	2,759	2,862
Employee benefit obligations	529	755
Other accruals	2,379	2,179
Total Current Liabilities	12,216	12,021
Long-term debt	16,295	18,734
Asset retirement obligations and accrued environmental costs	5,737	5,754
Deferred income taxes	6,694	6,179
Employee benefit obligations	1,080	1,153
Other liabilities and deferred credits	1,469	1,414
Total Liabilities	43,491	45,255
Equity
Common stock	21	21
Capital in excess of par	61,045	60,581
Treasury stock (at cost: 2022—826,994,049 shares; 2021—789,319,875 shares)	(54,644)	(50,920)
Accumulated other comprehensive loss	(5,313)	(4,950)
Retained earnings	49,093	40,674
Total Equity	50,202	45,406
Total Liabilities and Equity	$ 93,693	$ 90,661

XML

Consolidated Balance Sheet (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Statement of Financial Position [Abstract]
Allowance for accounts and notes receivable	$ 2	$ 2
Accumulated depreciation, depletion and amortization	$ 65,212	$ 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)	2,100,027,414	2,091,562,747
Treasury stock, shares (in shares)	826,994,049	789,319,875

XML

Consolidated Statement of Cash Flows - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022		Jun. 30, 2021
Cash Flows From Operating Activities
Net Income	$ 10,904		$ 3,073
Adjustments to reconcile net income to net cash provided by operating activities
Depreciation, depletion and amortization	3,633		3,753
Impairments	4		(1)
Dry hole costs and leasehold impairments	104		7
Accretion on discounted liabilities	122		125
Deferred taxes	868		567
Undistributed equity earnings	591		317
Gain on dispositions	(1,079)		(292)
Gain on investment in Cenovus Energy	(251)		(726)
Other	(37)		(688)
Working capital adjustments
Increase in accounts and notes receivable	(1,861)		(794)
Increase in inventories	(53)		(89)
Increase in prepaid expenses and other current assets	(283)		(388)
Increase in accounts payable	635		323
Increase (decrease) in taxes and other accruals	(315)		1,144
Net Cash Provided by Operating Activities	12,982		6,331
Cash Flows From Investing Activities
Capital expenditures and investments	(5,129)		(2,465)
Working capital changes associated with investing activities	496		2
Acquisition of businesses, net of cash acquired	37		382
Proceeds from asset dispositions	2,951		160
Net (purchase) sale of investments	(1,104)		1,302
Collection of advances/loans—related parties	55		52
Other	(8)		86
Net Cash Used in Investing Activities	(2,702)		(481)
Cash Flows From Financing Activities
Issuance of debt	2,897		0
Repayment of debt	(5,829)		(44)
Issuance of company common stock	350		(25)
Repurchase of company common stock	(3,725)		(981)
Dividends paid	(1,852)		(1,171)
Other	(56)		3
Net Cash Used in Financing Activities	(8,215)		(2,218)
Effect of Exchange Rate Changes on Cash, Cash Equivalents and Restricted Cash	(237)		9
Net Change in Cash, Cash Equivalents and Restricted Cash	1,828		3,641
Cash, cash equivalents and restricted cash at beginning of period	5,398	[1]	3,315
Cash, Cash Equivalents and Restricted Cash at End of Period	$ 7,226	[2]	$ 6,956

[1] Restricted cash of $152 million and $218 million are 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 $317 million is included in the "Other assets" line of our Consolidated Balance Sheet as of June 30, 2022.

XML

Consolidated Statement of Cash Flows (Parenthetical) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Prepaid expenses and other current assets
Restricted cash		$ 152
Other Assets
Restricted cash	$ 317	$ 218

XML

Basis of Presentation

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

Note 1—Basis of Presentation

The interim-period financial information presented in the financial statements included in this report is unaudited and, in the opinion of management, includes all known accruals and adjustments necessary for a fair presentation of the consolidated financial position of ConocoPhillips, its results of operations and cash flows for such periods. All such adjustments are of a normal and recurring nature unless otherwise disclosed. Certain notes and other information have been condensed or omitted from the interim financial statements included in this report. Therefore, these financial statements should be read in conjunction with the consolidated financial statements and notes included in our 2021 Annual Report on Form 10-K.

XML

Inventories

6 Months Ended

Jun. 30, 2022

Inventory Disclosure [Abstract]

Inventories

Note 2—Inventories

	Millions of Dollars
	June 30 2022		December 31 2021
Crude oil and natural gas	$	653	647
Materials and supplies	581		561
Total Inventories	$	1,234	1,208
Inventories valued on the LIFO basis	$	326	395

XML

Acquisitions and Dispositions

6 Months Ended

Jun. 30, 2022

Business Combination, Asset Acquisition And Dispositions [Abstract]

Acquisitions and Dispositions

Note 3—Acquisitions and Dispositions

Acquisition of Shell Enterprise LLC's (Shell) Permian Assets

In December 2021, we completed our acquisition of Shell's assets in the Permian based Delaware Basin in an all-cash transaction for $8.6 billion after customary adjustments. Assets acquired include approximately 225,000 net acres and producing properties located entirely in Texas. The acquisition was accounted for as a business combination 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.

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.

Supplemental Pro Forma (unaudited)

The following table summarizes the unaudited supplemental pro forma financial information for the three- and six-month periods ended June 30, 2021, as if we had completed the acquisition of Shell's Permian assets on January 1, 2020:

	Millions of Dollars
	Three Months Ended June 30, 2021				Six Months Ended June 30, 2021
Supplemental Pro Forma (unaudited)	As Reported		Pro forma Shell	Pro forma Combined	As Reported	Pro forma Shell	Pro forma Combined
Total Revenues and Other Income	10,211		799	11,010	20,770	1,395	22,165
Income before income taxes	3,080		297	3,377	4,794	416	5,210
Net Income	2,091		227	2,318	3,073	318	3,391
Earnings per share ($ per share):
Basic net income	$	1.55		1.71	2.32		2.56
Diluted net income	1.55			1.71	2.31		2.55

The unaudited supplemental pro forma financial information is presented for illustration and comparative purposes only and is not necessarily indicative of the operating results that would have occurred had the transaction 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 three- and six-month periods ended June 30, 2021, is a result of combining the consolidated income statement of ConocoPhillips with the results of 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 transaction. The pro forma results include adjustments made 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.

Acquisition of Concho Resources Inc. (Concho)

In January 2021, we completed our acquisition of Concho, an independent oil and gas exploration and production company in an all-stock transaction. In conjunction with this acquisition, we commenced, and completed in 2021, a company-wide restructuring program, the scope of which included combining the operations of the two companies as well as other global restructuring activities for which we recognized non-recurring restructuring and transaction costs. Further information regarding the Concho acquisition can be found in the following footnotes: Note 7—Changes in Equity; Note 9—Contingencies and Commitments; Note 10—Derivative and Financial Instruments; and Note 13—Cash Flow Information and should be read in conjunction with the notes included in our Annual Report on Form 10-K.

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 increases our ownership in APLNG to 47.5 percent, with Origin Energy and Sinopec owning

27.5 percent and 25 percent, respectively. APLNG is reported as an equity investment in our Asia Pacific segment.

Assets Sold

In April 2022, we sold our interests in certain noncore assets in the Lower 48 segment for net proceeds of $370 million and recognized a $80 million before-tax and $63 million after-tax gain. At the time of disposition, our interests in these assets had a net carrying value of $290 million, consisting primarily of $401 million of PP&E and $111 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 $264 million for the six-month period ended June 30, 2022 and 2021, respectively. Results of operations for the Indonesia interests sold were reported in our Asia Pacific segment.

For the three- and six-months ended June 30, 2022, we recorded contingent payments of $174 million and $424 million, respectively, relating to the previous dispositions of our interest in the Foster Creek Christina Lake Partnership and western Canada gas assets as well as our San Juan assets. The contingent payments are recorded as gain on disposition in our consolidated income statement and are reflected within our Canada and Lower 48 segments. For the three- and six-months ended June 30, 2021, we recorded contingent payments of $68 million and $94 million, respectively.

Planned Dispositions

In July 2022, we entered into agreements to sell our interests in certain noncore assets in the Lower 48 segment for $265 million, before customary adjustments. These transactions are expected to close in the third quarter of 2022.

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Investments, Loans and Long-Term Receivables

6 Months Ended

Jun. 30, 2022

Equity Method Investments and Joint Ventures [Abstract]

Investments, Loans and Long-Term Receivables

Note 4—Investments, Loans and Long-Term Receivables

APLNG

APLNG executed project agreements for an $8.5 billion project finance facility in 2012 which became non-recourse following financial completion in 2017. Following restructuring efforts, 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 June 30, 2022, a balance of $5.5 billion was outstanding on these facilities.

See Note 8.

In February 2022, we completed the acquisition of an additional 10 percent interest in APLNG from Origin Energy for approximately $1.4 billion resulting from the exercise of our preemption right. This increases our ownership in APLNG to 47.5 percent, with Origin Energy and Sinopec owning 27.5 percent and 25 percent, respectively.

At June 30, 2022, the carrying value of our equity method investment in APLNG was $6.4 billion. The balance is included in the “Investments and long-term receivables” line on our consolidated balance sheet.

Loans

As part of our normal ongoing business operations, we enter into numerous agreements with other parties to pursue business opportunities. Included in such activity are loans made to certain affiliated and non-affiliated companies. At June 30, 2022, significant loans to affiliated companies included $59 million in project financing to Qatar Liquefied Gas Company Limited (3), which is included within the “Accounts and notes receivable—related parties” line on our consolidated balance sheet.

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Investment in Cenovus Energy

6 Months Ended

Jun. 30, 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% of their issued and outstanding common shares. 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” 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 11.

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022		2021
Total Net gain on equity securities	$	—	418	251		726
Less: Net gain on equity securities sold during the period	—		31	251		60
Unrealized gain on equity securities still held at the reporting date	$	—	387	$	—	666

XML

Debt

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

Debt

Note 6—Debt

	Millions of Dollars
	June 30 2022		December 31 2021
2.4% Notes due 2022	$	329	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
2.4% 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% 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	645		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% – 1.09% during 2022 and 0.04% – 0.15% during 2021	265		265
Industrial Development Bonds due 2035 at 0.07% – 1.09% during 2022 and 0.04% – 0.12% during 2021	18		18
Other	33		35
Debt at face value	16,208		17,766
Finance leases	1,284		1,261
Net unamortized premiums, discounts and debt issuance costs	(521)		907
Total debt	16,971		19,934
Short-term debt	(676)		(1,200)
Long-term debt	$	16,295	18,734

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% 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

On March 8, 2022, we issued the following new notes consisting of:

•2.125% Notes due 2024 with principal of $900 million

•2.4% Notes due 2025 with principal of $900 million

•3.8% Notes 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 rates offered by certain designated banks in the London interbank market or at a margin above the overnight federal funds rate or prime rates offered by certain designated banks in the U.S. The 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 June 30, 2022. At December 31, 2021, we had no commercial paper outstanding and no direct borrowings or letters of credit issued.

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: “A3” with a “positive” 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 June 30, 2022, 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.

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Changes in Equity

6 Months Ended

Jun. 30, 2022

Stockholders' Equity Note [Abstract]

Changes in Equity

Note 7—Changes in Equity

	Millions of Dollars
	Common Stock
	Par Value		Capital in Excess of Par	Treasury Stock	Accum. Other Comprehensive Income (Loss)	Retained Earnings	Total
For the three months ended June 30, 2022
Balances at March 31, 2022	$	21	60,907	(52,344)	(4,808)	45,442	49,218
Net income						5,145	5,145
Other comprehensive income					(505)		(505)
Dividends declared
Ordinary ($0.46 per common share)						(598)	(598)
Variable return of cash ($0.70 per common share)						(896)	(896)
Repurchase of company common stock				(2,300)			(2,300)
Distributed under benefit plans			138				138
Other							—
Balances at June 30, 2022	$	21	61,045	(54,644)	(5,313)	49,093	50,202
For the six months ended June 30, 2022
Balances at December 31, 2021	$	21	60,581	(50,920)	(4,950)	40,674	45,406
Net income						10,904	10,904
Other comprehensive income					(363)		(363)
Dividends declared
Ordinary ($0.92 per common share)						(1,201)	(1,201)
Variable return of cash ($1.00 per common share)						(1,286)	(1,286)
Repurchase of company common stock				(3,725)			(3,725)
Distributed under benefit plans			464				464
Other				1		2	3
Balances at June 30, 2022	$	21	61,045	(54,644)	(5,313)	49,093	50,202

	Millions of Dollars
	Common Stock
	Par Value		Capital in Excess of Par	Treasury Stock	Accum. Other Comprehensive Income (Loss)	Retained Earnings	Total
For the three months ended June 30, 2021
Balances at March 31, 2021	$	21	60,278	(47,672)	(5,080)	35,608	43,155
Net income						2,091	2,091
Other comprehensive income					160		160
Dividends declared
Ordinary ($0.43 per common share)						(583)	(583)
Repurchase of company common stock				(606)			(606)
Distributed under benefit plans			59				59
Balances at June 30, 2021	$	21	60,337	(48,278)	(4,920)	37,116	44,276
For the six months ended June 30, 2021
Balances at December 31, 2020	$	18	47,133	(47,297)	(5,218)	35,213	29,849
Net income						3,073	3,073
Other comprehensive loss					298		298
Dividends declared
Ordinary ($0.86 per common share)						(1,171)	(1,171)
Acquisition of Concho	3		13,122				13,125
Repurchase of company common stock				(981)			(981)
Distributed under benefit plans			82				82
Other						1	1
Balances at June 30, 2021	$	21	60,337	(48,278)	(4,920)	37,116	44,276

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Guarantees

6 Months Ended

Jun. 30, 2022

Guarantees [Abstract]

Guarantees

Note 8—Guarantees

At June 30, 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 June 30, 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 June 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 is 9 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 June 30, 2022, the carrying value of this guarantee was $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 $820 million ($1.4 billion in the event of intentional or reckless breach) and would become payable if APLNG fails to meet its obligations under these agreements and the obligations cannot otherwise be mitigated. Future payments are considered unlikely, as the payments, or cost of volume delivery, would only be triggered if APLNG does not have enough natural gas to meet these sales commitments and if the co-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 15 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 June 30, 2022, the carrying value of these guarantees was approximately $20 million.

Other Guarantees

We have other guarantees with maximum future potential payment amounts totaling approximately $720 million, which consist primarily of guarantees of the residual value of leased office buildings, guarantees of the residual value of corporate aircrafts, and a guarantee for our portion of a joint venture’s project finance reserve accounts. These guarantees have remaining terms of one to five years and would become payable if certain asset values are lower than guaranteed amounts at the end of the lease or contract term, business conditions decline at guaranteed entities, or as a result of nonperformance of contractual terms by guaranteed parties. At June 30, 2022, the carrying value of these guarantees was $8 million.

Indemnifications

Over the years, we have entered into agreements to sell ownership interests in certain legal entities, joint ventures and assets that gave rise to qualifying indemnifications. These agreements include indemnifications for taxes and environmental liabilities. The carrying amount recorded for these indemnification obligations at June 30, 2022, was

$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 9 for additional information about environmental liabilities.

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Contingencies and Commitments

6 Months Ended

Jun. 30, 2022

Commitments and Contingencies Disclosure [Abstract]

Contingencies and Commitments

Note 9—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.

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.

At June 30, 2022, our balance sheet included a total environmental accrual of $178 million, compared with $187 million at December 31, 2021, for remediation activities in the U.S. and Canada. We expect to incur a substantial amount of these expenditures within the next 30 years. In the future, we may be involved in additional environmental assessments, cleanups and proceedings.

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 June 30, 2022, we had performance obligations secured by letters of credit of $320 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.

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 $771 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 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. 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 is challenging the BSEE order but 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 final investment decision 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.

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Derivative and Financial Instruments

6 Months Ended

Jun. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Derivative and Financial Instruments

Note 10—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
	June 30 2022		December 31 2021
Assets
Prepaid expenses and other current assets	$	1,790	1,168
Other assets	262		75
Liabilities
Other accruals	1,824		1,160
Other liabilities and deferred credits	232		63

The gains (losses) from commodity derivatives incurred and the line items where they appear on our consolidated income statement were:

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Sales and other operating revenues	$	(13)	(100)	(420)	(379)
Other income	1		(1)	2	16
Purchased commodities	(55)		132	346	145

During the first quarter of 2021, we recognized a $305 million loss on settlement of derivative contracts acquired through the Concho transaction. This loss is recorded within the “Sales and other operating revenues” line on our consolidated income statement. In connection with this settlement, we issued a cash payment of $692 million in the first quarter of 2021 and $69 million in the second quarter of 2021 which are included within “Cash Flows From Operating Activities” on our consolidated statement of cash flows.

The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts:

	Open Position Long (Short)
	June 30 2022	December 31 2021
Commodity
Natural gas and power (billions of cubic feet equivalent)
Fixed price	(14)	4
Basis	(1)	(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 June 30, 2022, and December 31, 2021:

	Millions of Dollars
	Carrying Amount
	Cash and Cash Equivalents			Short-Term Investments
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Cash	$	505	670
Demand Deposits	1,690		1,554
Time Deposits
1 to 90 days	4,555		2,363	524	217
91 to 180 days				112	4
Within one year				47	4
One year through five years
U.S. Government Obligations
1 to 90 days	39		431	—	—
	$	6,789	5,018	683	225

The following investments in debt securities classified as available for sale are carried at fair value on our consolidated balance sheet at June 30, 2022 and December 31, 2021:

	Millions of Dollars
	Carrying Amount
	Cash and Cash Equivalents			Short-Term Investments		Investments and Long-Term Receivables
	June 30 2022		December 31 2021	June 30 2022	December 31 2021	June 30 2022	December 31 2021
Major Security Type
Corporate Bonds	$	—	3	299	128	298	173
Commercial Paper	120		7	215	82
U.S. Government Obligations	—		—	68	—	94	2
U.S. Government Agency Obligations				5	2	5	8
Foreign Government Obligations				2	7	4	2
Asset-backed Securities				—	2	100	63
	$	120	10	589	221	501	248

Cash and Cash Equivalents and Short-Term Investments have remaining maturities within one year.

Investments and Long-Term Receivables have remaining maturities greater than one year through seven years.

The following table summarizes the amortized cost basis and fair value of investments in debt securities classified as available for sale:

	Millions of Dollars
	Amortized Cost Basis			Fair Value
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Major Security Type
Corporate Bonds	$	604	305	597	304
Commercial Paper	335		88	335	89
U.S. Government Obligations	163		2	162	2
U.S. Government Agency Obligations	10		10	10	10
Foreign Government Obligations	6		9	6	9
Asset-backed Securities	100		65	100	65
	$	1,218	479	1,210	479

As of June 30, 2022 and December 31, 2021, total unrealized losses for debt securities classified as available for sale with net losses were negligible. Additionally, as of June 30, 2022 and December 31, 2021, investments in these debt securities in an unrealized loss position for which an allowance for credit losses has not been recorded were negligible.

For the three- and six-month periods ended June 30, 2022, proceeds from sales and redemptions of investments in debt securities classified as available for sale were $86 million and $201 million, respectively. For the three- and six-month periods ended June 30, 2021, proceeds from sales and redemptions of investments in debt securities classified as available for sale were $173 million and $320 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, and foreign government obligations.

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 oil and gas 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.

The aggregate fair value of all derivative instruments with such credit risk-related contingent features that were in a liability position at June 30, 2022 and December 31, 2021 was $326 million and $281 million, respectively. For these instruments, collateral posted at June 30, 2022 was $6 million and no collateral was posted at December 31, 2021. If our credit rating had been downgraded below investment grade at June 30, 2022, we would have been required to post

$238 million of additional collateral, either with cash or letters of credit.

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Fair Value Measurement

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Fair Value Measurement

Note 11—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 the six-month period ended June 30, 2022, nor during the year ended December 31, 2021.

Recurring Fair Value Measurement

Financial assets and liabilities reported at fair value on a recurring basis includes 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
	June 30, 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	162		1,048	—	1,210	2	477	—	479
Commodity derivatives	957		1,037	58	2,052	562	619	62	1,243
Total assets	$	1,119	2,085	58	3,262	1,681	1,096	62	2,839
Liabilities
Commodity derivatives	$	1,004	867	185	2,056	593	543	87	1,223
Total liabilities	$	1,004	867	185	2,056	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 Recognized		Amounts Not Subject to Right of Setoff	Gross Amounts	Gross Amounts Offset	Net Amounts Presented	Cash Collateral	Net Amounts
June 30, 2022
Assets	$	2,052	27	2,025	1,302	723	—	723
Liabilities	2,056		16	2,040	1,302	738	48	690
December 31, 2021
Assets	$	1,243	85	1,158	650	508	—	508
Liabilities	1,223		82	1,141	650	491	36	455

At June 30, 2022 and December 31, 2021, we did not present any amounts gross on our consolidated balance sheet where we had the right of setoff.

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 5 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 10.

•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 4.

•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
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Financial assets
Investment in CVE common shares	$	—	1,117	—	1,117
Commodity derivatives	750		593	750	593
Investments in debt securities	1,210		479	1,210	479
Loans and advances—related parties	59		114	59	114
Financial liabilities
Total debt, excluding finance leases	15,687		18,673	16,547	22,451
Commodity derivatives	706		537	706	537

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Accumulated Other Comprehensive Loss

6 Months Ended

Jun. 30, 2022

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

Accumulated Other Comprehensive Loss

Note 12—Accumulated Other Comprehensive Loss

Accumulated other comprehensive loss in the equity section of our consolidated balance sheet includes:

	Millions of Dollars
	Defined Benefit Plans		Net Unrealized Loss on Securities	Foreign Currency Translation	Accumulated Other Comprehensive Loss
December 31, 2021	$	(31)	—	(4,919)	(4,950)
Other comprehensive loss	(49)		(7)	(307)	(363)
June 30, 2022	$	(80)	(7)	(5,226)	(5,313)

The following table summarizes reclassifications out of accumulated other comprehensive loss and into net income (loss):

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Defined benefit plans	$	12	42	16	54

The above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of $3 million and $11 million for the three-month periods ended June 30, 2022 and June 30, 2021, respectively, and $5 million and $15 million for the six-month periods ended

June 30, 2022 and June 30, 2021, respectively. See Note 14.

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Cash Flow Information

6 Months Ended

Jun. 30, 2022

Supplemental Cash Flow Information [Abstract]

Cash Flow Information

Note 13—Cash Flow Information

	Millions of Dollars
	Six Months Ended June 30
Cash Payments	2022		2021
Interest	$	486	464
Income taxes	3,942		107
Net Sales (Purchases) of Investments
Short-term investments purchased	$	(1,253)	(5,439)
Short-term investments sold	613		6,842
Long-term investments purchased	(510)		(149)
Long-term investments sold	46		48
	$	(1,104)	1,302

In the first quarter of 2021, we acquired Concho in an all-stock transaction for $13.1 billion. In connection with this transaction, we acquired cash of $382 million, which is included in "Cash Flows From Investing Activities" on our consolidated statement of cash flows.

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Employee Benefit Plans

6 Months Ended

Jun. 30, 2022

Retirement Benefits [Abstract]

Employee Benefit Plans

Note 14—Employee Benefit Plans

Pension and Postretirement Plans

	Millions of Dollars
	Pension Benefits					Other Benefits
	2022			2021		2022	2021
	U.S.		Int'l.	U.S.	Int'l.
Components of Net Periodic Benefit Cost
Three Months Ended June 30
Service cost	$	16	13	18	16	1	1
Interest cost	12		21	15	20	1	1
Expected return on plan assets	(13)		(34)	(20)	(30)	—	—
Amortization of prior service credit	—		—	—	—	(10)	(10)
Recognized net actuarial loss	5		2	12	8	—	1
Settlements	18		—	42	—	—	—
Net periodic benefit cost	$	38	2	67	14	(8)	(7)
Six Months Ended June 30
Service cost	$	32	26	39	31	1	1
Interest cost	24		42	28	40	2	2
Expected return on plan assets	(26)		(68)	(44)	(60)	—	—
Amortization of prior service credit	—		—	—	—	(20)	(19)
Recognized net actuarial loss	11		4	27	16	—	1
Settlements	22		—	44	—	—	—
Curtailments	—		—	12	—	—	—
Special Termination Benefits	—		—	9	—	—	—
Net periodic benefit cost	$	63	4	115	27	(17)	(15)

The components of net periodic benefit cost, other than the service cost component, are included in the "Other expenses" line of our consolidated income statement.

During the first six months of 2022, we contributed $44 million to our domestic benefit plans and $77 million to our international benefit plans. We expect our total contributions in 2022 to be approximately $95 million to our domestic qualified and nonqualified pension and postretirement benefit plans and $90 million to our international qualified and nonqualified pension and postretirement benefit plans.

During the three-month period ended June 30, 2022, lump-sum benefit payments exceeded the sum of service and interest costs for the year for the U.S. qualified pension plan and a U.S. nonqualified supplemental retirement plan. As a result, we recognized a proportionate share of prior actuarial losses from other comprehensive income as pension settlement expense of $18 million. In conjunction with the recognition of pension settlement expense, the fair market values of the pension plan assets were updated and the pension benefit obligations of the U.S. qualified pension plan and the U.S. nonqualified supplemental retirement plan were remeasured at June 30, 2022. At the measurement date, the net pension liability increased by $82 million, primarily a result of lower than premised return on assets, partially offset by an increase in the discount rate, resulting in a corresponding decrease to other comprehensive income.

The relevant discount rates are summarized in the following table:

	June 30 2022		December 31 2021
Relevant discount rates
U.S. qualified pension plan	4.85	%	2.85
U.S. nonqualified pension plan	4.70		2.50

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Related Party Transactions

6 Months Ended

Jun. 30, 2022

Related Party Transactions [Abstract]

Related Party Transactions

Note 15—Related Party Transactions

Our related parties primarily include equity method investments and certain trusts for the benefit of employees.

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
Significant Transactions with Equity Affiliates	2022		2021	2022	2021
Operating revenues and other income	$	21	24	43	40
Purchases	—		3	—	3
Operating expenses and selling, general and administrative expenses	44		63	90	89
Net interest (income) expense*	$	—	—	(1)	(1)

*We paid interest to, or received interest from, various affiliates. See Note 4 for information related to loans to equity affiliates.

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Sales and Other Operating Revenues

6 Months Ended

Jun. 30, 2022

Revenue from Contract with Customer [Abstract]

Sales and Other Operating Revenues

Note 16—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
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from contracts with customers	$	16,728	7,753	31,234	14,914
Revenue from contracts outside the scope of ASC Topic 606
Physical contracts meeting the definition of a derivative	4,411		1,754	7,551	4,728
Financial derivative contracts	22		49	138	(260)
Consolidated sales and other operating revenues	$	21,161	9,556	38,923	19,382

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 17—Segment Disclosures and Related Information:

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from Outside the Scope of ASC Topic 606 by Segment
Lower 48	$	3,483	1,345	5,927	3,811
Canada	807		207	1,367	510
Europe, Middle East and North Africa	121		202	257	407
Physical contracts meeting the definition of a derivative	$	4,411	1,754	7,551	4,728

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from Outside the Scope of ASC Topic 606 by Product
Crude oil	$	64	178	283	302
Natural gas	4,254		1,504	7,027	4,231
Other	93		72	241	195
Physical contracts meeting the definition of a derivative	$	4,411	1,754	7,551	4,728

Practical Expedients

Typically, our commodity sales contracts are less than 12 months in duration; however, in certain specific cases they 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 June 30, 2022, the “Accounts and notes receivable” line on our consolidated balance sheet includes trade receivables of $6,554 million compared with $5,268 million at December 31, 2021, and includes 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 to 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.

	Millions of Dollars
Contract Liabilities
At December 31, 2021	$	50
Contractual payments received	25
Revenue recognized	(56)
At June 30, 2022	$	19
Amounts Recognized in the Consolidated Balance Sheet at June 30, 2022
Noncurrent liabilities	$	19

For the six-month period ended June 30, 2022, we recognized revenue of $56 million in the "Sales and other operating revenues" line on our consolidated income statement. No revenue was recognized during the three-month period ended June 30, 2022. We expect to recognize the contract liabilities as of June 30, 2022, as revenue during 2026.

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Segment Disclosures and Related Information

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Segment Disclosures and Related Information

Note 17—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 income and expense; premiums on early retirement of debt; corporate overhead and certain technology activities, including licensing revenues; and unrealized holding gains or losses on equity securities. Corporate assets include all cash and cash equivalents and short-term investments.

We evaluate performance and allocate resources based on net income (loss). Intersegment sales are at prices that approximate market.

Analysis of Results by Operating Segment

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Sales and Other Operating Revenues
Alaska	$	2,349	1,418	4,267	2,551
Lower 48	14,458		5,889	26,015	12,402
Intersegment eliminations	(6)		(2)	(13)	(4)
Lower 48	14,452		5,887	26,002	12,398
Canada	1,794		802	3,314	1,669
Intersegment eliminations	(726)		(352)	(1,377)	(657)
Canada	1,068		450	1,937	1,012
Europe, Middle East and North Africa	2,652		1,165	5,241	2,143
Asia Pacific	638		630	1,388	1,207
Other International	—		2	—	3
Corporate and Other	2		4	88	68
Consolidated sales and other operating revenues	$	21,161	9,556	38,923	19,382
Sales and Other Operating Revenues by Geographic Location(1)
United States	$	16,802	7,308	30,355	15,015
Canada	1,069		450	1,938	1,012
China	301		171	574	326
Indonesia	—		207	159	403
Libya	351		290	782	520
Malaysia	336		252	654	478
Norway	737		618	1,669	1,030
United Kingdom	1,564		257	2,790	593
Other foreign countries	1		3	2	5
Worldwide consolidated	$	21,161	9,556	38,923	19,382
Sales and Other Operating Revenues by Product
Crude oil	$	11,494	5,797	21,364	10,292
Natural gas	7,267		2,812	13,265	7,323
Natural gas liquids	1,042		325	1,921	562
Other(2)	1,358		622	2,373	1,205
Consolidated sales and other operating revenues by product	$	21,161	9,556	38,923	19,382

(1)Sales and other operating revenues are attributable to countries based on the location of the selling operation.

(2)Includes LNG and bitumen.

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income (Loss)
Alaska	$	687	371	1,271	530
Lower 48	3,581		1,175	6,371	1,643
Canada	316		102	607	112
Europe, Middle East and North Africa	385		207	797	360
Asia Pacific	525		175	1,661	492
Other International	—		(5)	—	(9)
Corporate and Other	(349)		66	197	(55)
Consolidated net income	$	5,145	2,091	10,904	3,073

	Millions of Dollars
	June 30 2022		December 31 2021
Total Assets
Alaska	$	14,835	14,812
Lower 48	43,478		41,699
Canada	7,358		7,439
Europe, Middle East and North Africa	8,406		9,125
Asia Pacific	9,997		9,840
Other International	4		1
Corporate and Other	9,615		7,745
Consolidated total assets	$	93,693	90,661

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Income Taxes

6 Months Ended

Jun. 30, 2022

Income Tax Disclosure [Abstract]

Income Taxes

Note 18—Income Taxes

Our effective tax rate for the three-month periods ended June 30, 2022 and 2021 was 32.8 percent and 32.1 percent, respectively, and our effective tax rate for the six-month periods ended June 30, 2022 and 2021 was 29.9 percent and 35.9 percent, respectively. Our effective tax rate for the first six-months of 2022 was impacted by the shift of income among our taxing jurisdictions, the release of tax reserves related to the closing of an IRS audit, a change to our valuation allowance, and the impact of the interest deduction related to our debt exchange, as described below.

In the first quarter of 2022, the IRS closed the 2017 audit of our U.S. 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.

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 quarter to reflect changes to our ability to realize certain deferred tax assets under the new law.

For the three- and six-month periods of 2022, our valuation allowance increased by $58 million and $5 million, respectively, compared to a decrease of $87 million and $151 million for the same periods of 2021. The increase in the three- and six-month periods of 2022 relate to the Norway tax law change described above. In addition, our six-month periods of 2022 and of 2021 include impacts from changes in our valuation allowance related to the fair value measurement of our CVE common shares and our expectation of the tax impact related to incremental capital gains and losses.

Our 2022 and 2021 effective tax rates were adversely impacted by $37 million and $75 million, respectively, due to incremental interest deductions from debt exchanges in both periods offsetting U.S. foreign source revenue that would otherwise have been offset by foreign tax credits. See Note 6.

The Company has ongoing income tax audits in a number of jurisdictions. The government agents in charge of these audits regularly request additional time to complete audits, which we generally grant, and conversely occasionally close audits unpredictably. Within the next twelve months we may have audit periods close that could significantly impact our total unrecognized tax benefits. The amount of such change is not estimable but could be significant when compared with our total unrecognized tax benefits.

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Basis of Presentation (Policy)

6 Months Ended

Jun. 30, 2022

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Basis of Presentation

The interim-period financial information presented in the financial statements included in this report is unaudited and, in the opinion of management, includes all known accruals and adjustments necessary for a fair presentation of the consolidated financial position of ConocoPhillips, its results of operations and cash flows for such periods. All such adjustments are of a normal and recurring nature unless otherwise disclosed. Certain notes and other information have been condensed or omitted from the interim financial statements included in this report. Therefore, these financial statements should be read in conjunction with the consolidated financial statements and notes included in our 2021 Annual Report on Form 10-K.

Practical Expedients

Practical Expedients

Typically, our commodity sales contracts are less than 12 months in duration; however, in certain specific cases they 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 and Contract Liabilities

Receivables from Contracts with Customers

At June 30, 2022, the “Accounts and notes receivable” line on our consolidated balance sheet includes trade receivables of $6,554 million compared with $5,268 million at December 31, 2021, and includes 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 to 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.

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Inventories (Tables)

6 Months Ended

Jun. 30, 2022

Inventory Disclosure [Abstract]

Schedule of Inventories

	Millions of Dollars
	June 30 2022		December 31 2021
Crude oil and natural gas	$	653	647
Materials and supplies	581		561
Total Inventories	$	1,234	1,208
Inventories valued on the LIFO basis	$	326	395

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Acquisitions and Dispositions (Tables)

6 Months Ended

Jun. 30, 2022

Business Combination, Asset Acquisition And Dispositions [Abstract]

Schedule of Business Acquisition

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

Business Acquisition, Pro Forma Information (unaudited)

The following table summarizes the unaudited supplemental pro forma financial information for the three- and six-month periods ended June 30, 2021, as if we had completed the acquisition of Shell's Permian assets on January 1, 2020:

	Millions of Dollars
	Three Months Ended June 30, 2021				Six Months Ended June 30, 2021
Supplemental Pro Forma (unaudited)	As Reported		Pro forma Shell	Pro forma Combined	As Reported	Pro forma Shell	Pro forma Combined
Total Revenues and Other Income	10,211		799	11,010	20,770	1,395	22,165
Income before income taxes	3,080		297	3,377	4,794	416	5,210
Net Income	2,091		227	2,318	3,073	318	3,391
Earnings per share ($ per share):
Basic net income	$	1.55		1.71	2.32		2.56
Diluted net income	1.55			1.71	2.31		2.55

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Investment in Cenovus Energy (Tables)

6 Months Ended

Jun. 30, 2022

Cenovus Energy Inc

Debt and Equity Securities, FV-NI [Line Items]

Schedule of Gains and Losses Recorded in Other Income (Loss)

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022		2021
Total Net gain on equity securities	$	—	418	251		726
Less: Net gain on equity securities sold during the period	—		31	251		60
Unrealized gain on equity securities still held at the reporting date	$	—	387	$	—	666

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Debt (Tables)

6 Months Ended

Jun. 30, 2022

Debt Disclosure [Abstract]

Schedule of Long-term Debt

	Millions of Dollars
	June 30 2022		December 31 2021
2.4% Notes due 2022	$	329	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
2.4% 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% 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	645		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% – 1.09% during 2022 and 0.04% – 0.15% during 2021	265		265
Industrial Development Bonds due 2035 at 0.07% – 1.09% during 2022 and 0.04% – 0.12% during 2021	18		18
Other	33		35
Debt at face value	16,208		17,766
Finance leases	1,284		1,261
Net unamortized premiums, discounts and debt issuance costs	(521)		907
Total debt	16,971		19,934
Short-term debt	(676)		(1,200)
Long-term debt	$	16,295	18,734

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Changes in Equity (Tables)

6 Months Ended

Jun. 30, 2022

Stockholders' Equity Note [Abstract]

Schedule of Changes in Equity

	Millions of Dollars
	Common Stock
	Par Value		Capital in Excess of Par	Treasury Stock	Accum. Other Comprehensive Income (Loss)	Retained Earnings	Total
For the three months ended June 30, 2022
Balances at March 31, 2022	$	21	60,907	(52,344)	(4,808)	45,442	49,218
Net income						5,145	5,145
Other comprehensive income					(505)		(505)
Dividends declared
Ordinary ($0.46 per common share)						(598)	(598)
Variable return of cash ($0.70 per common share)						(896)	(896)
Repurchase of company common stock				(2,300)			(2,300)
Distributed under benefit plans			138				138
Other							—
Balances at June 30, 2022	$	21	61,045	(54,644)	(5,313)	49,093	50,202
For the six months ended June 30, 2022
Balances at December 31, 2021	$	21	60,581	(50,920)	(4,950)	40,674	45,406
Net income						10,904	10,904
Other comprehensive income					(363)		(363)
Dividends declared
Ordinary ($0.92 per common share)						(1,201)	(1,201)
Variable return of cash ($1.00 per common share)						(1,286)	(1,286)
Repurchase of company common stock				(3,725)			(3,725)
Distributed under benefit plans			464				464
Other				1		2	3
Balances at June 30, 2022	$	21	61,045	(54,644)	(5,313)	49,093	50,202

	Millions of Dollars
	Common Stock
	Par Value		Capital in Excess of Par	Treasury Stock	Accum. Other Comprehensive Income (Loss)	Retained Earnings	Total
For the three months ended June 30, 2021
Balances at March 31, 2021	$	21	60,278	(47,672)	(5,080)	35,608	43,155
Net income						2,091	2,091
Other comprehensive income					160		160
Dividends declared
Ordinary ($0.43 per common share)						(583)	(583)
Repurchase of company common stock				(606)			(606)
Distributed under benefit plans			59				59
Balances at June 30, 2021	$	21	60,337	(48,278)	(4,920)	37,116	44,276
For the six months ended June 30, 2021
Balances at December 31, 2020	$	18	47,133	(47,297)	(5,218)	35,213	29,849
Net income						3,073	3,073
Other comprehensive loss					298		298
Dividends declared
Ordinary ($0.86 per common share)						(1,171)	(1,171)
Acquisition of Concho	3		13,122				13,125
Repurchase of company common stock				(981)			(981)
Distributed under benefit plans			82				82
Other						1	1
Balances at June 30, 2021	$	21	60,337	(48,278)	(4,920)	37,116	44,276

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Derivative and Financial Instruments (Tables)

6 Months Ended

Jun. 30, 2022

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Balance Sheet Location and Fair Value Amounts of Derivatives

The following table presents the gross fair values of our commodity derivatives, excluding collateral, and the line items where they appear on our consolidated balance sheet:

	Millions of Dollars
	June 30 2022		December 31 2021
Assets
Prepaid expenses and other current assets	$	1,790	1,168
Other assets	262		75
Liabilities
Other accruals	1,824		1,160
Other liabilities and deferred credits	232		63

Schedule of Income Statement Location and Gain (Loss) Amounts of Derivatives

The gains (losses) from commodity derivatives incurred and the line items where they appear on our consolidated income statement were:

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Sales and other operating revenues	$	(13)	(100)	(420)	(379)
Other income	1		(1)	2	16
Purchased commodities	(55)		132	346	145

Schedule of Net Exposures from Outstanding Commodity Derivative Contracts

The table below summarizes our material net exposures resulting from outstanding commodity derivative contracts:

	Open Position Long (Short)
	June 30 2022	December 31 2021
Commodity
Natural gas and power (billions of cubic feet equivalent)
Fixed price	(14)	4
Basis	(1)	(22)

Schedule of Net Carrying Amount of Held to Maturity Investments

The following investments are carried on our consolidated balance sheet at cost, plus accrued interest, and the table reflects remaining maturities at June 30, 2022, and December 31, 2021:

	Millions of Dollars
	Carrying Amount
	Cash and Cash Equivalents			Short-Term Investments
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Cash	$	505	670
Demand Deposits	1,690		1,554
Time Deposits
1 to 90 days	4,555		2,363	524	217
91 to 180 days				112	4
Within one year				47	4
One year through five years
U.S. Government Obligations
1 to 90 days	39		431	—	—
	$	6,789	5,018	683	225

Schedule of Debt Securities Carried at Fair Value

The following investments in debt securities classified as available for sale are carried at fair value on our consolidated balance sheet at June 30, 2022 and December 31, 2021:

	Millions of Dollars
	Carrying Amount
	Cash and Cash Equivalents			Short-Term Investments		Investments and Long-Term Receivables
	June 30 2022		December 31 2021	June 30 2022	December 31 2021	June 30 2022	December 31 2021
Major Security Type
Corporate Bonds	$	—	3	299	128	298	173
Commercial Paper	120		7	215	82
U.S. Government Obligations	—		—	68	—	94	2
U.S. Government Agency Obligations				5	2	5	8
Foreign Government Obligations				2	7	4	2
Asset-backed Securities				—	2	100	63
	$	120	10	589	221	501	248

The following table summarizes the amortized cost basis and fair value of investments in debt securities classified as available for sale:

	Millions of Dollars
	Amortized Cost Basis			Fair Value
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Major Security Type
Corporate Bonds	$	604	305	597	304
Commercial Paper	335		88	335	89
U.S. Government Obligations	163		2	162	2
U.S. Government Agency Obligations	10		10	10	10
Foreign Government Obligations	6		9	6	9
Asset-backed Securities	100		65	100	65
	$	1,218	479	1,210	479

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Fair Value Measurement (Tables)

6 Months Ended

Jun. 30, 2022

Fair Value Disclosures [Abstract]

Schedule of 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
	June 30, 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	162		1,048	—	1,210	2	477	—	479
Commodity derivatives	957		1,037	58	2,052	562	619	62	1,243
Total assets	$	1,119	2,085	58	3,262	1,681	1,096	62	2,839
Liabilities
Commodity derivatives	$	1,004	867	185	2,056	593	543	87	1,223
Total liabilities	$	1,004	867	185	2,056	593	543	87	1,223

Schedule of 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 Recognized		Amounts Not Subject to Right of Setoff	Gross Amounts	Gross Amounts Offset	Net Amounts Presented	Cash Collateral	Net Amounts
June 30, 2022
Assets	$	2,052	27	2,025	1,302	723	—	723
Liabilities	2,056		16	2,040	1,302	738	48	690
December 31, 2021
Assets	$	1,243	85	1,158	650	508	—	508
Liabilities	1,223		82	1,141	650	491	36	455

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
	June 30 2022		December 31 2021	June 30 2022	December 31 2021
Financial assets
Investment in CVE common shares	$	—	1,117	—	1,117
Commodity derivatives	750		593	750	593
Investments in debt securities	1,210		479	1,210	479
Loans and advances—related parties	59		114	59	114
Financial liabilities
Total debt, excluding finance leases	15,687		18,673	16,547	22,451
Commodity derivatives	706		537	706	537

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Accumulated Other Comprehensive Loss (Tables)

6 Months Ended

Jun. 30, 2022

Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]

Schedule of Components of Accumulated Other Comprehensive Loss in the Equity Section of the Balance Sheet

Accumulated other comprehensive loss in the equity section of our consolidated balance sheet includes:

	Millions of Dollars
	Defined Benefit Plans		Net Unrealized Loss on Securities	Foreign Currency Translation	Accumulated Other Comprehensive Loss
December 31, 2021	$	(31)	—	(4,919)	(4,950)
Other comprehensive loss	(49)		(7)	(307)	(363)
June 30, 2022	$	(80)	(7)	(5,226)	(5,313)

Schedule of Items Reclassified out of Accumulated Other Comprehensive Income (Loss)

The following table summarizes reclassifications out of accumulated other comprehensive loss and into net income (loss):

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Defined benefit plans	$	12	42	16	54

The above amounts are included in the computation of net periodic benefit cost and are presented net of tax expense of $3 million and $11 million for the three-month periods ended June 30, 2022 and June 30, 2021, respectively, and $5 million and $15 million for the six-month periods ended

June 30, 2022 and June 30, 2021, respectively. See Note 14.

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Cash Flow Information (Tables)

6 Months Ended

Jun. 30, 2022

Supplemental Cash Flow Information [Abstract]

Schedule of Cash Flow Information

	Millions of Dollars
	Six Months Ended June 30
Cash Payments	2022		2021
Interest	$	486	464
Income taxes	3,942		107
Net Sales (Purchases) of Investments
Short-term investments purchased	$	(1,253)	(5,439)
Short-term investments sold	613		6,842
Long-term investments purchased	(510)		(149)
Long-term investments sold	46		48
	$	(1,104)	1,302

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Employee Benefit Plans (Tables)

6 Months Ended

Jun. 30, 2022

Retirement Benefits [Abstract]

Schedule of Components of Net Periodic Benefit Cost

	Millions of Dollars
	Pension Benefits					Other Benefits
	2022			2021		2022	2021
	U.S.		Int'l.	U.S.	Int'l.
Components of Net Periodic Benefit Cost
Three Months Ended June 30
Service cost	$	16	13	18	16	1	1
Interest cost	12		21	15	20	1	1
Expected return on plan assets	(13)		(34)	(20)	(30)	—	—
Amortization of prior service credit	—		—	—	—	(10)	(10)
Recognized net actuarial loss	5		2	12	8	—	1
Settlements	18		—	42	—	—	—
Net periodic benefit cost	$	38	2	67	14	(8)	(7)
Six Months Ended June 30
Service cost	$	32	26	39	31	1	1
Interest cost	24		42	28	40	2	2
Expected return on plan assets	(26)		(68)	(44)	(60)	—	—
Amortization of prior service credit	—		—	—	—	(20)	(19)
Recognized net actuarial loss	11		4	27	16	—	1
Settlements	22		—	44	—	—	—
Curtailments	—		—	12	—	—	—
Special Termination Benefits	—		—	9	—	—	—
Net periodic benefit cost	$	63	4	115	27	(17)	(15)

Schedule of Discount Rates

The relevant discount rates are summarized in the following table:

	June 30 2022		December 31 2021
Relevant discount rates
U.S. qualified pension plan	4.85	%	2.85
U.S. nonqualified pension plan	4.70		2.50

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Related Party Transactions (Tables)

6 Months Ended

Jun. 30, 2022

Related Party Transactions [Abstract]

Schedule of Significant Transactions with Related Parties

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
Significant Transactions with Equity Affiliates	2022		2021	2022	2021
Operating revenues and other income	$	21	24	43	40
Purchases	—		3	—	3
Operating expenses and selling, general and administrative expenses	44		63	90	89
Net interest (income) expense*	$	—	—	(1)	(1)

*We paid interest to, or received interest from, various affiliates. See Note 4 for information related to loans to equity affiliates.

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Sales and Other Operating Revenues (Tables)

6 Months Ended

Jun. 30, 2022

Revenue from Contract with Customer [Abstract]

Schedule of Disaggregation of Revenue

The following table provides further disaggregation of our consolidated sales and other operating revenues:

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from contracts with customers	$	16,728	7,753	31,234	14,914
Revenue from contracts outside the scope of ASC Topic 606
Physical contracts meeting the definition of a derivative	4,411		1,754	7,551	4,728
Financial derivative contracts	22		49	138	(260)
Consolidated sales and other operating revenues	$	21,161	9,556	38,923	19,382

The following disaggregation of revenues is provided in conjunction with Note 17—Segment Disclosures and Related Information:

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from Outside the Scope of ASC Topic 606 by Segment
Lower 48	$	3,483	1,345	5,927	3,811
Canada	807		207	1,367	510
Europe, Middle East and North Africa	121		202	257	407
Physical contracts meeting the definition of a derivative	$	4,411	1,754	7,551	4,728

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Revenue from Outside the Scope of ASC Topic 606 by Product
Crude oil	$	64	178	283	302
Natural gas	4,254		1,504	7,027	4,231
Other	93		72	241	195
Physical contracts meeting the definition of a derivative	$	4,411	1,754	7,551	4,728

Schedule of Contract with Customer, Asset and Liability

	Millions of Dollars
Contract Liabilities
At December 31, 2021	$	50
Contractual payments received	25
Revenue recognized	(56)
At June 30, 2022	$	19
Amounts Recognized in the Consolidated Balance Sheet at June 30, 2022
Noncurrent liabilities	$	19

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Segment Disclosures and Related Information (Tables)

6 Months Ended

Jun. 30, 2022

Segment Reporting [Abstract]

Schedule of Operating Segment Reporting

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Sales and Other Operating Revenues
Alaska	$	2,349	1,418	4,267	2,551
Lower 48	14,458		5,889	26,015	12,402
Intersegment eliminations	(6)		(2)	(13)	(4)
Lower 48	14,452		5,887	26,002	12,398
Canada	1,794		802	3,314	1,669
Intersegment eliminations	(726)		(352)	(1,377)	(657)
Canada	1,068		450	1,937	1,012
Europe, Middle East and North Africa	2,652		1,165	5,241	2,143
Asia Pacific	638		630	1,388	1,207
Other International	—		2	—	3
Corporate and Other	2		4	88	68
Consolidated sales and other operating revenues	$	21,161	9,556	38,923	19,382
Sales and Other Operating Revenues by Geographic Location(1)
United States	$	16,802	7,308	30,355	15,015
Canada	1,069		450	1,938	1,012
China	301		171	574	326
Indonesia	—		207	159	403
Libya	351		290	782	520
Malaysia	336		252	654	478
Norway	737		618	1,669	1,030
United Kingdom	1,564		257	2,790	593
Other foreign countries	1		3	2	5
Worldwide consolidated	$	21,161	9,556	38,923	19,382
Sales and Other Operating Revenues by Product
Crude oil	$	11,494	5,797	21,364	10,292
Natural gas	7,267		2,812	13,265	7,323
Natural gas liquids	1,042		325	1,921	562
Other(2)	1,358		622	2,373	1,205
Consolidated sales and other operating revenues by product	$	21,161	9,556	38,923	19,382

(1)Sales and other operating revenues are attributable to countries based on the location of the selling operation.

(2)Includes LNG and bitumen.

	Millions of Dollars
	Three Months Ended June 30			Six Months Ended June 30
	2022		2021	2022	2021
Net Income (Loss)
Alaska	$	687	371	1,271	530
Lower 48	3,581		1,175	6,371	1,643
Canada	316		102	607	112
Europe, Middle East and North Africa	385		207	797	360
Asia Pacific	525		175	1,661	492
Other International	—		(5)	—	(9)
Corporate and Other	(349)		66	197	(55)
Consolidated net income	$	5,145	2,091	10,904	3,073

	Millions of Dollars
	June 30 2022		December 31 2021
Total Assets
Alaska	$	14,835	14,812
Lower 48	43,478		41,699
Canada	7,358		7,439
Europe, Middle East and North Africa	8,406		9,125
Asia Pacific	9,997		9,840
Other International	4		1
Corporate and Other	9,615		7,745
Consolidated total assets	$	93,693	90,661

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Inventories - Schedule of Inventories (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Inventory Disclosure [Abstract]
Crude oil and natural gas	$ 653	$ 647
Materials and supplies	581	561
Total Inventories	1,234	1,208
Inventories valued on the LIFO basis	$ 326	$ 395

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Acquisitions and Dispositions - Narrative (Details) a in Thousands	1 Months Ended				3 Months Ended		6 Months Ended
	Apr. 30, 2022 USD ($)	Mar. 31, 2022 USD ($)	Feb. 28, 2022 USD ($)	Dec. 31, 2021 USD ($) a	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Sep. 30, 2022 USD ($)
Subsidiaries Holding Indonesia Assets and Operations
Business Acquisition [Line Items]
Earnings before income tax							$ 138,000,000	$ 264,000,000
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Canada and Lower 48
Business Acquisition [Line Items]
Contingent payment					$ 174,000,000	$ 68,000,000	$ 424,000,000	$ 94,000,000
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Subsidiaries Holding Indonesia Assets and Operations
Business Acquisition [Line Items]
Disposal group, consideration		$ 731,000,000
Before-tax gain (loss) on disposition		534,000,000
After-tax gain (loss) on disposition		462,000,000
Net carry value of asset disposed		200,000,000
Assets held for sale, property, plant and equipment		300,000,000
Asset held for sale, cash and cash equivalents		200,000,000
Asset held for sale, asset retirement obligation		$ 100,000,000
Disposal Group, Disposed of by Sale, Not Discontinued Operations | Certain Noncore Assets
Business Acquisition [Line Items]
Disposal group, consideration	$ 370,000,000
Before-tax gain (loss) on disposition	80,000,000
After-tax gain (loss) on disposition	63,000,000
Net carry value of asset disposed	290,000,000
Assets held for sale, property, plant and equipment	401,000,000
Assets held for sale, liabilities	$ 111,000,000
Disposal Group, Held-for-sale, Not Discontinued Operations | Certain Noncore Assets | Forecast | Subsequent Event
Business Acquisition [Line Items]
Disposal group, consideration									$ 265,000,000
APLNG
Business Acquisition [Line Items]
Additional ownership percentage in equity investment acquired			10.00%
Payments to acquire equity method investments			$ 1,400,000,000
Equity method investment, ownership percentage			47.50%		47.50%		47.50%
APLNG | Origin Energy
Business Acquisition [Line Items]
Ownership percentage			27.50%
APLNG | Sinopec
Business Acquisition [Line Items]
Ownership percentage			25.00%
Indonesia Corridor Block Production Sharing Contract | Subsidiaries Holding Indonesia Assets and Operations
Business Acquisition [Line Items]
Ownership percentage		54.00%
Transasia Pipeline Company | Subsidiaries Holding Indonesia Assets and Operations
Business Acquisition [Line Items]
Ownership percentage		35.00%
Shell Enterprises LLC
Business Acquisition [Line Items]
Total asset consideration				$ 8,600,000,000
Area of land | a				225
Capitalized costs, proved properties				$ 4,200,000,000
Capitalized costs, unproved properties				$ 4,300,000,000

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Acquisitions and Dispositions - Schedule of Business Combination (Details) - Shell Enterprises LLC $ in Millions	Dec. 31, 2021 USD ($)
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

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Acquisitions and Dispositions - Supplemental Pro Forma (unaudited) (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Supplemental Pro Forma (unaudited)
Total revenues and other Income	$ 21,989	$ 10,211	$ 41,280	$ 20,770
Income (loss) before income taxes	7,655	3,080	15,553	4,794
Net income (loss)	$ 5,145	$ 2,091	$ 10,904	$ 3,073
Earnings per share ($ per share):
Basic net income (in dollars per share)	$ 3.98	$ 1.55	$ 8.39	$ 2.32
Diluted net income (in dollars per share)	$ 3.96	$ 1.55	$ 8.36	$ 2.31
Pro Forma
Supplemental Pro Forma (unaudited)
Total revenues and other Income		$ 11,010		$ 22,165
Income (loss) before income taxes		3,377		5,210
Net income (loss)		$ 2,318		$ 3,391
Earnings per share ($ per share):
Basic net income (in dollars per share)		$ 1.71		$ 2.56
Diluted net income (in dollars per share)		$ 1.71		$ 2.55
Shell Enterprises LLC
Supplemental Pro Forma (unaudited)
Total revenue and other income, pro-forma Shell		$ 799		$ 1,395
Income (loss) before income taxes, pro-forma Shell		297		416
Net income (loss), pro-forma Shell		$ 227		$ 318
Earnings per share ($ per share):
Basic net income, pro-forma Shell (in dollars per share)
Diluted net income, pro-forma Shell (in dollars per share)

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Investments, Loans and Long-Term Receivables - Narrative (Details) - USD ($) $ in Millions	1 Months Ended
	Feb. 28, 2022	Jun. 30, 2022	Dec. 31, 2012
APLNG
Schedule of Equity Method Investments [Line Items]
Project finance facility, maximum borrowing capacity			$ 8,500
Line of credit facility value outstanding		$ 5,500
Additional ownership percentage in equity investment acquired	10.00%
Payments to acquire equity method investments	$ 1,400
Equity method investment, ownership percentage	47.50%	47.50%
Book value of equity method investment		$ 6,400
APLNG | Origin Energy
Schedule of Equity Method Investments [Line Items]
Ownership percentage	27.50%
APLNG | Sinopec
Schedule of Equity Method Investments [Line Items]
Ownership percentage	25.00%
QG3
Schedule of Equity Method Investments [Line Items]
Loan balance with affiliated company		$ 59

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

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Investment in Cenovus Energy - Schedule of Gains and Losses Recorded in Other Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Debt and Equity Securities, FV-NI [Line Items]
Total Net gain on equity securities			$ 251	$ 726
Cenovus Energy Inc
Debt and Equity Securities, FV-NI [Line Items]
Total Net gain on equity securities	$ 0	$ 418	251	726
Less: Net gain on equity securities sold during the period	0	31	251	60
Unrealized gain on equity securities still held at the reporting date	$ 0	$ 387	$ 0	$ 666

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Debt - Schedule of Long-term Debt (Details) - USD ($) $ in Millions	Jun. 30, 2022	May 31, 2022	Dec. 31, 2021
Debt Instrument [Line Items]
Long-term and short-term, combined amount, gross	$ 16,208		$ 17,766
Finance leases	1,284		1,261
Net unamortized premiums, discounts and debt issuance costs	(521)		907
Total debt	16,971		19,934
Short-term debt	(676)		(1,200)
Long-term debt	$ 16,295		18,734
2.4% Notes due 2022 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	2.40%
Long-term and short-term, combined amount, gross	$ 329		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%
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
2.4% Notes due 2025 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	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 | Notes Payable to Banks
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% Debentures due 2029 | Notes Payable to Banks
Debt Instrument [Line Items]
Stated interest rate	7.00%
7% Debentures due 2029 | Debentures
Debt Instrument [Line Items]
Stated interest rate	7.00%
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	$ 645		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%
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% – 1.09% 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% – 1.09% 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% – 1.09% during 2022 and 0.04% – 0.15% during 2021 | Variable Rate Debt Bonds | Maximum
Debt Instrument [Line Items]
Stated interest rate	1.09%		0.15%
Industrial Development Bonds due 2035 at 0.07% – 1.09% 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% – 1.09% 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% – 1.09% during 2022 and 0.04% – 0.12% during 2021 | Variable Rate Debt Bonds | Maximum
Debt Instrument [Line Items]
Stated interest rate	1.09%		0.12%
Other
Debt Instrument [Line Items]
Long-term and short-term, combined amount, gross	$ 33		$ 35

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Debt - Narrative (Details) $ in Millions	1 Months Ended		6 Months Ended
	May 31, 2022 USD ($)	Mar. 31, 2022 USD ($) transaction	Jun. 30, 2022 USD ($)	Jun. 30, 2021 USD ($)	Mar. 08, 2022 USD ($)	Feb. 28, 2022 USD ($)	Jan. 31, 2022 USD ($)	Dec. 31, 2021 USD ($)
Debt Instrument [Line Items]
Debt instrument, repurchased face amount		$ 2,716
Debt repurchase, incurred debt premium		333
Gain (loss) on repurchase of debt instrument		$ 155
Repayments of debt			$ 5,829	$ 44
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
Commercial paper program, amount outstanding			$ 320
Notes Payable to Banks | 4.95% Notes due 2026
Debt Instrument [Line Items]
Debt instrument, repurchased face amount	$ 1,250
Stated interest rate	4.95%		4.95%
Debt repurchase, incurred debt premium	$ 79
Gain (loss) on repurchase of debt instrument	(83)
Notes Payable to Banks | 3.75% Notes due 2027
Debt Instrument [Line Items]
Debt instrument, repurchased face amount		804
Stated interest rate			3.75%
Debt at face value						$ 1,000
Notes Payable to Banks | 4.3% Notes due 2028
Debt Instrument [Line Items]
Debt instrument, repurchased face amount		777
Stated interest rate			4.30%
Debt at face value						1,000
Notes Payable to Banks | 2.4% Notes due 2031
Debt Instrument [Line Items]
Debt instrument, repurchased face amount		273
Stated interest rate			2.40%
Debt at face value						500
Notes Payable to Banks | 4.875% Notes due 2047
Debt Instrument [Line Items]
Debt instrument, repurchased face amount		481
Stated interest rate			4.875%
Debt at face value						800
Notes Payable to Banks | 4.85% Notes due 2048
Debt Instrument [Line Items]
Debt instrument, repurchased face amount		381
Stated interest rate			4.85%
Debt at face value						600
Notes Payable to Banks | 7% Debentures due 2029
Debt Instrument [Line Items]
Stated interest rate			7.00%
Debt at face value						200
Debt instrument, exchange amount		88
Notes Payable to Banks | 6.95% Notes due 2029
Debt Instrument [Line Items]
Stated interest rate			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%
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%
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%
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%
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%
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%
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%
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%
Debt at face value			$ 785
Notes Payable to Banks | 4.025% Notes due 2062
Debt Instrument [Line Items]
Stated interest rate			4.025%
Debt at face value			$ 1,770
Notes Payable to Banks | 2.125% Notes due 2024
Debt Instrument [Line Items]
Stated interest rate			2.125%
Debt at face value					$ 900
Notes Payable to Banks | 2.4% Notes due 2025
Debt Instrument [Line Items]
Stated interest rate			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%
Debt at face value					$ 1,100
Variable Rate Debt Bonds
Debt Instrument [Line Items]
Debt at face value			$ 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%					1.12%
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
Commercial paper program, amount outstanding			0					$ 0
Remaining borrowing capacity under revolving credit facility			5,500
Commercial Paper | Conoco Phillips Commercial Paper Program
Debt Instrument [Line Items]
Project finance facility, maximum borrowing capacity			5,500
Commercial paper program, amount outstanding			0					$ 0
Letter of Credit | Maximum
Debt Instrument [Line Items]
Line of credit facility, capacity available for specific purpose other than for trade purchases			$ 500

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Changes in Equity (Details) - USD ($) $ / shares in Units, $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance	$ 49,218	$ 43,155	$ 45,406	$ 29,849
Net Income	5,145	2,091	10,904	3,073
Other comprehensive income (loss)	(505)	160	(363)	298
Dividends declared, ordinary	(598)	(583)	(1,201)	(1,171)
Dividends declared, variable return of cash	(896)		(1,286)
Repurchase of company common stock	(2,300)	(606)	(3,725)	(981)
Distributed under benefit plans	138	59	464	82
Acquisition of Concho				13,125
Other	0		3	1
Ending Balance	$ 50,202	$ 44,276	$ 50,202	$ 44,276
Dividends declared, ordinary (in dollars per share)	$ 0.46	$ 0.43	$ 0.92	$ 0.86
Dividends declared, variable return of cash (in dollars per share)	$ 0.70		$ 1.00
Par Value
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance	$ 21	$ 21	$ 21	$ 18
Acquisition of Concho				3
Ending Balance	21	21	21	21
Capital in Excess of Par
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance	60,907	60,278	60,581	47,133
Distributed under benefit plans	138	59	464	82
Acquisition of Concho				13,122
Ending Balance	61,045	60,337	61,045	60,337
Treasury Stock
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance	(52,344)	(47,672)	(50,920)	(47,297)
Repurchase of company common stock	(2,300)	(606)	(3,725)	(981)
Other			1
Ending Balance	(54,644)	(48,278)	(54,644)	(48,278)
Accum. Other Comprehensive Income (Loss)
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance	(4,808)	(5,080)	(4,950)	(5,218)
Other comprehensive income (loss)	(505)	160	(363)	298
Ending Balance	(5,313)	(4,920)	(5,313)	(4,920)
Retained Earnings
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Beginning Balance	45,442	35,608	40,674	35,213
Net Income	5,145	2,091	10,904	3,073
Dividends declared, ordinary	(598)	(583)	(1,201)	(1,171)
Dividends declared, variable return of cash	(896)		(1,286)
Other			2	1
Ending Balance	$ 49,093	$ 37,116	$ 49,093	$ 37,116

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Guarantees - Narrative (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Feb. 28, 2022
APLNG
Guarantor Obligations [Line Items]
Ownership percentage in equity investment	47.50%	47.50%
Finance Reserve Guarantee | APLNG
Guarantor Obligations [Line Items]
Guarantor obligations, remaining term	9 years
Maximum potential amount of future payments	$ 210
Guarantor obligations, current carrying value	14
Max Potential Future Payments Reckless Breach | APLNG
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	1,400
Max Potential Future Payments Pro-rata Share | APLNG
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	820
Continued Development | APLNG
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	290
Guarantor obligations, current carrying value	$ 20
Continued Development | APLNG | Minimum
Guarantor Obligations [Line Items]
Guarantor obligations, term	15 years
Continued Development | APLNG | Maximum
Guarantor Obligations [Line Items]
Guarantor obligations, term	23 years
Other Guarantees
Guarantor Obligations [Line Items]
Maximum potential amount of future payments	$ 720
Guarantor obligations, current carrying value	$ 8
Other Guarantees | Minimum
Guarantor Obligations [Line Items]
Guarantor obligations, term	1 year
Other Guarantees | Maximum
Guarantor Obligations [Line Items]
Guarantor obligations, term	5 years
Indemnifications
Guarantor Obligations [Line Items]
Guarantor obligations, current carrying value	$ 20

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Contingencies and Commitments - Narrative (Details) $ in Millions			1 Months Ended			6 Months Ended	12 Months Ended
	May 10, 2021 USD ($)	Aug. 02, 2019 USD ($)	Mar. 31, 2019 USD ($)	Aug. 31, 2018 USD ($)	Apr. 30, 2018 USD ($)	Jun. 30, 2022 USD ($)	Dec. 31, 2017 lawsuit	Dec. 31, 2021 USD ($)	Aug. 29, 2019 USD ($)
Loss Contingencies [Line Items]
Total environmental accrual included in balance sheet						$ 178		$ 187
Commercial paper program, amount outstanding						$ 320
Several Louisiana Parishes and the State of Louisiana Against Oil and Gas Companies
Loss Contingencies [Line Items]
Loss contingency, new claims filed, number | lawsuit							43
Several Louisiana Parishes and the State of Louisiana Against Oil and Gas Companies | ConocoPhillips Entities
Loss Contingencies [Line Items]
Loss contingency, new claims filed, number | lawsuit							22
Outer Continental Shelf Lease | Phillips Petroleum Company
Loss Contingencies [Line Items]
Ownership percentage in equity investment						25.00%
Sale of interest, duration						30 years
ConocoPhillips v Santos KOTN Pty Ltd and Santos Limited re Barossa Development Project | Performance Guarantee
Loss Contingencies [Line Items]
Loss contingency, damages sought, value	$ 200
Venezuela | ConocoPhillips Versus Petroleos de Venezuela ICISD
Loss Contingencies [Line Items]
Litigation settlement, amount awarded from other party			$ 8,700
Litigation award reduction									$ 227
Litigation settlement amount awarded from other party revised						$ 8,500
Venezuela | ConocoPhillips vs Petroleos De Venezuela ICC
Loss Contingencies [Line Items]
Litigation settlement, amount awarded from other party		$ 33		$ 500	$ 2,000
Proceeds from legal settlements						$ 771
US and Canada | Cleanup Remediation Activities
Loss Contingencies [Line Items]
Environmental loss contingencies, term						30 years

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Derivative and Financial Instruments - Schedule of Balance Sheet Location and Fair Value Amounts of Derivatives (Details) - Commodity Contract - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Prepaid expenses and other current assets
Derivatives, Fair Value [Line Items]
Commodity derivative assets	$ 1,790	$ 1,168
Other assets
Derivatives, Fair Value [Line Items]
Commodity derivative assets	262	75
Other accruals
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	1,824	1,160
Other liabilities and deferred credits
Derivatives, Fair Value [Line Items]
Commodity derivative liabilities	$ 232	$ 63

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Derivative and Financial Instruments - Schedule of Income Statement Location and Gain (Loss) Amounts of Derivatives (Details) - Commodity Contract - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Sales and other operating revenues
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (13)	$ (100)	$ (420)	$ (379)
Other income
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	1	(1)	2	16
Purchased commodities
Derivative Instruments, Gain (Loss) [Line Items]
Gains (losses) from commodity derivatives	$ (55)	$ 132	$ 346	$ 145

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Derivative and Financial Instruments - Narrative (Details) - USD ($)	3 Months Ended			6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Mar. 31, 2021	Jun. 30, 2022	Jun. 30, 2021	Dec. 31, 2021
Derivative [Line Items]
Proceeds from sales and redemptions of investments in debt securities classified as available for sale	$ 86,000,000	$ 173,000,000		$ 201,000,000	$ 320,000,000
Derivative, net liability position, aggregate fair value	326,000,000			326,000,000		$ 281,000,000
Collateral already posted, aggregate fair value	6,000,000			$ 6,000,000		$ 0
Minimum
Derivative [Line Items]
Investments and long-term receivables, remaining maturity				1 year
Maximum
Derivative [Line Items]
Investments and long-term receivables, remaining maturity				7 years
In event of downgrade below investment grade
Derivative [Line Items]
Additional collateral, aggregate fair value	$ 238,000,000			$ 238,000,000
Accounts Receivable | Maximum
Derivative [Line Items]
Credit derivative, term				30 days
Concho Resources Incorporated | Commodity Contract
Derivative [Line Items]
Gains (losses) from commodity derivatives			$ (305,000,000)
Increase (decrease) in commodity contract assets and liabilities		$ 69,000,000	$ 692,000,000

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Derivative and Financial Instruments - Schedule of Net Exposures from Outstanding Commodity Derivative Contracts (Details) - Commodity Contract - Bcf	6 Months Ended	12 Months Ended
	Jun. 30, 2022	Dec. 31, 2021
Natural Gas and Power, Fixed Price | Long
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures		4
Natural Gas and Power, Fixed Price | Short
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	14
Natural Gas and Power, Basis | Short
Trading Activity, Gains and Losses, Net [Line Items]
Commodity derivatives - volumetric material net exposures	1	22

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Derivative and Financial Instruments - Schedule of Net Carrying Amount of Held to Maturity Investments (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents, carried at cost plus accrued interest	$ 6,789	$ 5,018
Short-term investments, carried at cost plus accrued interest	683	225
Cash
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents, carried at cost plus accrued interest	505	670
Demand Deposits
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents, carried at cost plus accrued interest	1,690	1,554
Time Deposits | 1 to 90 days
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents, carried at cost plus accrued interest	4,555	2,363
Short-term investments, carried at cost plus accrued interest	524	217
Time Deposits | 91 to 180 days
Schedule of Held-to-maturity Securities [Line Items]
Short-term investments, carried at cost plus accrued interest	112	4
Time Deposits | Within one year
Schedule of Held-to-maturity Securities [Line Items]
Short-term investments, carried at cost plus accrued interest	47	4
U.S. Government Obligations | 1 to 90 days
Schedule of Held-to-maturity Securities [Line Items]
Cash and cash equivalents, carried at cost plus accrued interest	39	431
Short-term investments, carried at cost plus accrued interest	$ 0	$ 0

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Derivative and Financial Instruments - Schedule of Debt Securities Carried at Fair Value (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Cash and Cash Equivalents	$ 6,909	$ 5,028
Short-Term Investments	1,272	446
Investments and Long-Term Receivables	8,203	7,113
Within one year | Reported Value Measurement
Debt Securities, Available-for-sale [Line Items]
Cash and Cash Equivalents	120	10
Short-Term Investments	589	221
Within one year | Reported Value Measurement | Corporate Bonds
Debt Securities, Available-for-sale [Line Items]
Cash and Cash Equivalents	0	3
Short-Term Investments	299	128
Within one year | Reported Value Measurement | Commercial Paper
Debt Securities, Available-for-sale [Line Items]
Cash and Cash Equivalents	120	7
Short-Term Investments	215	82
Within one year | Reported Value Measurement | U.S. Government Obligations
Debt Securities, Available-for-sale [Line Items]
Cash and Cash Equivalents	0	0
Short-Term Investments	68	0
Within one year | Reported Value Measurement | U.S. Government Agency Obligations
Debt Securities, Available-for-sale [Line Items]
Short-Term Investments	5	2
Within one year | Reported Value Measurement | Foreign Government Obligations
Debt Securities, Available-for-sale [Line Items]
Short-Term Investments	2	7
Within one year | Reported Value Measurement | Asset-backed Securities
Debt Securities, Available-for-sale [Line Items]
Short-Term Investments	0	2
Investments and Long-Term Receivables | Reported Value Measurement
Debt Securities, Available-for-sale [Line Items]
Investments and Long-Term Receivables	501	248
Investments and Long-Term Receivables | Reported Value Measurement | Corporate Bonds
Debt Securities, Available-for-sale [Line Items]
Investments and Long-Term Receivables	298	173
Investments and Long-Term Receivables | Reported Value Measurement | U.S. Government Obligations
Debt Securities, Available-for-sale [Line Items]
Investments and Long-Term Receivables	94	2
Investments and Long-Term Receivables | Reported Value Measurement | U.S. Government Agency Obligations
Debt Securities, Available-for-sale [Line Items]
Investments and Long-Term Receivables	5	8
Investments and Long-Term Receivables | Reported Value Measurement | Foreign Government Obligations
Debt Securities, Available-for-sale [Line Items]
Investments and Long-Term Receivables	4	2
Investments and Long-Term Receivables | Reported Value Measurement | Asset-backed Securities
Debt Securities, Available-for-sale [Line Items]
Investments and Long-Term Receivables	$ 100	$ 63

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Derivative and Financial Instruments - Schedule of Amortized Cost Basis and Fair Value of Investments in Debt Securities Classified as Available for Sale (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	$ 1,218	$ 479
Fair Value	1,210	479
Corporate Bonds
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	604	305
Fair Value	597	304
Commercial Paper
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	335	88
Fair Value	335	89
U.S. Government Obligations
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	163	2
Fair Value	162	2
U.S. Government Agency Obligations
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	10	10
Fair Value	10	10
Foreign Government Obligations
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	6	9
Fair Value	6	9
Asset-backed Securities
Debt Securities, Available-for-sale [Line Items]
Amortized Cost Basis	100	65
Fair Value	$ 100	$ 65

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Fair Value Measurement - Schedule of Fair Value Hierarchy for Gross Financial Assets and Liabilities (Details) - USD ($) $ in Millions	Jun. 30, 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	2,052	1,243
Fair Value, Measurements, Recurring
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	1,117
Investments in debt securities	1,210	479
Commodity derivatives	2,052	1,243
Total assets	3,262	2,839
Commodity derivatives	2,056	1,223
Total liabilities	2,056	1,223
Fair Value, Measurements, Recurring | Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	1,117
Investments in debt securities	162	2
Commodity derivatives	957	562
Total assets	1,119	1,681
Commodity derivatives	1,004	593
Total liabilities	1,004	593
Fair Value, Measurements, Recurring | Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	0
Investments in debt securities	1,048	477
Commodity derivatives	1,037	619
Total assets	2,085	1,096
Commodity derivatives	867	543
Total liabilities	867	543
Fair Value, Measurements, Recurring | Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Investment in Cenovus Energy	0	0
Investments in debt securities	0	0
Commodity derivatives	58	62
Total assets	58	62
Commodity derivatives	185	87
Total liabilities	$ 185	$ 87

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Fair Value Measurement - Schedule of Commodity Derivative Balances Subject to Right of Setoff (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Offsetting Derivative Assets [Abstract]
Assets - gross amounts recognized	$ 2,052	$ 1,243
Assets - amounts without right of setoff	27	85
Assets - gross amounts	2,025	1,158
Assets - gross amounts offset	1,302	650
Assets - net amounts presented	723	508
Assets - cash collateral	0	0
Assets - net amounts	723	508
Offsetting Derivative Liabilities [Abstract]
Liabilities - gross amounts recognized	2,056	1,223
Liabilities - amounts without right of setoff	16	82
Liabilities - gross amounts recognized	2,040	1,141
Liabilities - gross amounts offset	1,302	650
Liabilities - net amounts presented	738	491
Liabilities - cash collateral	48	36
Liabilities - net amounts	$ 690	$ 455

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Fair Value Measurement - Schedule of Net Fair Value of Financial Instruments (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Financial Assets [Abstract]
Investment in Cenovus Energy	$ 0	$ 1,117
Carrying Amount
Financial Assets [Abstract]
Investment in Cenovus Energy	0	1,117
Investments in debt securities	1,210	479
Loans and advances—related parties	59	114
Financial Liabilities [Abstract]
Total debt, excluding finance leases	15,687	18,673
Carrying Amount | Commodity Contract
Financial Assets [Abstract]
Commodity derivatives	750	593
Financial Liabilities [Abstract]
Commodity derivatives	706	537
Estimate of Fair Value Measurement
Financial Assets [Abstract]
Investment in Cenovus Energy	0	1,117
Investments in debt securities	1,210	479
Loans and advances—related parties	59	114
Financial Liabilities [Abstract]
Total debt, excluding finance leases	16,547	22,451
Estimate of Fair Value Measurement | Commodity Contract
Financial Assets [Abstract]
Commodity derivatives	750	593
Financial Liabilities [Abstract]
Commodity derivatives	$ 706	$ 537

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Accumulated Other Comprehensive Loss - Schedule of Components of Accumulated Other Comprehensive Loss in the Equity Section of the Balance Sheet (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance			$ (4,950)
Other comprehensive income	$ (505)	$ 160	(363)	$ 298
Beginning balance	(5,313)		(5,313)
Defined Benefit Plans
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance			(31)
Other comprehensive income			(49)
Beginning balance	(80)		(80)
Net Unrealized Loss on Securities
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance			0
Other comprehensive income			(7)
Beginning balance	(7)		(7)
Foreign Currency Translation
AOCI Attributable to Parent, Net of Tax [Roll Forward]
Beginning balance			(4,919)
Other comprehensive income			(307)
Beginning balance	$ (5,226)		$ (5,226)

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Accumulated Other Comprehensive Loss - Schedule of Items Reclassified out of Accumulated Other Comprehensive Loss (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Accumulated Other Comprehensive Income (Loss), Net of Tax [Abstract]
Defined benefit plans	$ 12	$ 42	$ 16	$ 54
Tax expense of defined benefit plans	$ 3	$ 11	$ 5	$ 15

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Cash Flow Information - Schedule of Cash Flow Information (Details) - USD ($) $ in Millions	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021
Cash Payments
Interest	$ 486	$ 464
Income taxes	3,942	107
Net Sales (Purchases) of Investments
Short-term investments purchased	(1,253)	(5,439)
Short-term investments sold	613	6,842
Long-term investments purchased	(510)	(149)
Long-term investments sold	46	48
Net (purchase) sale of investments	$ (1,104)	$ 1,302

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Cash Flow Information - Narrative (Details) - Concho Resources Inc. $ in Millions	3 Months Ended
	Mar. 31, 2021 USD ($)
Cash and Cash Equivalents [Line Items]
Business combination, consideration transferred, equity interests issued and issuable	$ 13,100
Cash acquired from Concho	$ 382

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Employee Benefit Plans - Schedule of Components of Net Periodic Benefit Cost (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Other Benefits
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	$ 1	$ 1	$ 1	$ 1
Interest cost	1	1	2	2
Expected return on plan assets	0	0	0	0
Amortization of prior service credit	(10)	(10)	(20)	(19)
Recognized net actuarial loss	0	1	0	1
Settlements	0	0	0	0
Curtailments			0	0
Special Termination Benefits			0	0
Net periodic benefit cost	(8)	(7)	(17)	(15)
United States | Pension Benefits
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	16	18	32	39
Interest cost	12	15	24	28
Expected return on plan assets	(13)	(20)	(26)	(44)
Amortization of prior service credit	0	0	0	0
Recognized net actuarial loss	5	12	11	27
Settlements	18	42	22	44
Curtailments			0	12
Special Termination Benefits			0	9
Net periodic benefit cost	38	67	63	115
Int'l. | Pension Benefits
Defined Benefit Plan, Net Periodic Benefit Cost (Credit) [Abstract]
Service cost	13	16	26	31
Interest cost	21	20	42	40
Expected return on plan assets	(34)	(30)	(68)	(60)
Amortization of prior service credit	0	0	0	0
Recognized net actuarial loss	2	8	4	16
Settlements	0	0	0	0
Curtailments			0	0
Special Termination Benefits			0	0
Net periodic benefit cost	$ 2	$ 14	$ 4	$ 27

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Employee Benefit Plans - Narrative (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
United States
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, plan assets, contributions by employer			$ 44
Defined benefit plan, expected future employer contributions, current fiscal year	$ 95		95
United States | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Settlements	18	$ 42	22	$ 44
Increase (decrease) in net pension liability	82
Int'l.
Defined Benefit Plan Disclosure [Line Items]
Defined benefit plan, plan assets, contributions by employer			77
Defined benefit plan, expected future employer contributions, current fiscal year	90		90
Int'l. | Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Settlements	$ 0	$ 0	$ 0	$ 0

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Employee Benefit Plans - Schedule of Discount Rate (Details) - United States	Jun. 30, 2022	Dec. 31, 2021
U.S. qualified pension plan
Defined Benefit Plan Disclosure [Line Items]
Relevant discount rates	4.85%	2.85%
U.S. nonqualified pension plan
Defined Benefit Plan Disclosure [Line Items]
Relevant discount rates	4.70%	2.50%

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Related Party Transactions - Schedule of Significant Transactions with Related Parties (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Significant Transactions with Equity Affiliates
Operating revenues and other income	$ 21	$ 24	$ 43	$ 40
Purchases	0	3	0	3
Operating expenses and selling, general and administrative expenses	44	63	90	89
Net interest (income) expense	$ 0	$ 0	$ (1)	$ (1)

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Sales and Other Operating Revenues - Revenue (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Revenue from contract	$ 16,728	$ 7,753	$ 31,234	$ 14,914
Consolidated sales and other operating revenues	21,161	9,556	38,923	19,382
Physical contracts meeting the definition of a derivative
Revenue from contracts outside the scope of ASC Topic 606	4,411	1,754	7,551	4,728
Crude oil
Revenue from contracts outside the scope of ASC Topic 606	64	178	283	302
Natural gas
Revenue from contracts outside the scope of ASC Topic 606	4,254	1,504	7,027	4,231
Other
Revenue from contracts outside the scope of ASC Topic 606	93	72	241	195
Financial derivative contracts
Revenue from contracts outside the scope of ASC Topic 606	22	49	138	(260)
Lower 48 | Physical contracts meeting the definition of a derivative
Revenue from contracts outside the scope of ASC Topic 606	3,483	1,345	5,927	3,811
Canada | Physical contracts meeting the definition of a derivative
Revenue from contracts outside the scope of ASC Topic 606	807	207	1,367	510
Europe, Middle East and North Africa | Physical contracts meeting the definition of a derivative
Revenue from contracts outside the scope of ASC Topic 606	$ 121	$ 202	$ 257	$ 407

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Sales and Other Operating Revenues - Narrative (Details) - USD ($) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2022	Jun. 30, 2022	Dec. 31, 2021
Revenue from Contract with Customer [Abstract]
Accounts receivable, after allowance for credit loss	$ 6,554	$ 6,554	$ 5,268
Revenue recognized	$ 0	$ 56

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Sales and Other Operating Revenues - Schedule of Contract with Customer, Asset and Liability (Details) $ in Millions	3 Months Ended	6 Months Ended
	Jun. 30, 2022 USD ($)	Jun. 30, 2022 USD ($)
Change in Contract with Customer, Liability [Abstract]
Beginning balance		$ 50
Contractual payments received		25
Revenue recognized	$ 0	(56)
Ending balance	19	19
Noncurrent liabilities	$ 19	$ 19

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Segment Disclosures and Related Information - Narrative (Details)	6 Months Ended
	Jun. 30, 2022 segment
Segment Reporting [Abstract]
Number of operating segments	6

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Segment Disclosures and Related Information - Sales (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	$ 21,161	$ 9,556	$ 38,923	$ 19,382
Lower 48
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	14,458	5,889	26,015	12,402
Canada
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	1,794	802	3,314	1,669
Intersegment eliminations | Lower 48
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	(6)	(2)	(13)	(4)
Intersegment eliminations | Canada
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	(726)	(352)	(1,377)	(657)
Operating Segments
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	21,161	9,556	38,923	19,382
Operating Segments | Alaska
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	2,349	1,418	4,267	2,551
Operating Segments | Lower 48
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	14,452	5,887	26,002	12,398
Operating Segments | Canada
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	1,068	450	1,937	1,012
Operating Segments | Europe, Middle East and North Africa
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	2,652	1,165	5,241	2,143
Operating Segments | Asia Pacific
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	638	630	1,388	1,207
Operating Segments | Other International
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	0	2	0	3
Corporate and Other
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	2	4	88	68
United States
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	16,802	7,308	30,355	15,015
Canada
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	1,069	450	1,938	1,012
China
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	301	171	574	326
Indonesia
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	0	207	159	403
Libya
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	351	290	782	520
Malaysia
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	336	252	654	478
Norway
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	737	618	1,669	1,030
United Kingdom
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	1,564	257	2,790	593
Other foreign countries
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	1	3	2	5
Natural gas
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	7,267	2,812	13,265	7,323
Natural gas liquids
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	1,042	325	1,921	562
Crude oil
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	11,494	5,797	21,364	10,292
Other
Segment Reporting Information [Line Items]
Consolidated sales and other operating revenues	$ 1,358	$ 622	$ 2,373	$ 1,205

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Segment Disclosures and Related Information - Net Income (Loss) (Details) - USD ($) $ in Millions	3 Months Ended		6 Months Ended
	Jun. 30, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Net Income (Loss) Attributable to Parent [Abstract]
Consolidated net income	$ 5,145	$ 2,091	$ 10,904	$ 3,073
Operating Segments | Alaska
Net Income (Loss) Attributable to Parent [Abstract]
Consolidated net income	687	371	1,271	530
Operating Segments | Lower 48
Net Income (Loss) Attributable to Parent [Abstract]
Consolidated net income	3,581	1,175	6,371	1,643
Operating Segments | Canada
Net Income (Loss) Attributable to Parent [Abstract]
Consolidated net income	316	102	607	112
Operating Segments | Europe, Middle East and North Africa
Net Income (Loss) Attributable to Parent [Abstract]
Consolidated net income	385	207	797	360
Operating Segments | Asia Pacific
Net Income (Loss) Attributable to Parent [Abstract]
Consolidated net income	525	175	1,661	492
Operating Segments | Other International
Net Income (Loss) Attributable to Parent [Abstract]
Consolidated net income	0	(5)	0	(9)
Corporate and Other
Net Income (Loss) Attributable to Parent [Abstract]
Consolidated net income	$ (349)	$ 66	$ 197	$ (55)

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Segment Disclosures and Related Information - Assets (Details) - USD ($) $ in Millions	Jun. 30, 2022	Dec. 31, 2021
Total Assets
Total Assets	$ 93,693	$ 90,661
Corporate and Other
Total Assets
Total Assets	9,615	7,745
Alaska | Operating Segments
Total Assets
Total Assets	14,835	14,812
Lower 48 | Operating Segments
Total Assets
Total Assets	43,478	41,699
Canada | Operating Segments
Total Assets
Total Assets	7,358	7,439
Europe, Middle East and North Africa | Operating Segments
Total Assets
Total Assets	8,406	9,125
Asia Pacific | Operating Segments
Total Assets
Total Assets	9,997	9,840
Other International | Operating Segments
Total Assets
Total Assets	$ 4	$ 1

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Income Taxes - Narrative (Details) - USD ($) $ in Millions	3 Months Ended			6 Months Ended
	Jun. 30, 2022	Mar. 31, 2022	Jun. 30, 2021	Jun. 30, 2022	Jun. 30, 2021
Valuation Allowance [Line Items]
Effective tax rate	32.80%		32.10%	29.90%	35.90%
Effective income tax rate reconciliation, tax Settlement, amount		$ 515
Adjustment to valuation allowances increase (decrease)	$ 58		$ (87)	$ 5	$ (151)
Effective income tax rate reconciliation, incremental interest deductions from debt exchanges				$ (37)	$ (75)
Norwegian Tax Administration
Valuation Allowance [Line Items]
Adjustment to valuation allowances increase (decrease)	$ 58