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 September 30, 2021

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 1-8590

MURPHY OIL CORPORATION

(Exact name of registrant as specified in its charter)

Delaware		71-0361522
(State or other jurisdiction of incorporation or organization)		(I.R.S. Employer Identification Number)
9805 Katy Fwy, Suite G-200		77024
Houston,	Texas	(Zip Code)
(Address of principal executive offices)
(281)		675-9000
(Registrant’s telephone number, including area code)

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

Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, $1.00 Par Value	MUR	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, 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. o

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

Number of shares of Common Stock, $1.00 par value, outstanding at October 31, 2021 was 154,459,128.

MURPHY OIL CORPORATION

TABLE OF CONTENTS

	Page
Part I – Financial Information
Item 1.  Financial Statements
Consolidated Balance Sheets	2
Consolidated Statements of Operations	3
Consolidated Statements of Comprehensive Income	4
Consolidated Statements of Cash Flows	5
Consolidated Statements of Stockholders’ Equity	6
Notes to Consolidated Financial Statements	7
Note A – Nature of Business and Interim Financial Statements	7
Note B – New Accounting Principles and Recent Accounting Pronouncements	7
Note C – Revenue from Contracts with Customers	8
Note D – Property, Plant, and Equipment	10
Note E – Discontinued Operations and Assets Held for Sale	12
Note F – Financing Arrangements and Debt	12
Note G – Other Financial Information	13
Note H – Employee and Retiree Benefit Plans	14
Note I – Incentive Plans	14
Note J – Earnings Per Share	16
Note K – Income Taxes	16
Note L – Financial Instruments and Risk Management	17
Note M – Accumulated Other Comprehensive Loss	19
Note N – Environmental and Other Contingencies	19
Note O – Business Segments	20
Item 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations	22
Item 3.  Quantitative and Qualitative Disclosures About Market Risk	35
Item 4.  Controls and Procedures	35
Part II – Other Information	36
Item 1.  Legal Proceedings	36
Item 1A.  Risk Factors	36
Item 2. Unregistered Sales of Equity Securities and Use of Proceeds	36
Item 6.  Exhibits	36
Signature	37

1

PART I – FINANCIAL INFORMATION

ITEM 1.  FINANCIAL STATEMENTS

Murphy Oil Corporation and Consolidated Subsidiaries

CONSOLIDATED BALANCE SHEETS (unaudited)

(Thousands of dollars)	September 30, 2021		December 31, 2020
ASSETS
Current assets
Cash and cash equivalents	$	505,067	310,606
Accounts receivable, less allowance for doubtful accounts of $1,605 in 2021 and 2020	186,683		262,014
Inventories	57,411		66,076
Prepaid expenses	40,583		33,860
Assets held for sale	40,987		327,736
Total current assets	830,731		1,000,292
Property, plant and equipment, at cost less accumulated depreciation, depletion and amortization of $12,268,101 in 2021 and $11,455,305 in 2020	8,112,093		8,269,038
Operating lease assets	918,719		927,658
Deferred income taxes	442,212		395,253
Deferred charges and other assets	27,101		28,611
Total assets	$	10,330,856	10,620,852
LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt, finance lease	$	646	—
Accounts payable	615,436		407,097
Income taxes payable	18,035		18,018
Other taxes payable	26,997		22,498
Operating lease liabilities	157,294		103,758
Other accrued liabilities	316,205		150,578
Liabilities associated with assets held for sale	—		14,372
Total current liabilities	1,134,613		716,321
Long-term debt, including finance lease obligation	2,613,703		2,988,067
Asset retirement obligations	797,627		816,308
Deferred credits and other liabilities	723,732		680,580
Non-current operating lease liabilities	781,114		845,088
Deferred income taxes	166,120		180,341
Total liabilities	6,216,909		6,226,705
Equity
Cumulative Preferred Stock, par $100, authorized 400,000 shares, none issued	—		—
Common Stock, par $1.00, authorized 450,000,000 shares, issued 195,100,628 shares in 2021 and 195,100,628 shares in 2020	195,101		195,101
Capital in excess of par value	921,227		941,692
Retained earnings	5,069,578		5,369,538
Accumulated other comprehensive loss	(580,174)		(601,333)
Treasury stock	(1,656,224)		(1,690,661)
Murphy Shareholders' Equity	3,949,508		4,214,337
Noncontrolling interest	164,439		179,810
Total equity	4,113,947		4,394,147
Total liabilities and equity	$	10,330,856	10,620,852

See Notes to Consolidated Financial Statements, page 7.

2

Murphy Oil Corporation and Consolidated Subsidiaries

CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)

	Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars, except per share amounts)	2021		2020	2021		2020
Revenues and other income
Revenue from sales to customers	$	687,549	425,324	$	2,038,905	1,311,627
(Loss) gain on derivative instruments	(59,164)		(5,290)	(499,794)		319,502
Gain on sale of assets and other income	2,315		1,831	21,217		6,006
Total revenues and other income	630,700		421,865	1,560,328		1,637,135
Costs and expenses
Lease operating expenses	130,131		124,491	403,708		478,283
Severance and ad valorem taxes	11,670		6,781	32,215		22,645
Transportation, gathering and processing	44,588		41,322	137,196		126,779
Exploration expenses, including undeveloped lease amortization	24,517		12,092	49,840		61,686
Selling and general expenses	27,210		28,509	85,826		104,381
Restructuring expenses	—		4,982	—		46,379
Depreciation, depletion and amortization	189,806		231,603	615,372		769,151
Accretion of asset retirement obligations	12,198		10,778	34,854		31,213
Impairment of assets	—		219,138	171,296		1,206,284
Other (benefit) expense	(32,791)		20,224	58,616		(2,957)
Total costs and expenses	407,329		699,920	1,588,923		2,843,844
Operating income (loss) from continuing operations	223,371		(278,055)	(28,595)		(1,206,709)
Other income (loss)
Interest income and other (loss)	(1,593)		(5,177)	(11,459)		(10,107)
Interest expense, net	(46,925)		(45,182)	(178,399)		(124,877)
Total other loss	(48,518)		(50,359)	(189,858)		(134,984)
Income (loss) from continuing operations before income taxes	174,853		(328,414)	(218,453)		(1,341,693)
Income tax expense (benefit)	36,838		(62,584)	(62,498)		(248,890)
Income (loss) from continuing operations	138,015		(265,830)	(155,955)		(1,092,803)
(Loss) from discontinued operations, net of income taxes	(706)		(778)	(600)		(6,907)
Net income (loss) including noncontrolling interest	137,309		(266,608)	(156,555)		(1,099,710)
Less: Net income (loss) attributable to noncontrolling interest	28,853		(23,055)	85,509		(122,869)
NET INCOME (LOSS) ATTRIBUTABLE TO MURPHY	$	108,456	(243,553)	$	(242,064)	(976,841)
INCOME (LOSS) PER COMMON SHARE – BASIC
Continuing operations	$	0.70	(1.58)	$	(1.57)	(6.31)
Discontinued operations	—		(0.01)	—		(0.05)
Net income (loss)	$	0.70	(1.59)	$	(1.57)	(6.36)
INCOME (LOSS) PER COMMON SHARE – DILUTED
Continuing operations	$	0.70	(1.58)	$	(1.57)	(6.31)
Discontinued operations	—		(0.01)	—		(0.05)
Net income (loss)	$	0.70	(1.59)	$	(1.57)	(6.36)
Cash dividends per Common share	$	0.125	0.125	0.375		0.500
Average Common shares outstanding (thousands)
Basic	154,439		153,596	154,239		153,480
Diluted	155,932		153,596	154,239		153,480

See Notes to Consolidated Financial Statements, page 7.

3

Murphy Oil Corporation and Consolidated Subsidiaries

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited)

	Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars)	2021		2020	2021		2020
Net income (loss) including noncontrolling interest	$	137,309	(266,608)	$	(156,555)	(1,099,710)
Other comprehensive (loss) income, net of tax
Net (loss) gain from foreign currency translation	(31,308)		28,323	6,534		(39,520)
Retirement and postretirement benefit plans	4,653		3,726	12,935		(45,219)
Deferred loss on interest rate hedges reclassified to interest expense	—		297	1,690		905
Other comprehensive (loss) income	(26,655)		32,346	21,159		(83,834)
COMPREHENSIVE INCOME (LOSS)	$	110,654	(234,262)	$	(135,396)	(1,183,544)

See Notes to Consolidated Financial Statements, page 7.

4

Murphy Oil Corporation and Consolidated Subsidiaries

CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Operating Activities
Net income (loss) including noncontrolling interest	$	(156,555)	(1,099,710)
Adjustments to reconcile net income (loss) to net cash provided by continuing operations activities
Loss from discontinued operations	600		6,907
Depreciation, depletion and amortization	615,372		769,151
Dry hole and previously suspended exploration costs	17,899		8,255
Amortization of undeveloped leases	13,872		21,951
Accretion of asset retirement obligations	34,854		31,213
Impairment of assets	171,296		1,206,284
Noncash restructuring expense	—		17,565
Deferred income tax (benefit) expense	(65,149)		(231,748)
Mark to market loss (gain) on contingent consideration	105,111		(29,476)
Mark to market loss (gain) on derivative instruments	228,497		(104,463)
Long-term non-cash compensation	42,080		35,200
Net decrease (increase) in noncash working capital	117,330		(26,261)
Other operating activities, net	(33,924)		(26,837)
Net cash provided by continuing operations activities	1,091,283		578,031
Investing Activities
Property additions and dry hole costs	(564,230)		(648,725)
Property additions for King's Quay FPS	(17,734)		(74,936)
Proceeds from sales of property, plant and equipment	270,038		—
Net cash required by investing activities	(311,926)		(723,661)
Financing Activities
Borrowings on revolving credit facility	165,000		450,000
Repayment of revolving credit facility	(365,000)		(250,000)
Retirement of debt	(726,358)		(12,225)
Debt issuance, net of cost	541,913		(613)
Early redemption of debt cost	(36,756)		—
Distributions to noncontrolling interest	(100,880)		(43,673)
Cash dividends paid	(57,896)		(76,790)
Withholding tax on stock-based incentive awards	(4,973)		(7,094)
Capital lease obligation payments	(643)		(514)
Net cash (required) provided by financing activities	(585,593)		59,091
Cash Flows from Discontinued Operations 1
Operating activities	—		(1,202)
Investing activities	—		4,494
Financing activities	—		—
Net cash provided by discontinued operations	—		3,292
Effect of exchange rate changes on cash and cash equivalents	697		(585)
Net increase (decrease) in cash and cash equivalents	194,461		(87,124)
Cash and cash equivalents at beginning of period	310,606		306,760
Cash and cash equivalents at end of period	$	505,067	219,636

1  Net cash provided by discontinued operations is not part of the cash flow reconciliation. See Notes to Consolidated Financial Statements, page 7.

5

Murphy Oil Corporation and Consolidated Subsidiaries

CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY (unaudited)

	Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars)	2021		2020	2021		2020
Cumulative Preferred Stock – par $100, authorized 400,000 shares, none issued	$	—	—	$	—	—
Common Stock – par $1.00, authorized 450,000,000 shares, issued 195,100,628 shares at September 30, 2021 and 195,100,628 shares at September 30, 2020
Balance at beginning of period	195,101		195,101	195,101		195,089
Exercise of stock options	—		—	—		12
Balance at end of period	195,101		195,101	195,101		195,101
Capital in Excess of Par Value
Balance at beginning of period	915,181		931,429	941,692		949,445
Exercise of stock options, including income tax benefits	(35)		—	(661)		(156)
Restricted stock transactions and other	(402)		(409)	(38,749)		(33,649)
Share-based compensation	6,483		5,298	18,945		20,678
Balance at end of period	921,227		936,318	921,227		936,318
Retained Earnings
Balance at beginning of period	4,980,428		5,823,426	5,369,538		6,614,304
Net (loss) attributable to Murphy	108,456		(243,553)	(242,064)		(976,841)
Cash dividends	(19,306)		(19,200)	(57,896)		(76,790)
Balance at end of period	5,069,578		5,560,673	5,069,578		5,560,673
Accumulated Other Comprehensive Loss
Balance at beginning of period	(553,519)		(690,341)	(601,333)		(574,161)
Foreign currency translation gain (loss), net of income taxes	(31,308)		28,323	6,534		(39,520)
Retirement and postretirement benefit plans, net of income taxes	4,653		3,726	12,935		(45,219)
Deferred loss on interest rate hedges reclassified to interest expense, net of income taxes	—		297	1,690		905
Balance at end of period	(580,174)		(657,995)	(580,174)		(657,995)
Treasury Stock
Balance at beginning of period	(1,656,591)		(1,691,070)	(1,690,661)		(1,717,217)
Awarded restricted stock, net of forfeitures	343		409	33,888		26,556
Exercise of stock options	24		—	549		—
Balance at end of period – 40,656,661 shares of Common Stock in 2021 and 41,502,003 shares of Common Stock in 2020, at cost	(1,656,224)		(1,690,661)	(1,656,224)		(1,690,661)
Murphy Shareholders’ Equity	3,949,508		4,343,436	3,949,508		4,343,436
Noncontrolling Interest
Balance at beginning of period	161,228		204,937	179,810		337,151
Net income (loss) attributable to noncontrolling interest	28,853		(23,055)	85,509		(122,869)
Distributions to noncontrolling interest owners	(25,642)		(11,273)	(100,880)		(43,673)
Balance at end of period	164,439		170,609	164,439		170,609
Total Equity	$	4,113,947	4,514,045	$	4,113,947	4,514,045

See Notes to Consolidated Financial Statements, page 7.

6

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS

These notes are an integral part of the financial statements of Murphy Oil Corporation and Consolidated Subsidiaries (Murphy/ Company) on pages 2 through 6 of this Form 10-Q report.

Note A – Nature of Business and Interim Financial Statements

NATURE OF BUSINESS – Murphy Oil Corporation is an international oil and natural gas exploration and production company that conducts its business through various operating subsidiaries.  The Company primarily produces oil and natural gas in the United States and Canada and conducts oil and natural gas exploration activities worldwide.

In connection with the LLOG Exploration Offshore L.L.C. and LLOG Bluewater Holdings, L.L.C., (LLOG) acquisition, we hold a 0.5% interest in two variable interest entities (VIEs), Delta House Oil and Gas Lateral LLC and Delta House Floating Production System (FPS) LLC (collectively Delta House). These VIEs have not been consolidated because we are not considered the primary beneficiary. These non-consolidated VIEs are not material to our financial position or results of operations. As of September 30, 2021, our maximum exposure to loss was $3.4 million (excluding operational impacts), which represents our net investment in Delta House. We have not provided any financial support to Delta House other than amounts previously required by our membership interest.

INTERIM FINANCIAL STATEMENTS – In the opinion of Murphy’s management, the unaudited financial statements presented herein include all accruals necessary to present fairly the Company’s financial position at September 30, 2021 and December 31, 2020, and the results of operations, cash flows and changes in stockholders’ equity for the interim periods ended September 30, 2021 and 2020, in conformity with accounting principles generally accepted in the United States of America (U.S.).  In preparing the financial statements of the Company in conformity with accounting principles generally accepted in the U.S., management has made a number of estimates and assumptions related to the reporting of assets, liabilities, revenues, and expenses and the disclosure of contingent assets and liabilities.  Actual results may differ from the estimates.

Consolidated financial statements and notes to consolidated financial statements included in this Form 10-Q report should be read in conjunction with the Company’s 2020 Form 10-K report, as certain notes and other pertinent information have been abbreviated or omitted in this report.  Financial results for the three-month and nine-month periods ended September 30, 2021 are not necessarily indicative of future results.

Note B – New Accounting Principles and Recent Accounting Pronouncements

Accounting Principles Adopted

Income Taxes. In December 2019, the FASB issued ASU 2019-12, which removes certain exceptions for investments, intraperiod allocations and interim calculations, and adds guidance to reduce complexity in accounting for income taxes. The amendments in this ASU are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. Implementation on a prospective or retrospective basis varies by specific topics within the ASU. The Company adopted this guidance in the first quarter of 2021 and it did not have a material impact on its consolidated financial statements.

Recent Accounting Pronouncements

None affecting the Company.

7

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note C – Revenue from Contracts with Customers

Nature of Goods and Services

The Company explores for and produces crude oil, natural gas and natural gas liquids (collectively oil and natural gas) in select basins around the globe. The Company’s revenue from sales of oil and natural gas production activities are primarily subdivided into two key geographic segments: the U.S. and Canada.  Additionally, revenue from sales to customers is generated from three primary revenue streams: crude oil and condensate, natural gas liquids, and natural gas.

For operated oil and natural gas production where the non-operated working interest owner does not take-in-kind its proportionate interest in the produced commodity, the Company acts as an agent for the working interest owner and recognizes revenue only for its own share of the commingled production. The exception to this is the reporting of the noncontrolling interest in MP GOM as prescribed by ASC 810-10-45.

U.S. - In the United States, the Company primarily produces oil and natural gas from fields in the Eagle Ford Shale area of South Texas and in the Gulf of Mexico.  Revenue is generally recognized when oil and natural gas are transferred to the customer at the delivery point. Revenue recognized is largely index based with price adjustments for floating market differentials.

Canada - In Canada, contracts include long-term floating commodity index priced and natural gas physical forward sales fixed-price contracts. For the Offshore business in Canada, contracts are based on index prices and revenue is recognized at the time of vessel load based on the volumes on the bill of lading and point of custody transfer.

8

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note C – Revenue from Contracts with Customers (Contd.)

Disaggregation of Revenue

The Company reviews performance based on two key geographical segments and between onshore and offshore sources of revenue within these geographies.

For the three-month and nine-month periods ended September 30, 2021, the Company recognized $687.5 million and $2,038.9 million, respectively, from contracts with customers for the sales of oil, natural gas liquids and natural gas. For the three-month and nine-month periods ended September 30, 2020, the Company recognized $425.3 million and $1,311.6 million, respectively, from contracts with customers for the sales of oil, natural gas liquids and natural gas.

		Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars)		2021		2020	2021	2020
Net crude oil and condensate revenue
United States	Onshore	$	167,010	86,498	464,767	272,284
	Offshore	340,001		216,918	1,079,418	714,143
Canada	Onshore	29,110		32,358	89,708	67,268
	Offshore	20,499		19,173	70,333	54,864
Other		—		—	—	1,806
Total crude oil and condensate revenue		556,620		354,947	1,704,226	1,110,365
Net natural gas liquids revenue
United States	Onshore	16,356		6,766	33,480	16,145
	Offshore	11,046		4,765	31,866	13,255
Canada	Onshore	4,501		2,780	11,728	6,090
Total natural gas liquids revenue		31,903		14,311	77,074	35,490
Net natural gas revenue
United States	Onshore	11,127		4,529	24,442	14,177
	Offshore	17,444		9,827	56,855	35,487
Canada	Onshore	70,455		41,710	176,308	116,108
Total natural gas revenue		99,026		56,066	257,605	165,772
Total revenue from contracts with customers		687,549		425,324	2,038,905	1,311,627
(Loss) gain on derivative instruments		(59,164)		(5,290)	(499,794)	319,502
Gain on sale of assets and other income		2,315		1,831	21,217	6,006
Total revenue and other income		$	630,700	421,865	1,560,328	1,637,135

Contract Balances and Asset Recognition

As of September 30, 2021, and December 31, 2020, receivables from contracts with customers, net of royalties and associated payables, on the balance sheet from continuing operations, were $144.0 million and $135.2 million, respectively. Payment terms for the Company’s sales vary across contracts and geographical regions, with the majority of the cash receipts required within 30 days of billing. Based on a forward-looking expected loss model in accordance with ASU 2016-13, the Company did not recognize any impairment losses on receivables or contract assets arising from customer contracts during the reporting periods.

The Company has not entered into any revenue contracts that have financing components as at September 30, 2021.

The Company does not employ sales incentive strategies such as commissions or bonuses for obtaining sales contracts. For the periods presented, the Company did not identify any assets to be recognized associated with the costs to obtain a contract with a customer.

9

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note C – Revenue from Contracts with Customers (Contd.)

Performance Obligations

The Company recognizes oil and natural gas revenue when it satisfies a performance obligation by transferring control over a commodity to a customer.  Judgment is required to determine whether some customers simultaneously receive and consume the benefit of commodities. As a result of this assessment for the Company, each unit of measure of the specified commodity is considered to represent a distinct performance obligation that is satisfied at a point in time upon the transfer of control of the commodity.

For contracts with market or index-based pricing, which represent the majority of sales contracts, the Company has elected the allocation exception and allocates the variable consideration to each single performance obligation in the contract. As a result, there is no price allocation to unsatisfied remaining performance obligations for delivery of commodity product in subsequent periods.

The Company has entered into several long-term, fixed-price contracts in Canada. The underlying reason for entering a fixed price contract is generally unrelated to anticipated future prices or other observable data and serves a particular purpose in the company’s long-term strategy.

As of September 30, 2021, the Company had the following sales contracts in place which are expected to generate revenue from sales to customers for a period of more than 12 months starting at the inception of the contract:

Current Long-Term Contracts Outstanding at September 30, 2021
Location	Commodity	End Date		Description	Approximate Volumes
U.S.	Oil	Q4 2021		Fixed quantity delivery in Eagle Ford	17,000 BOED
U.S.	Natural Gas and NGL	Q1 2023		Deliveries from dedicated acreage in Eagle Ford	As produced
Canada	Natural Gas	Q4 2021		Contracts to sell natural gas at USD index pricing	10 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at USD index pricing	8 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at CAD fixed prices	5 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at USD fixed pricing	20 MMCFD
Canada	Natural Gas	Q4 2023	1	Contracts to sell natural gas at USD index pricing	25 MMCFD
Canada	Natural Gas	Q4 2023		Contracts to sell natural gas at CAD fixed prices	38 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at USD index pricing	31 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at CAD fixed prices	100 MMCFD
Canada	Natural Gas	Q4 2024	1	Contracts to sell natural gas at CAD fixed prices	34 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at USD fixed pricing	15 MMCFD
Canada	Natural Gas	Q4 2026	1	Contracts to sell natural gas at USD index pricing	49 MMCFD

1 These contracts are scheduled to commence after the balance sheet date, at various dates between Q4 2021 and Q1 2022.

Fixed price contracts are accounted for as normal sales and purchases for accounting purposes.

Note D – Property, Plant, and Equipment

Exploratory Wells

Under FASB guidance exploratory well costs should continue to be capitalized when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the Company is making sufficient progress assessing the reserves and the economic and operating viability of the project.

As of September 30, 2021, the Company had total capitalized exploratory well costs for continuing operations pending the determination of proved reserves of $186.6 million.  The following table reflects the net changes in capitalized exploratory well costs during the nine-month periods ended September 30, 2021 and 2020.

10

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note D – Property, Plant and Equipment (Contd.)

(Thousands of dollars)	2021		2020
Beginning balance at January 1	$	181,616	217,326
Additions pending the determination of proved reserves	5,007		9,941
Capitalized exploratory well costs charged to expense	—		(39,408)
Balance at September 30	$	186,623	187,859

The capitalized well costs charged to expense during 2020 represent a charge for asset impairments (see below).

The following table provides an aging of capitalized exploratory well costs based on the date the drilling was completed for each individual well and the number of projects for which exploratory well costs have been capitalized.  The projects are aged based on the last well drilled in the project.

	September 30,
	2021				2020
(Thousands of dollars)	Amount		No. of Wells	No. of Projects	Amount	No. of Wells	No. of Projects
Aging of capitalized well costs:
Zero to one year	$	3,297	2	2	8,000	1	—
One to two years	—		—	—	54,334	5	5
Two to three years	53,078		5	5	—	—	—
Three years or more	130,248		6	—	125,525	6	—
	$	186,623	13	7	187,859	12	5

Of the $183.3 million of exploratory well costs capitalized more than one year at September 30, 2021, $92.3 million is in Vietnam, $45.0 million is in the U.S., $25.9 million is in Brunei, $15.3 million is in Mexico, and $4.8 million is in Canada.  In all geographical areas, either further appraisal or development drilling is planned and/or development studies/plans are in various stages of completion. 

Impairments

During the first quarter of 2021, the Company recorded an impairment charge of $171.3 million for Terra Nova due to the status, including agreements with the partners, of operating and production plans.

In 2020, declines in future oil and natural gas prices (principally driven by reduced demand from the COVID-19 pandemic) led to impairments in certain of the Company’s U.S. Offshore and Other Foreign properties. The Company recorded pretax noncash impairment charges of $1,206.3 million to reduce the carrying values to their estimated fair values at select properties.

The fair values were determined by internal discounted cash flow models using estimates of future production, prices, costs and discount rates believed to be consistent with those used by principal market participants in the applicable region.

The following table reflects the recognized impairments for the nine months ended September 30, 2021 and 2020.

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
U.S.	$	—	1,152,515
Canada	171,296		—
Other Foreign	—		39,709
Corporate	—		14,060
	$	171,296	1,206,284

Divestments

During the first quarter of 2021, the King’s Quay FPS was sold to ArcLight Capital Partners, LLC (ArcLight) for proceeds of $267.7 million, which reimburses the Company for previously incurred capital expenditures.

11

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note E – Assets Held for Sale and Discontinued Operations

The Company has accounted for its former U.K. and U.S. refining and marketing and Malaysian exploration and production operations as discontinued operations for all periods presented.  The results of operations associated with discontinued operations for the three-month and nine-month periods ended September 30, 2021 and 2020 were as follows:

	Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars)	2021		2020	2021		2020
Revenues	$	144	—	$	801	4,074
Costs and expenses
Other costs and expenses (benefits)	850		778	1,401		10,981
(Loss) income before taxes	(706)		(778)	(600)		(6,907)
Income tax expense	—		—	—		—
(Loss) income from discontinued operations	$	(706)	(778)	$	(600)	(6,907)

As of September 30, 2021, assets held for sale on the Consolidated Balance Sheet include the carrying value of the net property, plant equipment of CA-2 project in Brunei and the Company’s office building in El Dorado, Arkansas. As of June 30, 2021, the CA-1 asset in Brunei is no longer being marketed for sale.

As of December 31, 2020, assets held for sale included the King’s Quay Floating Production System (FPS) of $250.1 million (sold in March 2021), the Brunei exploration and production properties, and the Company’s office building in El Dorado, Arkansas.

(Thousands of dollars)	September 30, 2021		December 31, 2020
Current assets
Cash	$	—	10,185
Inventories	—		406
Property, plant, and equipment, net	40,987		307,704
Deferred income taxes and other assets	—		9,441
Total current assets associated with assets held for sale	$	40,987	327,736
Current liabilities
Accounts payable	$	—	5,306
Other accrued liabilities	—		45
Current maturities of long-term debt (finance lease)	—		737
Taxes payable	—		1,510
Long-term debt (finance lease)	—		6,513
Asset retirement obligation	—		261
Total current liabilities associated with assets held for sale	$	—	14,372

Note F – Financing Arrangements and Debt

As of September 30, 2021, the Company had a $1.6 billion revolving credit facility (RCF). The RCF is a senior unsecured guaranteed facility which expires in November 2023. At September 30, 2021, the Company had no outstanding borrowings under the RCF and $31.4 million of outstanding letters of credit, which reduce the borrowing capacity of the RCF. At September 30, 2021, the interest rate in effect on borrowings under the facility was 1.78%. At September 30, 2021, the Company was in compliance with all covenants related to the RCF.

In March 2021, the Company issued $550.0 million of new notes that bear interest at a rate of 6.375% and mature on July 15, 2028. The Company incurred transaction costs of $8.1 million on the issuance of these new notes and the Company will pay interest semi-annually on January 15 and July 15 of each year, beginning July 15, 2021. The proceeds of the $550.0 million notes, along with cash on hand, were used to redeem and cancel $259.3 million of the Company’s 4.00% notes due June 2022 and $317.1 million of the Company’s 4.95% notes due December 2022 (originally issued as 3.70% notes due 2022; collectively

12

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note F – Financing Arrangements and Debt (Contd.)

the 2022 Notes). The cost of the debt extinguishment of $36.9 million is included in Interest expense, net on the Consolidated Statement of Operations for the nine months ended September 30, 2021. The cash costs of $34.2 million are shown as a financing activity on the Consolidated Statement of Cash Flows for the nine months ended September 30, 2021.

In August 2021, the Company redeemed $150.0 million aggregate principal amount of its 6.875% senior notes due 2024 (2024 Notes). The cost of the debt extinguishment of $3.5 million is included in Interest expense, net on the Consolidated Statement of Operations for the nine months ended September 30, 2021. The cash costs of $2.6 million are shown as a financing activity on the Consolidated Statement of Cash Flows for the nine months ended September 30, 2021.

The Company also has a shelf registration statement on file with the U.S. Securities and Exchange Commission that permits the offer and sale of debt and/or equity securities through October 15, 2024.

Subsequent to quarter end, the Company issued a notice of partial redemption with respect to $150.0 million aggregate principal amount of its 6.875% senior notes due 2024 (2024 Notes). The Company will redeem the 2024 Notes at the applicable redemption price set forth in the indenture governing the 2024 Notes, plus accrued and unpaid interest, if any, to the date of redemption. The redemption date of the 2024 Notes will be December 2, 2021.

Note G – Other Financial Information

Additional disclosures regarding cash flow activities are provided below.

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Net (increase) decrease in operating working capital, excluding cash and cash equivalents:
Decrease in accounts receivable ¹	$	75,100	251,706
Decrease in inventories	9,718		4,747
(Increase) in prepaid expenses	(6,682)		(17,400)
Increase (decrease) in accounts payable and accrued liabilities ¹	40,687		(264,078)
(Decrease) in income taxes payable	(1,493)		(1,236)
Net (increase) decrease in noncash operating working capital	$	117,330	(26,261)
Supplementary disclosures:
Cash income taxes paid, net of refunds	$	1,685	(12,559)
Interest paid, net of amounts capitalized of $11.6 million in 2021 and $5.9 million in 2020	127,793		139,651
Non-cash investing activities:
Asset retirement costs capitalized ²	$	36,300	6,342
Decrease in capital expenditure accrual	31,301		74,742

1 Excludes receivable/payable balances relating to mark-to-market of derivative instruments and contingent consideration relating to acquisitions.

2 Excludes non-cash capitalized cost offset by impairment of $74.4 million in the first quarter of 2021 and a gain in other operating income of $71.8 million following a commercial agreement to sanction an asset life extension project at Terra Nova in the third quarter of 2021, which extended the life of Terra Nova by approximately 10 years.

13

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note H – Employee and Retiree Benefit Plans

The Company has defined benefit pension plans that are principally noncontributory and cover most full-time employees.  All pension plans are funded except for the U.S. and Canadian nonqualified supplemental plan and the U.S. director’s plan.  All U.S. tax qualified plans meet the funding requirements of federal laws and regulations.  Contributions to foreign plans are based on local laws and tax regulations.  The Company also sponsors health care and life insurance benefit plans, which are not funded, that cover most retired U.S. employees.  The health care benefits are contributory; the life insurance benefits are noncontributory.

The table that follows provides the components of net periodic benefit expense for the three-month and nine-month periods ended September 30, 2021 and 2020.

	Three Months Ended September 30,
	Pension Benefits			Other Postretirement Benefits
(Thousands of dollars)	2021		2020	2021	2020
Service cost	$	1,770	1,664	328	342
Interest cost	4,258		4,827	521	612
Expected return on plan assets	(6,038)		(5,773)	—	—
Amortization of prior service cost (credit)	155		149	—	—
Recognized actuarial loss	5,269		5,690	(8)	(24)
Net periodic benefit expense	$	5,414	6,557	841	930
	Nine Months Ended September 30,
	Pension Benefits			Other Postretirement Benefits
(Thousands of dollars)	2021		2020	2021	2020
Service cost	$	5,306	5,996	981	1,235
Interest cost	12,844		16,381	1,563	2,200
Expected return on plan assets	(18,326)		(18,414)	—	—
Amortization of prior service cost (credit)	467		515	—	—
Recognized actuarial loss	15,829		14,223	(23)	(24)
Net periodic benefit expense	$	16,120	18,701	2,521	3,411
Other - curtailment	—		586	—	(1,825)
Other - special termination benefits	—		8,435	—	—
Total net periodic benefit expense	$	16,120	27,722	2,521	1,586

The components of net periodic benefit expense, other than the service cost, curtailment and special termination benefits components, are included in the line item “Interest and other income (loss)” in Consolidated Statements of Operations.

During the nine-month period ended September 30, 2021, the Company made contributions of $31.0 million to its defined benefit pension and postretirement benefit plans. Remaining funding in 2021 for the Company’s defined benefit pension and postretirement plans is anticipated to be $10.9 million.

Note I – Incentive Plans

The costs resulting from all share-based and cash-based incentive plans are recognized as an expense in the Consolidated Statements of Operations using a fair value-based measurement method over the periods that the awards vest.

The 2017 Annual Incentive Plan (2017 Annual Plan) authorizes the Executive Compensation Committee (the Committee) to establish specific performance goals associated with annual cash awards that may be earned by officers, executives and certain other employees.  Cash awards under the 2017 Annual Plan are determined based on the Company’s actual financial and operating results as measured against the performance goals established by the Committee. 

The 2020 Long-Term Incentive Plan (2020 Long-Term Plan) authorizes the Committee to make grants of the Company’s Common Stock to employees.  These grants may be in the form of stock options (nonqualified or incentive), stock appreciation rights (SAR), restricted stock, restricted stock units (RSU), performance units, performance shares, dividend equivalents and

14

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

other stock-based incentives.  The 2020 Long-Term Plan expires in 2030.  A total of five million shares are issuable during the life of the 2020 Long-Term Plan. Shares issued pursuant to awards granted under this Plan may be shares that are authorized and unissued or shares that were reacquired by the Company, including shares purchased in the open market. Share awards that have been canceled, expired, forfeited or otherwise not issued under an award shall not count as shares issued under this Plan.

During the first nine months of 2021, the Committee granted the following awards from the 2020 Long-Term Plan:

2020 Long-Term Incentive Plan

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Performance Based RSUs 1	1,156,800	February 2, 2021	$	16.03	Monte Carlo at Grant Date
Time Based RSUs 2	385,600	February 2, 2021	$	12.30	Average Stock Price at Grant Date
Cash Settled RSUs 3	1,022,700	February 2, 2021	$	12.30	Average Stock Price at Grant Date

1 Performance based RSUs are scheduled to vest over a three year performance period.

2 Time based RSUs are generally scheduled to vest over three years from the date of grant.

3 Cash settled RSUs are scheduled to vest over three years from the date of grant.

The Company also has a Stock Plan for Non-Employee Directors that permits the issuance of restricted stock, restricted stock units and stock options or a combination thereof to the Company’s Non-Employee Directors.

At the Company’s annual stockholders’ meeting held on May 12, 2021, shareholders approved the replacement of the 2018 Stock Plan for Non-Employee Directors (2018 NED Plan) with the 2021 Stock Plan for Non-Employee Directors (2021 NED Plan). The 2021 NED Plan permits the issuance of restricted stock, restricted stock units and stock options or a combination thereof to the Company’s Non-Employee Directors. The Company currently has outstanding incentive awards issued to Directors under the 2021 NED Plan and the 2018 NED Plan. All awards on or after May 12, 2021, will be made under the 2021 NED Plan.

During the first nine months of 2021, the Committee granted the following awards to Non-Employee Directors:

2018 Stock Plan for Non-Employee Directors

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Time Based RSUs 1	182,652	February 3, 2021	$	13.14	Closing Stock Price at Grant Date

1 Non-employee directors time-based RSUs are scheduled to vest in February 2022.

2021 Stock Plan for Non-Employee Directors

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Time Based RSUs 1	5,655	June 10, 2021	$	23.58	Closing Stock Price at Grant Date

1 Non-employee directors time-based RSUs are scheduled to vest in February 2022.

All stock option exercises are non-cash transactions for the Company.  The employee receives net shares, after applicable withholding obligations, upon each stock option exercise. The actual income tax benefit realized from the tax deductions related to stock option exercises of the share-based payment arrangements were immaterial for the nine-month period ended September 30, 2021.

Amounts recognized in the financial statements with respect to share-based plans are shown in the following table:

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Compensation charged against income before tax benefit	$	29,145	17,542
Related income tax benefit recognized in income	4,120		2,278

Certain incentive compensation granted to the Company’s named executive officers, to the extent their total compensation exceeds $1.0 million per executive per year, is not eligible for a U.S. income tax deduction under the Tax Cuts and Jobs Act (2017 Tax Act).

15

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note J – Earnings Per Share

Net (loss) income attributable to Murphy was used as the numerator in computing both basic and diluted income per Common share for the three-month and nine-month periods ended September 30, 2021 and 2020.  The following table reports the weighted-average shares outstanding used for these computations.

	Three Months Ended September 30,		Nine Months Ended September 30,
(Weighted-average shares)	2021	2020	2021	2020
Basic method	154,439,313	153,596,109	154,239,440	153,479,654
Dilutive stock options and restricted stock units ¹	1,492,949	—	—	—
Diluted method	155,932,262	153,596,109	154,239,440	153,479,654

1 Due to a net loss recognized by the Company for the nine-month period ended September 30, 2021 and the three-month and nine-month periods ended September 30, 2020, no unvested stock awards were included in the computation of diluted earnings per share because the effect would have been antidilutive.

The following table reflects certain options to purchase shares of common stock that were outstanding during the periods presented but were not included in the computation of diluted shares above because the incremental shares from the assumed conversion were antidilutive.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Antidilutive stock options excluded from diluted shares	1,316,222		2,111,068		1,502,758		2,305,973
Weighted average price of these options	$	34.42	$	38.54	$	34.97	$	40.15

Note K – Income Taxes

The Company’s effective income tax rate is calculated as the amount of income tax expense (benefit) divided by income (loss) from continuing operations before income taxes.  For the three-month and nine-month periods ended September 30, 2021 and 2020, the Company’s effective income tax rates were as follows:

	2021	2020
Three months ended September 30,	21.1%	19.1%
Nine months ended September 30,	28.6%	18.6%

The effective tax rate for the three-month period ended September 30, 2021 was above the U.S. statutory tax rate of 21% primarily due to income generated in Canada, which has a higher tax rate, offset by no tax applied to the pre-tax income of the noncontrolling interest in MP GOM, which has the impact of decreasing the effective tax rate on income.

The effective tax rate for the three-month period ended September 30, 2020 was below the statutory tax rate of 21% due to exploration expenses in certain foreign jurisdictions in which no income tax benefit is available, as well as no tax benefit available from the pre-tax loss of the noncontrolling interest in MP GOM.

The effective tax rate for the nine-month period ended September 30, 2021 was above the U.S. statutory tax rate of 21% primarily due to no tax applied to the pre-tax income of the noncontrolling interest in MP GOM, which has the impact of increasing the effective tax rate on an overall loss.

The effective tax rate for the nine-month period ended September 30, 2020 was below the statutory tax rate of 21% due to exploration expenses in certain foreign jurisdictions in which no income tax benefit is available, as well as no tax benefit available from the pre-tax loss of the noncontrolling interest in MP GOM. These items reduced the tax credit on a reported pre-tax net loss.

The Company’s tax returns in multiple jurisdictions are subject to audit by taxing authorities, and currently the Company is under audit in several of these jurisdictions.  These audits often take multiple years to complete and settle.  Although the Company believes that recorded liabilities for unsettled issues are adequate, additional gains or losses could occur in future years from resolution of outstanding unsettled matters.  As of September 30, 2021, the earliest years remaining open for audit and/or settlement in our major taxing jurisdictions are as follows: United States – 2016; Canada – 2016; Malaysia – 2014; and

16

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note K– Income Taxes (Contd.)

United Kingdom – 2018. Following the divestment of Malaysia in the third quarter of 2019, the Company has retained certain possible liabilities and rights to income tax receivables relating to Malaysia for the years prior to 2019. The Company believes current recorded liabilities are adequate.

Note L – Financial Instruments and Risk Management

Murphy uses derivative instruments, such as swaps and zero-cost commodity price collar contracts, to manage certain risks related to commodity prices, foreign currency exchange rates and interest rates.  The use of derivative instruments for risk management is covered by operating policies and is closely monitored by the Company’s senior management.  The Company does not hold any derivatives for speculative purposes and it does not use derivatives with leveraged or complex features.  Derivative instruments are traded with creditworthy major financial institutions or over national exchanges such as the New York Mercantile Exchange (NYMEX).  The Company has a risk management control system to monitor commodity price risks and any derivatives obtained to manage a portion of such risks.  For accounting purposes, the Company has not designated commodity and foreign currency derivative contracts as hedges, and therefore, it recognizes all gains and losses on these derivative contracts in its Consolidated Statements of Operations.  

Certain interest rate derivative contracts were previously accounted for as hedges and the gain or loss associated with recording the fair value of these contracts was deferred in Accumulated other comprehensive loss and amortized to the income statement over time. During the nine-month period ended September 30, 2021, the Company redeemed all of the remaining notes due 2022 and expensed the remainder of the previously deferred loss on the interest rate swap of $2.1 million to Interest expense in the Consolidated Statement of Operations.

Commodity Price Risks

The Company has entered into crude oil swaps and collar contracts. Under the swaps contracts, which mature monthly, the Company pays the average monthly price in effect and receives the fixed contract price on a notional amount of sales volume, thereby fixing the price for the commodity sold. Under the collar contracts, which also mature monthly, the Company purchased a put option and sold a call option with no net premiums paid to or received from counterparties. Upon maturity, collar contracts require payments by the Company if the NYMEX average closing price is above the ceiling price or payments to the Company if the NYMEX average closing price is below the floor price.

At September 30, 2021, volumes per day associated with outstanding crude oil derivative contracts and the weighted average prices for these contracts are as follows:

	September 30, 2021
	2021		2022
NYMEX WTI swap contracts:
Volume per day (Bbl):	45,000		20,000
Price per Bbl:	$	42.77	$	44.88
NYMEX WTI collar contracts:
Volume per day (Bbl):	—		16,000
Price per Bbl:
Ceiling:	$	—	$	71.83
Floor:	—		60.38

Foreign Currency Exchange Risks

The Company is subject to foreign currency exchange risk associated with operations in countries outside the U.S. The Company had no foreign currency exchange derivatives outstanding at September 30, 2021 and 2020.

At September 30, 2021 and December 31, 2020, the fair value of derivative instruments not designated as hedging instruments are presented in the following table.

17

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note L – Financial Instruments and Risk Management (Contd.)

	September 30, 2021			December 31, 2020
(Thousands of dollars)	Asset (Liability) Derivatives			Asset (Liability) Derivatives
Type of Derivative Contract	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity swaps	Accounts receivable	$	—	Accounts receivable	13,050
	Accounts payable	(312,448)		Accounts payable	(89,842)
	Deferred credits and other liabilities	(41,645)		Deferred credits and other liabilities	(12,833)
Commodity collars	Accounts receivable	—		Accounts receivable	—
	Accounts payable	(15,929)		Accounts payable	—

For the three-month and nine-month periods ended September 30, 2021 and 2020, the gains and losses recognized in the Consolidated Statements of Operations for derivative instruments not designated as hedging instruments are presented in the following table.

		Gain (Loss)			Gain (Loss)
(Thousands of dollars)	Statement of Operations Location	Three Months Ended September 30,			Nine months ended September 30,
Type of Derivative Contract		2021		2020	2021	2020
Commodity swaps	(Loss) gain on derivative instruments	$	(43,235)	(5,290)	(483,865)	319,502
Commodity collars	(Loss) gain on derivative instruments	(15,929)		—	(15,929)	—

Fair Values – Recurring

The Company carries certain assets and liabilities at fair value in its Consolidated Balance Sheets.  The fair value hierarchy is based on the quality of inputs used to measure fair value, with Level 1 being the highest quality and Level 3 being the lowest quality.  Level 1 inputs are quoted prices in active markets for identical assets or liabilities.  Level 2 inputs are observable inputs other than quoted prices included within Level 1.  Level 3 inputs are unobservable inputs which reflect assumptions about pricing by market participants.

The carrying value of assets and liabilities recorded at fair value on a recurring basis at September 30, 2021 and December 31, 2020, are presented in the following table.

	September 30, 2021					December 31, 2020
(Thousands of dollars)	Level 1		Level 2	Level 3	Total	Level 1	Level 2	Level 3	Total
Assets:
Commodity swaps	$	—	—	—	—	—	13,050	—	13,050
	$	—	—	—	—	—	13,050	—	13,050
Liabilities:
Commodity collars	$	—	15,929	—	15,929	—	—	—	—
Nonqualified employee savings plan	17,180		—	—	17,180	14,988	—	—	14,988
Commodity swaps	—		354,093	—	354,093	—	102,675	—	102,675
Contingent consideration	—		—	238,115	238,115	—	—	133,004	133,004
	$	17,180	370,022	238,115	625,317	14,988	102,675	133,004	250,667

The fair value of commodity (WTI crude oil) derivative contracts in 2021 and 2020 were based on active market quotes for WTI crude oil.  The before tax income effect of changes in the fair value of crude oil derivative contracts is recorded in Gain (loss) on derivative instruments in the Consolidated Statements of Operations. 

The nonqualified employee savings plan is an unfunded savings plan through which participants seek a return via phantom investments in equity securities and/or mutual funds.  The fair value of this liability was based on quoted prices for these equity securities and mutual funds.  The income effect of changes in the fair value of the nonqualified employee savings plan is recorded in Selling and general expenses in the Consolidated Statements of Operations. 

18

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note L – Financial Instruments and Risk Management (Contd.)

The contingent consideration, related to two acquisitions in 2019 and 2018, is valued using a Monte Carlo simulation model. The income effect of changes in the fair value of the contingent consideration is recorded in Other expense (benefit) in the Consolidated Statements of Operations. Contingent consideration is payable annually in years 2022 to 2026.

The Company offsets certain assets and liabilities related to derivative contracts when the legal right of offset exists. There were no offsetting positions recorded at September 30, 2021 and December 31, 2020.

Note M – Accumulated Other Comprehensive Loss

The components of Accumulated other comprehensive loss on the Consolidated Balance Sheets at December 31, 2020 and September 30, 2021 and the changes during the nine-month period ended September 30, 2021, are presented net of taxes in the following table.

(Thousands of dollars)	Foreign Currency Translation Gains (Losses)		Retirement and Postretirement Benefit Plan Adjustments		Deferred Loss on Interest Rate Derivative Hedges		Total
Balance at December 31, 2020	$	(324,011)	(275,632)		(1,690)		(601,333)
Components of other comprehensive income (loss):
Before reclassifications to income and retained earnings	6,534		—		—		6,534
Reclassifications to income	—		12,935	¹	1,690	²	14,625
Net other comprehensive income (loss)	6,534		12,935		1,690		21,159
Balance at September 30, 2021	$	(317,477)	(262,697)		—		(580,174)

1 Reclassifications before taxes of $16,282 are included in the computation of net periodic benefit expense for the nine-month period ended September 30, 2021.  See Note H for additional information.  Related income taxes of $3,347 are included in Income tax expense (benefit) for the nine-month period ended September 30, 2021.

2 Reclassifications before taxes of $2,140 are included in Interest expense, net, for the nine-month period ended September 30, 2021.  Related income taxes of $450 are included in Income tax expense (benefit) for the nine-month period ended September 30, 2021. See Note L for additional information.

Note N – Environmental and Other Contingencies

The Company’s operations and earnings have been and may be affected by various forms of governmental action both in the United States and throughout the world.  Examples of such governmental action include, but are by no means limited to:  tax legislation changes, including tax rate changes, and retroactive tax claims; royalty and revenue sharing increases; import and export controls; price controls; currency controls; allocation of supplies of crude oil and petroleum products and other goods; expropriation of property; restrictions and preferences affecting the issuance of oil and natural gas or mineral leases; restrictions on drilling and/or production; laws and regulations intended for the promotion of safety and the protection and/or remediation of the environment; governmental support for other forms of energy; and laws and regulations affecting the Company’s relationships with employees, suppliers, customers, stockholders and others. Governmental actions are often motivated by political considerations and may be taken without full consideration of their consequences or may be taken in response to actions of other governments.  It is not practical to attempt to predict the likelihood of such actions, the form the actions may take or the effect such actions may have on the Company.

ENVIRONMENTAL, HEALTH AND SAFETY MATTERS – Murphy and other companies in the oil and natural gas industry are subject to numerous federal, state, local and foreign laws and regulations dealing with the environment and protection of health and safety. The principal environmental, health and safety laws and regulations to which Murphy is subject address such matters as the generation, storage, handling, use, disposal and remediation of petroleum products, wastewater and hazardous materials; the emission and discharge of such materials to the environment, including greenhouse gas emissions; wildlife, habitat and water protection; the placement, operation and decommissioning of production equipment; and the health and

safety of our employees, contractors and communities where our operations are located. These laws and regulations also generally require permits for existing operations, as well as the construction or development of new operations and the decommissioning facilities once production has ceased.

Violation of environmental, health and safety laws, regulations and permits can result in the imposition of significant civil and criminal penalties, injunctions and construction bans or delays. A discharge of hazardous substances into the environment

19

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

Note N– Environmental and Other Contingencies (Contd.)

could, to the extent such event is not insured, subject the Company to substantial expense, including both the cost to comply with applicable laws and regulations and claims by neighboring landowners and other third parties for any personal injury and property damage that might result. Item 103 of SEC Regulation S-K requires disclosure of certain environmental matters when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that the Company reasonably believes will exceed a specified threshold. Pursuant to recent SEC amendments to this item, the Company will be using a threshold of $1.0 million for such proceedings.

The Biden administration has indicated that it intends to increase regulatory oversight of the oil and gas industry, with a focus on climate change and greenhouse gas emissions (including methane emissions). The Biden administration has issued a number of executive orders that address climate change, including creation of climate-related task forces, directives to federal agencies to procure carbon-free electricity, and a goal of a carbon pollution-free power sector by 2035 and a net-zero emissions U.S. economy by 2050. The Biden administration has also issued orders related to oil and gas activities on federal lands, infrastructure and environmental justice. In addition, an international climate agreement (the Paris Agreement) was agreed to at the 2015 United Nations Framework Convention on Climate Change in Paris, France. The Paris Agreement entered into force in November 2016. Although the U.S. officially withdrew from the Paris Agreement on November 4, 2020, on January 20, 2021, President Biden began the 30-day process of rejoining the Paris Agreement, which became effective for the U.S. on February 19, 2021.

The Company currently owns or leases, and has in the past owned or leased, properties at which hazardous substances have been or are being handled. Hazardous substances may have been disposed of or released on or under the properties owned or leased by the Company or on or under other locations where these wastes have been taken for disposal. In addition, many of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons or other wastes were not under Murphy’s control. Under existing laws, the Company could be required to investigate, remove or remediate previously disposed wastes (including wastes disposed of or released by prior owners or operators), to investigate and clean up contaminated property (including contaminated groundwater) or to perform remedial plugging operations to prevent future contamination. Certain of these historical properties are in various stages of negotiation, investigation, and/or cleanup, and the Company is investigating the extent of any such liability and the availability of applicable defenses. The Company has retained certain liabilities related to environmental matters at formerly owned U.S. refineries that were sold in 2011. The Company also obtained insurance covering certain levels of environmental exposures related to past operations of these refineries. Murphy USA Inc. has retained any environmental exposure associated with Murphy’s former U.S. marketing operations that were spun-off in August 2013. The Company believes costs related to these sites will not have a material adverse effect on Murphy’s net income, financial condition or liquidity in a future period.

There is the possibility that environmental expenditures could be required at currently unidentified sites, and additional expenditures could be required at known sites. However, based on information currently available to the Company, the amount of future investigation and remediation costs incurred at known or currently unidentified sites is not expected to have a material adverse effect on the Company’s future net income, cash flows or liquidity.

LEGAL MATTERS – Murphy and its subsidiaries are engaged in a number of other legal proceedings, all of which Murphy considers routine and incidental to its business. Based on information currently available to the Company, the ultimate resolution of environmental and legal matters referred to in this note is not expected to have a material adverse effect on the Company’s net income, financial condition or liquidity in a future period.

Note O – Business Segments

Information about business segments and geographic operations is reported in the following table.  For geographic purposes, revenues are attributed to the country in which the sale occurs.  Corporate, including interest income, other gains and losses (including foreign exchange gains/losses and realized and unrealized gains/losses on crude oil contracts), interest expense and unallocated overhead, is shown in the tables to reconcile the business segments to consolidated totals.

20

NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)

	Total Assets at September 30, 2021		Three Months Ended September 30, 2021		Three Months Ended September 30, 2020
(Millions of dollars)			External Revenues	Income (Loss)	External Revenues	Income (Loss)
Exploration and production ¹
United States	$	6,586.3	565.2	168.1	330.8	(172.6)
Canada	2,241.2		124.6	73.9	96.3	(8.6)
Other	264.6		—	(5.2)	—	(11.7)
Total exploration and production	9,092.1		689.8	236.8	427.1	(192.9)
Corporate	1,237.8		(59.1)	(98.8)	(5.2)	(72.9)
Continuing operations	10,329.9		630.7	138.0	421.9	(265.8)
Discontinued operations, net of tax	1.0		—	(0.7)	—	(0.8)
Total	$	10,330.9	630.7	137.3	421.9	(266.6)
			Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
(Millions of dollars)			External Revenues	Income (Loss)	External Revenues	Income (Loss)
Exploration and production ¹
United States			1,704.4	481.8	1,070.6	(1,011.7)
Canada			349.2	(37.7)	245.2	(35.0)
Other			—	(22.5)	1.8	(73.0)
Total exploration and production			2,053.6	421.6	1,317.6	(1,119.7)
Corporate			(493.3)	(577.6)	319.5	26.9
Continuing operations			1,560.3	(156.0)	1,637.1	(1,092.8)
Discontinued operations, net of tax			—	(0.6)	—	(6.9)
Total			1,560.3	(156.6)	1,637.1	(1,099.7)

1 Additional details about results of oil and natural gas operations are presented in the table on pages 25 and 26.

21

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS

Summary

In 2021, the global distribution and administration of vaccinations in response to the ongoing coronavirus disease 2019 (COVID-19) pandemic has led to an improving global economic outlook and subsequently increased demand for oil and gas. Emerging COVID-19 variants, such as the Delta variant, continue to create uncertainty in the outlook, however in 2021 demand for oil and gas has remained resilient. The demand resilience has revealed an oil supply shortage, and hence is applying upward pressure to current and future oil and gas prices.

The OPEC+ group of oil producing countries (OPEC+) continues to target increasing supply by 0.4 million bpd a month, with aims to fully phase out prior cuts by September 2022, at the current rate of OPEC+ supply increases. In 2020 OPEC+ cut production by 10 million barrels per day (bpd) following the COVID-19 demand reduction. It has gradually reinstated supply so that the curtailments are approximately 5.8 million bpd at the end of September 2021. However, some members of the OPEC+ are falling short on supply increases.

Overall, the combination of OPEC+ supply constraints and the increase in demand driven by the global COVID-19 vaccine roll out has provided upward pressure to the oil price which directly impacts the Company’s product revenue from sales compared to one year ago.

For the three months ended September 30, 2021, West Texas Intermediate (WTI) crude oil prices averaged approximately $70.56 per barrel (compared to $66.07 in the second quarter of 2021 and $40.93 in the third quarter of 2020). The closing price for WTI at the end of the third quarter of 2021 was approximately $71.54 per barrel, reflecting a modest increase from the second quarter 2021 closing price and an 81% increase from the third quarter 2020 closing price. The average price in October 2021 was $81.22 per barrel. As of close on November 2, 2021, the NYMEX WTI forward curve price for the remainder of 2021 and 2022 were $83.91 and $76.27 per barrel, respectively.

In the third quarter of 2021, the Company continued to delever by redeeming $150.0 million aggregate principal amount of its 6.875% senior notes due 2024 for the principal amount plus cash costs of $2.6 million. Earlier in 2021, the Company executed a series of financial transactions which redeemed the remaining notes due 2022 and issued new 7 year senior unsecured notes maturing in July 2028. The 2022 notes were redeemed for total use of funds of $619.5 million, which included redemption at par of $576.4 million, early retirement premium (make whole payment) of $34.2 million, and $8.9 million of accrued interest. The 2028 notes were issued for total proceeds of $550.0 million and closing costs of $8.1 million. The proceeds from issue are reported net of costs to issue on the Consolidated Balance Sheets.

In the third quarter of 2021, the Company acquired an additional 7.525% working interest at Terra Nova in Canada following a commercial agreement to sanction an asset life extension project. This transaction deferred an asset obligation at Terra Nova by approximately 10 years and decreased the obligation associated with the abandonment liability of the working interest before the acquisition by approximately $72 million.

For the three months ended September 30, 2021, the Company produced 163 thousand barrels of oil equivalent per day (including noncontrolling interest) from continuing operations; this includes the impact of Hurricane Ida on U.S. Gulf of Mexico production of 14.5 thousand barrels of oil equivalent per day (including NCI).  The Company invested $110.5 million in capital expenditures (on a value of work done basis) in the three months ended September 30, 2021. The Company reported net income from continuing operations of $138.0 million for the three months ended September 30, 2021. This amount includes income attributable to noncontrolling interest of $28.9 million, after-tax gains on unrealized mark to market revaluations on commodity price swap and collar positions of $44.1 million, an after-tax non-cash credit of $53.6 million related to the deferral of asset retirement obligations and after-tax losses on contingent consideration of $22.4 million.

For the nine months ended September 30, 2021, the Company produced 170 thousand barrels of oil equivalent per day (including noncontrolling interest) from continuing operations; this includes the impact of Hurricane Ida on U.S. Gulf of Mexico production of 4.9 thousand barrels of oil equivalent per day (including NCI).  The Company invested $568.7 million in capital expenditures (on a value of work done basis) in the nine months ended September 30, 2021, which included $18.0 million to fund the development of the King’s Quay Floating Production System (FPS). The FPS capital expenditures were reimbursed by Arclight in the first quarter of 2021 (see below). The Company reported net loss from continuing operations of $156.0 million for the nine months ended September 30, 2021. This amount includes income attributable to noncontrolling interest of $85.5 million, after-tax impairment charges of $128.0 million, an after-tax non-cash credit of $53.6 million related to the deferral of asset retirement obligations and after-tax losses on unrealized mark to market revaluations on commodity price swap and collar positions and contingent consideration of $180.5 million and $83.0 million, respectively.

22

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Summary (contd.)

For the three months ended September 30, 2020, the Company produced 163 thousand barrels of oil equivalent per day (including noncontrolling interest) from continuing operations.  The Company invested $122.7 million in capital expenditures (on a value of work done basis), in the third quarter of 2020, which included $19.3 million to fund the development of the King’s Quay FPS. The Company reported net loss from continuing operations of $265.8 million for the third quarter of 2020. This amount included loss attributable to noncontrolling interest of $23.1 million, after-tax impairment charges of $145.9 million and after-tax losses on unrealized mark to market revaluations on commodity price hedge positions and contingent consideration of $54.8 million and $11.1 million, respectively.

For the nine months ended September 30, 2020, the Company produced 180 thousand barrels of oil equivalent per day (including noncontrolling interest) from continuing operations. The Company invested $680.3 million in capital expenditures (on a value of work done basis) for the nine months ended September 30, 2020, which included $80.7 million to fund the development of the King’s Quay FPS. The Company reported net loss from continuing operations of $1,092.8 million for the nine months ended September 30, 2020. This amount included loss attributable to noncontrolling interest of $122.9 million, after-tax impairment charges of $854.2 million and after-tax gains on unrealized mark to market revaluations on commodity price hedge positions and contingent consideration of $82.5 million and $23.3 million, respectively.

In the first quarter, the Company’s subsidiary "Murphy Exploration & Production Company USA" closed a transaction with ArcLight Capital Partners, LLC (ArcLight) for the sale of Murphy’s entire 50% interest in the King’s Quay FPS and associated export lateral pipelines. The transaction reimbursed Murphy for its share of project costs from inception to closing with proceeds of $267.7 million.

Results of Operations

Murphy’s income (loss) by type of business is presented below.

	Income (Loss)
	Three Months Ended September 30,			Nine Months Ended September 30,
(Millions of dollars)	2021		2020	2021	2020
Exploration and production	$	236.8	(192.9)	421.6	(1,119.7)
Corporate and other	(98.8)		(72.9)	(577.6)	26.9
Income (loss) from continuing operations	138.0		(265.8)	(156.0)	(1,092.8)
Discontinued operations ¹	(0.7)		(0.8)	(0.6)	(6.9)
Net income (loss) including noncontrolling interest	$	137.3	(266.6)	(156.6)	(1,099.7)

1 The Company has presented its former U.K. and U.S. refining and marketing and Malaysian exploration and production operations as discontinued operations in its consolidated financial statements. 

Exploration and Production

Results of E&P continuing operations are presented by geographic segment below.

	Income (Loss)
	Three Months Ended September 30,			Nine Months Ended September 30,
(Millions of dollars)	2021		2020	2021	2020
Exploration and production
United States	$	168.1	(172.6)	481.8	(1,011.7)
Canada	73.9		(8.6)	(37.7)	(35.0)
Other	(5.2)		(11.7)	(22.5)	(73.0)
Total	$	236.8	(192.9)	421.6	(1,119.7)

23

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Results of Operations (contd.)

Other key performance metrics

The Company uses other operational performance and income metrics to review operational performance. The table below presents Earnings before interest, taxes, depreciation and amortization (EBITDA) and adjusted EBITDA. Management uses EBITDA and adjusted EBITDA internally to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. EBITDA and adjusted EBITDA are non-GAAP financial measures and should not be considered a substitute for Net income (loss) or Cash provided by operating activities as determined in accordance with accounting principles generally accepted in the United States of America. Also presented below is adjusted EBITDA per barrel of oil equivalent sold, a non-GAAP financial metric. Management uses EBITDA per barrel of oil equivalent sold to evaluate the Company’s profitability of one barrel of oil equivalent sold in the period.

	Three Months Ended September 30,			Nine Months Ended September 30,
(Millions of dollars, except per barrel of oil equivalents sold)	2021		2020	2021	2020
Net income (loss) attributable to Murphy (GAAP)	$	108.5	(243.6)	(242.1)	(976.8)
Income tax expense (benefit)	36.8		(62.6)	(62.5)	(248.9)
Interest expense, net	46.9		45.2	178.4	124.9
Depreciation, depletion and amortization expense ¹	182.8		219.7	588.4	725.1
EBITDA attributable to Murphy (Non-GAAP)	375.0		(41.3)	462.2	(375.7)
Mark-to-market (gain) loss on derivative instruments	(55.9)		69.3	228.5	(104.5)
Impairment of assets ¹	—		186.5	171.3	1,072.5
Mark-to-market loss (gain) on contingent consideration	28.4		14.0	105.1	(29.5)
Asset retirement obligation (gains) losses	(71.8)		—	(71.8)	—
Accretion of asset retirement obligations ¹	10.8		10.8	30.8	31.2
Unutilized rig charges	3.2		5.2	8.5	13.2
Foreign exchange (gains) losses	(2.8)		0.8	(1.5)	(2.5)
Discontinued operations loss	0.7		0.8	0.6	6.9
Restructuring expenses	—		5.0	—	46.4
Inventory loss	—		—	—	4.8
Seal insurance proceeds	—		(1.7)	—	(1.7)
Adjusted EBITDA attributable to Murphy (Non-GAAP)	$	287.6	249.4	933.7	661.1
Total barrels of oil equivalents sold from continuing operations attributable to Murphy (thousands of barrels)	14,219		14,166	43,536	46,478
Adjusted EBITDA per barrel of oil equivalents sold	$	20.23	17.61	21.45	14.22

1 Depreciation, depletion, and amortization expense, impairment of assets and accretion of asset retirement obligations used in the computation of Adjusted EBITDA exclude the portion attributable to the non-controlling interest.

24

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Results of Operations (contd.)

OIL AND GAS OPERATING RESULTS – THREE MONTHS ENDED SEPTEMBER 30, 2021 AND 2020

(Millions of dollars)	United States 1		Canada	Other	Total
Three Months Ended September 30, 2021
Oil and gas sales and other operating revenues	$	565.2	124.6	—	689.8
Lease operating expenses	96.7		33.4	0.1	130.2
Severance and ad valorem taxes	10.8		0.8	—	11.6
Transportation, gathering and processing	28.4		16.2	—	44.6
Depreciation, depletion and amortization	147.0		39.7	0.1	186.8
Accretion of asset retirement obligations	9.3		2.9	—	12.2
Exploration expenses
Dry holes and previously suspended exploration costs	17.3		—	—	17.3
Geological and geophysical	—		—	0.3	0.3
Other exploration	1.3		0.1	0.5	1.9
	18.6		0.1	0.8	19.5
Undeveloped lease amortization	3.1		0.1	1.8	5.0
Total exploration expenses	21.7		0.2	2.6	24.5
Selling and general expenses	4.2		4.0	1.2	9.4
Other ²	39.1		(71.7)	2.0	(30.6)
Results of operations before taxes	208.0		99.1	(6.0)	301.1
Income tax provisions (benefits)	39.9		25.2	(0.8)	64.3
Results of operations (excluding Corporate segment)	$	168.1	73.9	(5.2)	236.8
Three Months Ended September 30, 2020
Oil and gas sales and other operating revenues	$	330.8	96.3	—	427.1
Lease operating expenses	91.5		32.6	0.4	124.5
Severance and ad valorem taxes	6.4		0.3	—	6.7
Transportation, gathering and processing	29.3		12.0	—	41.3
Depreciation, depletion and amortization	166.2		59.6	0.5	226.3
Accretion of asset retirement obligations	9.4		1.4	—	10.8
Impairment of assets	205.1		—	—	205.1
Exploration expenses
Dry holes and previously suspended exploration costs	0.6		—	—	0.6
Geological and geophysical	0.1		—	(0.1)	—
Other exploration	0.6		0.1	3.6	4.3
	1.3		0.1	3.5	4.9
Undeveloped lease amortization	4.9		0.1	2.3	7.3
Total exploration expenses	6.2		0.2	5.8	12.2
Selling and general expenses	5.3		3.4	1.6	10.3
Other	22.5		(1.5)	2.5	23.5
Results of operations before taxes	(211.1)		(11.7)	(10.8)	(233.6)
Income tax (benefits) provisions	(38.5)		(3.1)	0.9	(40.7)
Results of operations (excluding Corporate segment)	$	(172.6)	(8.6)	(11.7)	(192.9)

1 Includes results attributable to a noncontrolling interest in MP GOM.

2 For the three months ended September 30, 2021, Canada includes $71.8 million of income related to the deferral of an asset retirement obligation at Terra Nova.

25

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Results of Operations (contd.)

OIL AND GAS OPERATING RESULTS – NINE MONTHS ENDED SEPTEMBER 30, 2021 AND 2020

(Millions of dollars)	United States 1		Canada	Other	Total
Nine Months Ended September 30, 2021
Oil and gas sales and other operating revenues	$	1,704.4	349.2	—	2,053.6
Lease operating expenses	303.3		100.0	0.4	403.7
Severance and ad valorem taxes	30.6		1.6	—	32.2
Transportation, gathering and processing	90.5		46.7	—	137.2
Depreciation, depletion and amortization	476.6		128.0	1.1	605.7
Accretion of asset retirement obligations	27.5		7.4	—	34.9
Impairment of assets	—		171.3	—	171.3
Exploration expenses
Dry holes and previously suspended exploration costs	17.9		—	—	17.9
Geological and geophysical	2.7		—	1.3	4.0
Other exploration	4.2		0.2	9.6	14.0
	24.8		0.2	10.9	35.9
Undeveloped lease amortization	7.9		0.2	5.8	13.9
Total exploration expenses	32.7		0.4	16.7	49.8
Selling and general expenses	15.0		12.0	4.7	31.7
Other ²	133.5		(67.7)	(1.2)	64.6
Results of operations before taxes	594.7		(50.5)	(21.7)	522.5
Income tax provisions (benefits)	112.9		(12.8)	0.8	100.9
Results of operations (excluding Corporate segment)	$	481.8	(37.7)	(22.5)	421.6
Nine months ended September 30, 2020
Oil and gas sales and other operating revenues	$	1,070.6	245.2	1.8	1,317.6
Lease operating expenses	386.5		90.6	1.2	478.3
Severance and ad valorem taxes	21.6		1.0	—	22.6
Transportation, gathering and processing	95.4		31.4	—	126.8
Depreciation, depletion and amortization	589.5		161.3	1.5	752.3
Accretion of asset retirement obligations	27.1		4.1	—	31.2
Impairment of assets	1,152.5		—	39.7	1,192.2
Exploration expenses
Dry holes and previously suspended exploration costs	8.3		—	—	8.3
Geological and geophysical	9.4		0.1	4.1	13.6
Other exploration	4.3		0.4	13.1	17.8
	22.0		0.5	17.2	39.7
Undeveloped lease amortization	14.8		0.3	6.9	22.0
Total exploration expenses	36.8		0.8	24.1	61.7
Selling and general expenses	16.6		13.2	5.5	35.3
Other	1.0		(2.5)	1.4	(0.1)
Results of operations before taxes	(1,256.4)		(54.7)	(71.6)	(1,382.7)
Income tax provisions (benefits)	(244.7)		(19.7)	1.4	(263.0)
Results of operations (excluding Corporate segment)	$	(1,011.7)	(35.0)	(73.0)	(1,119.7)

1 Includes results attributable to a noncontrolling interest in MP GOM.

2 For the nine months ended September 30, 2021, Canada includes $71.8 million of income related to the deferral of an asset retirement obligation at Terra Nova.

26

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Results of Operations (contd.)

Exploration and Production

Third quarter 2021 vs. 2020

All amounts include amount attributable to a noncontrolling interest in MP GOM, unless otherwise noted.

United States E&P operations reported earnings of $168.1 million in the third quarter of 2021 compared to a loss of $172.6 million in the third quarter of 2020.  Results were $340.7 million favorable in the 2021 quarter compared to the 2020 period primarily due to higher revenues ($234.4 million), lower impairment charge ($205.1 million) and depreciation, depletion and amortization (DD&A: $19.2 million), partially offset by higher income tax expense ($78.4 million), other operating expense ($16.6 million) and exploration expense ($15.5 million). Higher revenues were primarily due to higher commodity prices. The production impact of Hurricane Ida in the third quarter of 2021 is offset by the impact of multiple storms that occurred in the third quarter of 2020. Lower impairment charges were due to impairment charges recognized in the prior period related to Gulf of Mexico Cascade & Chinook field and no such charges in current period. Lower DD&A is a result of the prior year impairment charge reducing the depreciable asset base. Higher income tax expense is a result of pre-tax profits principally due to the recovering oil price. Higher other operating expense is primarily due to unfavorable mark to market revaluation on contingent consideration (as a result of higher commodity prices) related to prior Gulf of Mexico (GOM) acquisitions. Higher exploration expense is primarily due to dry hole costs related to Silverback in the current period.

Canadian E&P operations reported earnings of $73.9 million in the third quarter 2021 compared to a loss of $8.6 million in the third quarter of 2020. Results were favorable $82.5 million compared to the 2020 period primarily due to a credit of $71.8 million reported in ‘other operating expense’ as a result of the deferral of an asset retirement obligation at Terra Nova following the sanction of an asset life extension project. Results were also favorably impacted by higher revenue ($28.3 million) and lower DD&A ($19.9 million), partially offset by higher tax expense ($28.3 million) and higher transportation, gathering and processing ($4.2 million). Higher revenue is primarily attributable to higher natural gas prices and higher natural gas volumes at Tupper Montney. Lower DD&A is due to lower production volumes at Kaybob Duvernay due to normal well decline. Higher transportation, gathering and processing costs are due to higher gas processing and downstream transportation capacity, which are expected to be utilized by growth at Tupper Montney in the future.

Other international E&P operations reported a loss from continuing operations of $5.2 million in the third quarter of 2021 compared to a loss of $11.7 million in the third quarter of 2020.  The result was $6.5 million favorable in the 2021 period versus 2020 primarily due lower exploration expenses in Brazil and Mexico.

Nine months 2021 vs. 2020

All amounts include amount attributable to a noncontrolling interest in MP GOM, unless otherwise noted.

United States E&P operations reported earnings of $481.8 million in the first nine months of 2021 compared to a loss of $1,011.7 million in the first nine months of 2020.  Results were $1,493.5 million favorable in 2021 period compared to the 2020 period primarily due to no impairment charges in the current period (2020: $1,152.5 million). Further, the change year over year is driven by higher revenues ($633.8 million), lower DD&A ($112.9 million), lower lease operating expenses (LOE: $83.2 million), partially offset by higher income tax expense ($357.6 million) and higher other operating expense ($132.5 million). The impairment charge in the prior year was primarily the result of lower forecast future prices as of March 31, 2020, as a result of lower oil demand (COVID-19 impact) and abundant oil supply at the time of the assessment. Higher revenues are primarily attributable to higher realized prices (oil and condensate, natural gas and NGLs) in 2021 compared to 2020. The production impact of Hurricane Ida in the third quarter of 2021 is offset by the impact of multiple storms that occurred in 2020. Lower DD&A is a result of the prior year impairment charge reducing the depreciable asset base. Lower lease operating expenses were primarily due to higher GOM workover costs in the prior year at Cascade ($51.3 million) and Dalmatian ($20.5 million). Higher income tax expense is a result of higher pre-tax income principally due to higher oil price and lower DD&A and LOE. Higher other operating expense is primarily due to an unfavorable mark to market revaluation on contingent consideration ($105.1 million; as a result of higher commodity prices) from prior GOM acquisitions.

Canadian E&P operations reported a loss of $37.7 million in the first nine months of 2021 compared to a loss of $35.0 million in the first nine months of 2020.  Results were comparable year over year. 2021 results include an impairment charge ($171.3 million) recorded in the first quarter following notice from the operator of asset abandonment at Terra Nova at the time of the assessment and a partially offsetting credit of $71.8 million as of September 30, 2021 reported in ‘other operating expense’ as a result of the deferral of an asset retirement obligation at Terra Nova following the sanction of an asset life extension project. The current year results also include higher revenue ($104.0 million) and lower DD&A ($33.3 million) offset by higher transportation, gathering and processing expenses ($15.3 million) and lease operating expenses ($9.4 million). Higher revenue is primarily attributable to higher natural gas prices and volumes at Tupper Montney and higher oil prices at Hibernia and Kaybob Duvernay. Lower DD&A is primarily due to lower production volumes at Kaybob Duvernay following reduced capital

27

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Results of Operations (contd.)

expenditures throughout 2020. Higher lease operating expenses and transportation, gathering and processing costs are due to higher gas processing and downstream transportation capacity, which are expected to be utilized by growth at Tupper Montney in the future.

Other international E&P operations reported a loss of $22.5 million in the first nine months of 2021 compared to a loss of $73.0 million in the prior year. Results were $50.5 million favorable compared to the 2020 period primarily due to no repeat of an impairment charge of $39.7 million in the prior year.

Corporate

Third quarter 2021 vs. 2020

Corporate activities, which include interest expense and income, foreign exchange effects, realized and unrealized gains/losses on derivative instruments (forward swaps and collars to hedge/fix the price of oil sold) and corporate overhead not allocated to Exploration and Production, reported a loss of $98.8 million in the third quarter of 2021 compared to net loss of $72.9 million in the third quarter of 2020. The $25.9 million unfavorable variance is principally due to higher net losses on derivative instruments in 2021 compared to the 2020 period (2021: $59.2 million loss; 2020: $5.3 million loss), partially offset by lower impairment charges ($14.1 million), higher tax benefits ($5.7 million), lower restructuring charges ($5.0 million), and lower DD&A ($2.3 million). Realized and unrealized losses on derivative instruments are due to an increase in market pricing in future periods whereby the swap contracts provide the Company with a fixed price and the collar contracts provide for a minimum (floor) and a maximum (ceiling) price. Lower impairment and restructuring charges are due to the 2020 cost reduction efforts which included closing the Company’s previous headquarters office in El Dorado, Arkansas, its office in Calgary, Alberta, and consolidating all worldwide staff activities to its existing office location in Houston, Texas. Higher income tax benefit is a result of higher pre-tax loss driven by the higher realized and unrealized losses on derivative instruments.

Nine months 2021 vs. 2020

Corporate activities, which include interest expense and income, foreign exchange effects, realized and unrealized gains/losses on derivative instruments (forward swaps and collars to hedge/fix the price of oil sold) and corporate overhead not allocated to Exploration and Production, reported a loss of $577.6 million in the first nine months of 2021 compared to earnings of $26.9 million in the first nine months of 2020. The $604.5 million unfavorable variance is primarily due to realized and unrealized losses on derivative instruments in 2021 compared to gains in 2020 (2021: $499.8 million loss; 2020: $319.5 million gain), and higher interest expense ($54.1 million), partially offset by higher tax benefits ($177.6 million), lower restructuring charges ($46.4 million), lower G&A ($15.0 million), lower impairment charges ($14.1 million) and lower DD&A ($7.2 million). Realized and unrealized losses on derivative instruments are due to an increase in market pricing in future periods whereby the swap contracts provide the Company with a fixed price and the collar contracts provide for a minimum (floor) and a maximum (ceiling) price. As of September 30, 2021, the average forward NYMEX WTI price for the remainder of 2021 was $74.87 and for 2022 was $70.87 (versus swap contract fixed hedge prices of $42.77 and $44.88, respectively). Interest charges are higher in 2021 primarily due an early redemption premium incurred by the Company upon the early retirement of the notes originally due June and December 2022. Higher income tax benefit is a result of pre-tax losses driven by the higher realized and unrealized losses on derivative instruments. Lower restructuring charges, G&A expenditures and impairment charges are due to the 2020 cost reduction efforts which included closing its previous headquarters office in El Dorado, Arkansas, its office in Calgary, Alberta, and consolidating all worldwide staff activities to its existing office location in Houston, Texas.

Production Volumes and Prices

Third quarter 2021 vs. 2020

Total hydrocarbon production from continuing operations averaged 163,224 barrels of oil equivalent per day in the third quarter of 2021, which was in line with the 162,824 barrels per day produced in third quarter 2020. U.S. Gulf of Mexico production in the current year was impacted by Hurricane Ida and the prior year was impacted by multiple storms. The estimated storm impact in the third quarter of 2021 was 14,542 barrels of oil equivalent per day (including NCI) and 14,230 barrels of oil equivalent per day (including NCI) in the third quarter of 2020.

Average crude oil and condensate production from continuing operations was 88,245 barrels per day in the third quarter of 2021 compared to 95,391 barrels per day in the third quarter of 2020. The decrease of 7,146 barrels per day was associated with lower volumes in Canada (5,281 barrels per day lower primarily attributable to Kaybob Duvernay well decline), lower volumes in the Gulf of Mexico (3,506 barrels per day principally due to facility shut-ins as a result of Hurricane Ida), offset by higher Eagle Ford Shale production (1,342 barrels per day higher at Karnes due to 2021 capital expenditures in this area). On a

28

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Results of Operations (contd.)

worldwide basis, the Company’s crude oil and condensate prices averaged $68.88 per barrel in the third quarter 2021 compared to $39.79 per barrel in the 2020 period, an increase of 73% quarter over quarter.

Total production of natural gas liquids (NGL) from continuing operations was 10,391 barrels per day in the third quarter 2021 compared to 10,523 barrels per day in the 2020 period. The average sales price for U.S. NGL was $32.01 per barrel in the 2021 quarter compared to $13.91 per barrel in 2020. The average sales price for NGL in Canada was $45.12 per barrel in the 2021 quarter compared to $19.97 per barrel in 2020. NGL prices are higher in Canada due to the higher value of the product at the Kaybob Duvernay and Placid Montney assets.

Natural gas production volumes from continuing operations averaged 387.5 million cubic feet per day (MMCFD) in the third quarter 2021 compared to 341.5 MMCFD in 2020.  The increase of 46 MMCFD was a result of higher volumes in Canada (49 MMCFD), offset by lower volumes in the Gulf of Mexico (7 MMCFD) and in the Eagle Ford Shale (4 MMCFD). Higher natural gas volumes in Canada are primarily due to bringing online 10 new wells at Tupper Montney in the second quarter of 2021. Lower volumes in the Gulf of Mexico are principally due to facility shut-ins as a result of Hurricane Ida.

Natural gas prices for the total Company averaged $2.78 per thousand cubic feet (MCF) in the 2021 quarter, versus $1.78 per MCF average in the same quarter of 2020.  Average natural gas prices in the U.S. and Canada in the quarter were $3.99 and $2.47 per MCF, respectively.

Nine months 2021 vs. 2020

Total hydrocarbon production from all E&P continuing operations averaged 170,209 barrels of oil equivalent per day in the first nine months of 2021, which represented a 6% decrease from the 180,443 barrels per day produced in the first nine months of 2020. The decrease in production is principally due to lower capital expenditures throughout 2020 to support generating positive free cashflow.

Average crude oil and condensate production from continuing operations was 98,314 barrels per day in the first nine months of 2021 compared to 108,678 barrels per day in the first nine months of 2020. The decrease of 10,364 barrels per day was principally due to lower Gulf of Mexico production (5,472 barrels per day) due to temporary operational issues at the Cascade & Chinook and Kodiak fields in the first quarter of 2021 and facility shut-ins as a result of Hurricane Ida in the third quarter of 2021. Lower Canada production (3,628 barrels per day) is due to normal field decline at Kaybob coupled with temporary operational issues at Hibernia and lower Eagle Ford Shale production (1,393 barrels per day) is due to normal well decline, lower capital expenditures throughout 2020 and the effects of a winter storm impacting Eagle Ford Shale production in the first quarter of 2021. On a worldwide basis, the Company’s crude oil and condensate prices averaged $64.19 per barrel in the first nine months of 2021 compared to $36.88 per barrel in the 2020 period, an increase of 74% year over year.

Total production of natural gas liquids (NGL) from continuing operations was 10,498 barrels per day in the first nine months of 2021 compared to 11,901 barrels per day in the 2020 period.  The average sales price for U.S. NGL was $25.63 per barrel in 2021 compared to $10.13 per barrel in 2020. The average sales price for NGL in Canada was $37.05 per barrel in 2021 compared to $16.95 per barrel in 2020. NGL prices are higher in Canada due to the higher value of the product at the Kaybob Duvernay and Placid Montney assets.

Natural gas sales volumes from continuing operations averaged 368.4 million cubic feet per day (MMCFD) in the first nine months of 2021 compared to 359.2 MMCFD in 2020.  The increase of 9.2 MMCFD was primarily the result of higher volumes at Tupper (18.8 MMCFD) driven by the 10 new wells at Tupper Montney in the second quarter of 2021, partially offset by lower volumes in the Gulf of Mexico (4.3 MMCFD), other Canada assets (4.0 MMCFD), and in the Eagle Ford (1.3 MMCFD). Lower volumes in the Gulf of Mexico are principally due to temporary operational issues at the Cascade & Chinook and Kodiak fields. Lower volumes at Eagle Ford Shale are due to normal well decline, lower capital expenditures throughout 2020 and the effects of a winter storm impacting Eagle Ford Shale production in the first quarter of 2021. Natural gas prices for the total Company averaged $2.56 per thousand cubic feet (MCF) in the first nine months of 2021, versus $1.68 per MCF average in the same period of 2020.  Average natural gas prices in the U.S. and Canada in the quarter were $3.26 and $2.33, respectively.

Additional details about results of oil and natural gas operations are presented in the tables on pages 25 and 26.

29

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Results of Operations (contd.)

The following table contains hydrocarbons produced during the three-month and nine-month periods ended September 30, 2021 and 2020.

		Three Months Ended September 30,		Nine Months Ended September 30,
Barrels per day unless otherwise noted		2021	2020	2021	2020
Continuing operations
Net crude oil and condensate
United States	Onshore	26,193	24,851	26,552	27,945
	Gulf of Mexico 1	53,011	56,517	61,905	67,377
Canada	Onshore	4,963	9,595	5,598	8,106
	Offshore	3,779	4,428	4,016	5,136
Other		299	—	243	114
Total net crude oil and condensate - continuing operations		88,245	95,391	98,314	108,678
Net natural gas liquids
United States	Onshore	5,847	5,489	5,043	5,459
	Gulf of Mexico 1	3,459	3,521	4,296	5,131
Canada	Onshore	1,085	1,513	1,159	1,311
Total net natural gas liquids - continuing operations		10,391	10,523	10,498	11,901
Net natural gas – thousands of cubic feet per day
United States	Onshore	31,478	27,520	27,750	29,054
	Gulf of Mexico 1	46,339	53,046	63,557	67,850
Canada	Onshore	309,709	260,895	277,077	262,279
Total net natural gas - continuing operations		387,526	341,461	368,384	359,183
Total net hydrocarbons - continuing operations including NCI 2,3		163,224	162,824	170,209	180,443
Noncontrolling interest
Net crude oil and condensate – barrels per day		(7,546)	(9,298)	(8,834)	(10,674)
Net natural gas liquids – barrels per day		(243)	(327)	(322)	(443)
Net natural gas – thousands of cubic feet per day 2		(2,331)	(3,269)	(3,498)	(4,137)
Total noncontrolling interest		(8,178)	(10,170)	(9,739)	(11,807)
Total net hydrocarbons - continuing operations excluding NCI 2,3		155,046	152,654	160,470	168,636

1 Includes net volumes attributable to a noncontrolling interest in MP Gulf of Mexico, LLC (MP GOM).

2 Natural gas converted on an energy equivalent basis of 6:1

3 NCI – noncontrolling interest in MP GOM.

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ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

Results of Operations (contd.)

The following table contains the weighted average sales prices excluding transportation cost deduction for the three-month and nine-month periods ended September 30, 2021 and 2020. Comparative periods are conformed to current presentation.

		Three Months Ended September 30,		Nine Months Ended September 30,
		2021	2020	2021	2020
Weighted average Exploration and Production sales prices
Continuing operations
Crude oil and condensate – dollars per barrel
United States	Onshore	69.30	37.83	64.16	35.56
	Gulf of Mexico 1	68.93	40.82	64.44	38.08
Canada 2	Onshore	63.76	36.65	58.70	30.29
	Offshore	72.64	43.81	68.93	37.85
Other		—	—	—	63.51
Natural gas liquids – dollars per barrel
United States	Onshore	30.37	13.39	24.29	10.78
	Gulf of Mexico 1	34.71	14.71	27.17	9.43
Canada 2	Onshore	45.12	19.97	37.05	16.95
Natural gas – dollars per thousand cubic feet
United States	Onshore	3.85	1.78	3.23	1.76
	Gulf of Mexico 1	4.09	2.01	3.28	1.91
Canada 2	Onshore	2.47	1.74	2.33	1.62

1 Prices include the effect of noncontrolling interest share for MP GOM.

2 U.S. dollar equivalent.

Financial Condition

Cash Provided by Operating Activities

Net cash provided by continuing operating activities was $1,091.3 million for the first nine months of 2021 compared to $578.0 million during the same period in 2020.  The increased cash from operating activities is primarily attributable to higher revenue from sales to customers ($727.3 million), lower working capital ($143.6 million), lower lease operating expense ($74.6 million), and lower general and administrative and cash restructuring expense ($47.4 million), partially offset by higher cash payments made on forward swap commodity contracts (2021: realized loss of $271.3 million; 2020: realized gain of $215.0 million).

Cash Required by Investing Activities

Net cash required by investing activities was $311.9 million for the first nine months of 2021 compared to $723.7 million during the same period in 2020. Property additions and dry hole costs, which includes amounts expensed, were $582.0 million and $723.7 million in the first nine months of 2021 and 2020, respectively. These amounts include $17.7 million and $74.9 million used to fund the development of the King’s Quay FPS in the first nine months of 2021 and 2020, respectively. In the first quarter of 2021, the King’s Quay FPS was sold to ArcLight Capital Partners, LLC (ArcLight) for proceeds of $267.7 million, which reimbursed the Company for previously incurred capital expenditures. Lower property additions in 2021 are principally due to lower capital spending at Eagle Ford Shale and lower spend on King’s Quay.

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ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (contd.)

Financial Condition (contd.)

Total accrual basis capital expenditures were as follows:

	Nine Months Ended September 30,
(Millions of dollars)	2021		2020
Capital Expenditures
Exploration and production	$	556.0	671.0
Corporate	12.7		9.3
Total capital expenditures	$	568.7	680.3

A reconciliation of property additions and dry hole costs in the Consolidated Statements of Cash Flows to total capital expenditures for continuing operations follows.

	Nine Months Ended September 30,
(Millions of dollars)	2021		2020
Property additions and dry hole costs per cash flow statements	$	564.2	648.7
Property additions King's Quay per cash flow statements	17.7		74.9
Geophysical and other exploration expenses	13.3		26.8
Capital expenditure accrual changes and other	(26.6)		(70.2)
Total capital expenditures	$	568.7	680.3

Capital expenditures in the exploration and production business in 2021 compared to 2020 have decreased as a result of capital expenditure reductions to support generating positive free cash flow.

Cash Used in/ Provided by Financing Activities

Net cash required by financing activities was $585.6 million for the first nine months of 2021 compared to net cash provided by financing activities of $59.1 million during the same period in 2020. In 2021, the cash used in financing activities was principally for the early redemption of the notes due 2022 and 2024 ($726.4 million), early redemption cost (make whole payment) of the notes due 2022 ($36.8 million), repayment of the previously outstanding balance on the Company’s unsecured RCF ($200.0 million), distributions to the non-controlling interest (NCI) in the Gulf of Mexico ($100.9 million), and cash dividends to shareholders ($57.9 million), partially offset by the issuance of new notes due 2028, net of debt issuance cost ($541.9 million).

As of September 30, 2021 and in the event it is required to fund investing activities from borrowings, the Company has $1,568.6 million available on its committed RCF.

In 2020, the cash provided by financing activities was principally from borrowings on the Company’s unsecured revolving credit facility ($450.0 million), offset by repayments on the revolving credit facility ($250.0 million), cash dividends to shareholders ($76.8 million), and distributions to our noncontrolling interest ($43.7 million).

Working Capital

Working capital (total current assets less total current liabilities – excluding assets and liabilities held for sale) at September 30, 2021 was a deficit of $344.9 million, $315.5 million lower than December 31, 2020, with the decrease primarily attributable to higher accounts payable ($208.3 million), higher other accrued liabilities ($165.6 million), higher operating lease liabilities ($53.5 million), partly offset by a higher cash balance ($194.5 million) and lower accounts receivable ($75.3 million). Higher accounts payable is primarily due to the increase in unrealized losses on derivative instruments (swaps and collars) maturing in the next 12 months. Higher other accrued liabilities are associated with contingent consideration obligations (from 2018 and 2019 Gulf of Mexico acquisitions). Higher operating lease liabilities are associated with a rig contract to support the Khaleesi-Mormont and Samurai developments which will utilize the King’s Quay FPS. Lower accounts receivable are principally due to the timing of cash received from our joint venture partners to fund joint operations.

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ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (contd.)

Financial Condition (contd.)

Capital Employed

At September 30, 2021, long-term debt of $2,613.7 million had decreased by $374.4 million compared to December 31, 2020, primarily as a result of repayment of the borrowings on the RCF ($200.0 million) and the redemption of the notes due 2022 and 2024 ($726.4 million) in excess of the issuance of notes due 2028 ($550.0 million) in the first quarter of 2021.  The total of the fixed-rate notes in issue had a weighted average maturity of 7.5 years and a weighted average coupon of 6.3% percent.

A summary of capital employed at September 30, 2021 and December 31, 2020 follows.

	September 30, 2021				December 31, 2020
(Millions of dollars)	Amount		%		Amount		%
Capital employed
Long-term debt	$	2,613.7	39.8	%	$	2,988.1	41.5	%
Murphy shareholders' equity	3,949.5		60.2	%	4,214.3		58.5	%
Total capital employed	$	6,563.2	100.0	%	$	7,202.4	100.0	%

Cash and invested cash are maintained in several operating locations outside the United States.  At September 30, 2021, Cash and cash equivalents held outside the U.S. included U.S. dollar equivalents of approximately $119.4 million in Canada and $6.2 million in Brunei.  In certain cases, the Company could incur cash taxes or other costs should these cash balances be repatriated to the U.S. in future periods.  Canada currently collects a 5% withholding tax on any earnings repatriated to the U.S.

Accounting changes and recent accounting pronouncements – see Note B to the Consolidated Financial Statements

Outlook

As discussed in the Summary section on page 23, average crude oil prices continued to recover during the second half of 2021 versus 2020 (Q3 2021 WTI: $70.56; Q3 2020 WTI: $40.93). As of close on November 2, 2021, the NYMEX WTI forward curve price for the remainder of 2021 and 2022 were $83.91 and $76.27 per barrel, respectively; however we cannot predict what impact economic factors (including the ongoing COVID-19 pandemic and OPEC+ decisions) may have on future commodity pricing. Lower prices, should they occur, will result in lower profits and operating cash-flows. For the fourth quarter, production is expected to average between 145.5 and 153.5 MBOEPD, excluding noncontrolling interest (NCI).

The Company’s capital expenditure spend for 2021 is expected to be between $675.0 million and $685.0 million. Capital and other expenditures are routinely reviewed and planned capital expenditures may be adjusted to reflect differences between budgeted and forecast cash flow during the year.  Capital expenditures may also be affected by asset purchases or sales, which often are not anticipated at the time a budget is prepared.  The Company will primarily fund its remaining capital program in 2021 using operating cash flow and available cash. If oil and/or natural gas prices weaken, actual cash flow generated from operations could be reduced such that capital spending reductions are required and/or borrowings under available credit facilities might be required during the year to maintain funding of the Company’s ongoing development projects.  

The Company plans to utilize surplus cash (not planned to be used by operations, investing activities, dividends or payment to noncontrolling interests) to repay outstanding debt.

The Company continues to monitor the impact of commodity prices on its financial position and is currently in compliance with the covenants related to the revolving credit facility (see Note F). The Company continues to monitor the effects of the COVID-19 pandemic and is encouraged by the progress of the vaccination roll-outs globally.

As of November 2, 2021, the Company has entered into derivative or forward fixed-price delivery contracts to manage risk associated with certain future oil and natural gas sales prices as follows:

	Commodity	Type	Volumes (Bbl/d)	Price (USD/Bbl)	Remaining Period
Area					Start Date	End Date
United States	WTI ¹	Fixed price derivative swap	45,000	$42.77	10/1/2021	12/31/2021
United States	WTI ¹	Fixed price derivative swap	20,000	$44.88	1/1/2022	12/31/2022

			Volumes (Bbl/d)	Average Put (USD/Bbl)	Average Call (USD/Bbl)	Remaining Period
Area	Commodity	Type				Start Date	End Date
United States	WTI ¹	Derivative collars	23,000	$62.652	$74.774	1/1/2022	12/31/2022

1 West Texas Intermediate

33

ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)

			Volumes (MMcf/d)	Price/Mcf	Remaining Period
Area	Commodity	Type			Start Date	End Date
Montney	Natural Gas	Fixed price forward sales	196	C$2.55	10/1/2021	12/31/2021
Montney	Natural Gas	Fixed price forward sales	186	C$2.36	1/1/2022	1/31/2022
Montney	Natural Gas	Fixed price forward sales	176	C$2.34	2/1/2022	4/30/2022
Montney	Natural Gas	Fixed price forward sales	205	C$2.34	5/1/2022	5/31/2022
Montney	Natural Gas	Fixed price forward sales	247	C$2.34	6/1/2022	10/31/2022
Montney	Natural Gas	Fixed price forward sales	266	C$2.36	11/1/2022	12/31/2022
Montney	Natural Gas	Fixed price forward sales	269	C$2.35	1/1/2023	3/31/2023
Montney	Natural Gas	Fixed price forward sales	250	C$2.35	4/1/2023	12/31/2023
Montney	Natural Gas	Fixed price forward sales	162	C$2.39	1/1/2024	12/31/2024
Montney	Natural Gas	Fixed price forward sales	45	US$2.05	10/1/2021	12/31/2022
Montney	Natural Gas	Fixed price forward sales	25	US$1.98	1/1/2023	10/31/2024
Montney	Natural Gas	Fixed price forward sales	15	US$1.98	11/1/2024	12/31/2024

Forward-Looking Statements

This Form 10-Q contains forward-looking statements as defined in the Private Securities Litigation Reform Act of 1995.  Forward-looking statements are generally identified through the inclusion of words such as “aim”, “anticipate”, “believe”, “drive”, “estimate”, “expect”, “expressed confidence”, “forecast”, “future”, “goal”, “guidance”, “intend”, “may”, “objective”, “outlook”, “plan”, “position”, “potential”, “project”, “seek”, “should”, “strategy”, “target”, “will” or variations of such words and other similar expressions. These statements, which express management’s current views concerning future events or results, are subject to inherent risks and uncertainties. Factors that could cause one or more of these future events or results not to occur as implied by any forward-looking statement include, but are not limited to: macro conditions in the oil and gas industry, including supply/demand levels, actions taken by major oil exporters and the resulting impacts on commodity prices; increased volatility or deterioration in the success rate of our exploration programs or in our ability to maintain production rates and replace reserves; reduced customer demand for our products due to environmental, regulatory, technological or other reasons; adverse foreign exchange movements; political and regulatory instability in the markets where we do business; the impact on our operations or market of health pandemics such as COVID-19 and related government responses; other natural hazards impacting our operations or markets; any other deterioration in our business, markets or prospects; any failure to obtain necessary regulatory approvals; any inability to service or refinance our outstanding debt or to access debt markets at acceptable prices; or adverse developments in the U.S. or global capital markets, credit markets or economies in general. For further discussion of factors that could cause one or more of these future events or results not to occur as implied by any forward-looking statement, see “Risk Factors” in Murphy’s 2020 Annual Report on Form 10-K on file with the U.S. Securities and Exchange Commission and on page 37 of this Form 10-Q report.  Murphy undertakes no duty to publicly update or revise any forward-looking statements.

34

ITEM 3. QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK

The Company is exposed to market risks associated with interest rates, prices of crude oil, natural gas and petroleum products, and foreign currency exchange rates.  As described in Note L to this Form 10-Q report, Murphy makes use of derivative financial and commodity instruments to manage risks associated with existing or anticipated transactions.

There were commodity transactions in place at September 30, 2021, covering certain future U.S. crude oil sales volumes in 2021 and 2022.  A 10% increase in the respective benchmark price of these commodities would have increased the net payable associated with these derivative contracts by approximately $113.6 million, while a 10% decrease would have decreased the recorded net payable by a similar amount.

There were no derivative foreign exchange contracts in place at September 30, 2021.

ITEM 4.  CONTROLS AND PROCEDURES

Under the direction of its principal executive officer and principal financial officer, controls and procedures have been established by the Company to ensure that material information relating to the Company and its consolidated subsidiaries is made known to the officers who certify the Company’s financial reports and to other members of senior management and the Board of Directors.

Based on the Company’s evaluation as of the end of the period covered by the filing of this Quarterly Report on Form 10-Q, the principal executive officer and principal financial officer of Murphy Oil Corporation have concluded that the Company’s disclosure controls and procedures (as defined in Rules 13a-15(e) and 15d-15(e) under the Securities Exchange Act of 1934) are effective to ensure that the information required to be disclosed by Murphy Oil Corporation in reports that it files or submits under the Securities Exchange Act of 1934 is recorded, processed, summarized and reported within the time periods specified in SEC rules and forms.

During the quarter ended September 30, 2021, there were no changes in the Company’s internal control over financial reporting that have materially affected, or are reasonably likely to materially affect, the Company’s internal control over financial reporting.

35

PART II – OTHER INFORMATION

ITEM 1. LEGAL PROCEEDINGS

Murphy and its subsidiaries are engaged in a number of legal proceedings, all of which Murphy considers routine and incidental to its business.  Based on information currently available to the Company, the ultimate resolution of matters referred to in this item is not expected to have a material adverse effect on the Company’s net income or loss, financial condition or liquidity in a future period.

ITEM 1A. RISK FACTORS

The Company’s operations in the oil and natural gas business naturally lead to various risks and uncertainties.  These risk factors are discussed in Item 1A Risk Factors in its 2020 Form 10-K filed on February 26, 2021.  The Company has not identified any additional risk factors not previously disclosed in its 2020 Form 10-K report.

ITEM 6. EXHIBITS

The Exhibit Index on page 39 of this Form 10-Q report lists the exhibits that are hereby filed or incorporated by reference.

36

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.

MURPHY OIL CORPORATION
(Registrant)
By	/s/ CHRISTOPHER D. HULSE
	Christopher D. Hulse
	Vice President and Controller
	(Chief Accounting Officer and Duly Authorized Officer)

November 4, 2021

(Date)

37

EXHIBIT INDEX

The following is an index of exhibits that are hereby filed as indicated by asterisk (*), that are considered furnished rather than filed, or that are incorporated by reference. Exhibits other than those listed have been omitted since they are either not required or not applicable.

Exhibit No.
*31.1	Certification required by Rule 13a-14(a) pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
*31.2	Certification required by Rule 13a-14(a) pursuant to Section 302 of the Sarbanes-Oxley Act of 2002
*32	Certifications pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
101. INS	XBRL Instance Document
101. SCH	XBRL Taxonomy Extension Schema Document
101. CAL	XBRL Taxonomy Extension Calculation Linkbase Document
101. DEF	XBRL Taxonomy Extension Definition Linkbase Document
101. LAB	XBRL Taxonomy Extension Labels Linkbase Document
101. PRE	XBRL Taxonomy Extension Presentation Linkbase

38

EX-31.1

EXHIBIT 31.1

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, Roger W. Jenkins, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Murphy Oil Corporation;

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 controls 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 controls over financial reporting.

Date: November 4, 2021

/s/ Roger W. Jenkins

Roger W. Jenkins

Principal Executive Officer

Ex. 31.1

EX-31.2

EXHIBIT 31.2

CERTIFICATION PURSUANT TO

SECTION 302 OF THE SARBANES-OXLEY ACT OF 2002

I, David R. Looney, certify that:

1.I have reviewed this quarterly report on Form 10-Q of Murphy Oil Corporation;

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 controls 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 controls over financial reporting.

Date: November 4, 2021

/s/ David R. Looney

David R. Looney

Principal Financial Officer

Ex. 31.2

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

In connection with the quarterly report of Murphy Oil Corporation (the “Company”) on Form 10-Q for the period ended September 30, 2021 as filed with the Securities and Exchange Commission on the date hereof (the “Report”), we, Roger W. Jenkins and David R. Looney,  Principal Executive Officer and Principal Financial Officer, respectively, of the Company, certify, pursuant to 18 U.S.C. § 1350, as adopted pursuant to § 906 of the Sarbanes-Oxley Act of 2002, that to our knowledge:

(1)The Report fully complies with the requirements of section 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.

Date: November 4, 2021

/s/ Roger W. Jenkins

Roger W. Jenkins

Principal Executive Officer

/s/ David R. Looney

David R. Looney

Principal Financial Officer

Ex. 32.1

XML

Cover Page - shares	9 Months Ended
	Sep. 30, 2021	Oct. 31, 2021
Cover [Abstract]
Document Type	10-Q
Document Quarterly Report	true
Document Period End Date	Sep. 30, 2021
Document Transition Report	false
Entity File Number	1-8590
Entity Registrant Name	MURPHY OIL CORPORATION
Entity Incorporation, State or Country Code	DE
Entity Tax Identification Number	71-0361522
Entity Address, Address Line One	9805 Katy Fwy, Suite G-200
Entity Address, City or Town	Houston,
Entity Address, State or Province	TX
Entity Address, Postal Zip Code	77024
City Area Code	(281)
Local Phone Number	675-9000
Title of 12(b) Security	Common Stock, $1.00 Par Value
Trading Symbol	MUR
Security Exchange Name	NYSE
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		154,459,128
Amendment Flag	false
Document Fiscal Year Focus	2021
Document Fiscal Period Focus	Q3
Entity Central Index Key	0000717423
Current Fiscal Year End Date	--12-31

XML

CONSOLIDATED BALANCE SHEETS (unaudited) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Current assets
Cash and cash equivalents	$ 505,067	$ 310,606
Accounts receivable, less allowance for doubtful accounts	186,683	262,014
Inventories	57,411	66,076
Prepaid expenses	40,583	33,860
Assets held for sale	40,987	327,736
Total current assets	830,731	1,000,292
Property, plant and equipment, at cost less accumulated depreciation, depletion and amortization of $12,268,101 in 2021 and $11,455,305 in 2020	8,112,093	8,269,038
Operating lease assets	918,719	927,658
Deferred income taxes	442,212	395,253
Deferred charges and other assets	27,101	28,611
Total assets	10,330,856	10,620,852
Current liabilities
Current maturities of long-term debt, finance lease	646	0
Accounts payable	615,436	407,097
Income taxes payable	18,035	18,018
Other taxes payable	26,997	22,498
Operating lease liabilities	157,294	103,758
Other accrued liabilities	316,205	150,578
Liabilities associated with assets held for sale	0	14,372
Total current liabilities	1,134,613	716,321
Long-term debt, including finance lease obligation	2,613,703	2,988,067
Asset retirement obligations	797,627	816,308
Deferred credits and other liabilities	723,732	680,580
Non-current operating lease liabilities	781,114	845,088
Deferred income taxes	166,120	180,341
Total liabilities	6,216,909	6,226,705
Equity
Cumulative Preferred Stock, par $100, authorized 400,000 shares, none issued	0	0
Common Stock, par $1.00, authorized 450,000,000 shares, issued 195,100,628 shares in 2021 and 195,100,628 shares in 2020	195,101	195,101
Capital in excess of par value	921,227	941,692
Retained earnings	5,069,578	5,369,538
Accumulated other comprehensive loss	(580,174)	(601,333)
Treasury stock	(1,656,224)	(1,690,661)
Murphy Shareholders' Equity	3,949,508	4,214,337
Noncontrolling interest	164,439	179,810
Total equity	4,113,947	4,394,147
Total liabilities and equity	$ 10,330,856	$ 10,620,852

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CONSOLIDATED BALANCE SHEETS (unaudited) (Parenthetical) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Statement of Financial Position [Abstract]
Allowance for doubtful accounts	$ 1,605	$ 1,605
Accumulated depreciation, depletion and amortization	$ 12,268,101	$ 11,455,305
Cumulative preferred stock, par value (in USD per share)	$ 100	$ 100
Cumulative preferred stock, authorized shares (in shares)	400,000	400,000
Cumulative preferred stock, shares issued (in shares)	0	0
Common stock, par value (in USD per share)	$ 1.00	$ 1.00
Common stock, authorized shares (in shares)	450,000,000	450,000,000
Common stock, shares issued (in shares)	195,100,628	195,100,628

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CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Revenues and other income
Revenue from sales to customers	$ 687,549	$ 425,324	$ 2,038,905	$ 1,311,627
(Loss) gain on derivative instruments	(59,164)	(5,290)	(499,794)	319,502
Gain on sale of assets and other income	2,315	1,831	21,217	6,006
Total revenues and other income	630,700	421,865	1,560,328	1,637,135
Costs and expenses
Lease operating expenses	130,131	124,491	403,708	478,283
Severance and ad valorem taxes	11,670	6,781	32,215	22,645
Transportation, gathering and processing	44,588	41,322	137,196	126,779
Exploration expenses, including undeveloped lease amortization	24,517	12,092	49,840	61,686
Selling and general expenses	27,210	28,509	85,826	104,381
Restructuring expenses	0	4,982	0	46,379
Depreciation, depletion and amortization	189,806	231,603	615,372	769,151
Accretion of asset retirement obligations	12,198	10,778	34,854	31,213
Impairment of assets	0	219,138	171,296	1,206,284
Other (benefit) expense	(32,791)	20,224	58,616	(2,957)
Total costs and expenses	407,329	699,920	1,588,923	2,843,844
Operating income (loss) from continuing operations	223,371	(278,055)	(28,595)	(1,206,709)
Other income (loss)
Interest income and other (loss)	(1,593)	(5,177)	(11,459)	(10,107)
Interest expense, net	(46,925)	(45,182)	(178,399)	(124,877)
Total other loss	(48,518)	(50,359)	(189,858)	(134,984)
Income (loss) from continuing operations before income taxes	174,853	(328,414)	(218,453)	(1,341,693)
Income tax expense (benefit)	36,838	(62,584)	(62,498)	(248,890)
Income (loss) from continuing operations	138,015	(265,830)	(155,955)	(1,092,803)
(Loss) from discontinued operations, net of income taxes	(706)	(778)	(600)	(6,907)
Net income (loss) including noncontrolling interest	137,309	(266,608)	(156,555)	(1,099,710)
Less: Net income (loss) attributable to noncontrolling interest	28,853	(23,055)	85,509	(122,869)
NET INCOME (LOSS) ATTRIBUTABLE TO MURPHY	$ 108,456	$ (243,553)	$ (242,064)	$ (976,841)
INCOME (LOSS) PER COMMON SHARE – BASIC
Continuing operations (in USD per share)	$ 0.70	$ (1.58)	$ (1.57)	$ (6.31)
Discontinued operations (in USD per share)	0	(0.01)	0	(0.05)
Net income (loss) (in USD per share)	0.70	(1.59)	(1.57)	(6.36)
INCOME (LOSS) PER COMMON SHARE – DILUTED
Continuing operations (in USD per share)	0.70	(1.58)	(1.57)	(6.31)
Discontinued operations (in USD per share)	0	(0.01)	0	(0.05)
Net income (loss) (in USD per share)	0.70	(1.59)	(1.57)	(6.36)
Cash dividends per Common share (in USD per share)	$ 0.125	$ 0.125	$ 0.375	$ 0.500
Average Common shares outstanding (thousands)
Basic (in shares)	154,439,313	153,596,109	154,239,440	153,479,654
Diluted (in shares)	155,932,262	153,596,109	154,239,440	153,479,654

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CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Statement of Comprehensive Income [Abstract]
Net income (loss) including noncontrolling interest	$ 137,309	$ (266,608)	$ (156,555)	$ (1,099,710)
Other comprehensive (loss) income, net of tax
Net (loss) gain from foreign currency translation	(31,308)	28,323	6,534	(39,520)
Retirement and postretirement benefit plans	4,653	3,726	12,935	(45,219)
Deferred loss on interest rate hedges reclassified to interest expense	0	297	1,690	905
Other comprehensive (loss) income	(26,655)	32,346	21,159	(83,834)
COMPREHENSIVE INCOME (LOSS)	$ 110,654	$ (234,262)	$ (135,396)	$ (1,183,544)

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CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited) - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2021	Sep. 30, 2020
Operating Activities
Net income (loss) including noncontrolling interest		$ (156,555)	$ (1,099,710)
Adjustments to reconcile net income (loss) to net cash provided by continuing operations activities
Loss from discontinued operations		600	6,907
Depreciation, depletion and amortization		615,372	769,151
Dry hole and previously suspended exploration costs		17,899	8,255
Amortization of undeveloped leases		13,872	21,951
Accretion of asset retirement obligations		34,854	31,213
Impairment of assets		171,296	1,206,284
Noncash restructuring expense		0	17,565
Deferred income tax (benefit) expense		(65,149)	(231,748)
Mark to market loss (gain) on contingent consideration		105,111	(29,476)
Mark to market loss (gain) on derivative instruments		228,497	(104,463)
Long-term non-cash compensation		42,080	35,200
Net decrease (increase) in noncash working capital		117,330	(26,261)
Other operating activities, net		(33,924)	(26,837)
Net cash provided by continuing operations activities		1,091,283	578,031
Investing Activities
Property additions and dry hole costs		(564,230)	(648,725)
Property additions for King's Quay FPS		(17,734)	(74,936)
Proceeds from sales of property, plant and equipment		270,038	0
Net cash required by investing activities		(311,926)	(723,661)
Financing Activities
Borrowings on revolving credit facility		165,000	450,000
Repayment of revolving credit facility		(365,000)	(250,000)
Retirement of debt		(726,358)	(12,225)
Debt issuance, net of cost		541,913	(613)
Early redemption of debt cost		(36,756)	0
Distributions to noncontrolling interest		(100,880)	(43,673)
Cash dividends paid		(57,896)	(76,790)
Withholding tax on stock-based incentive awards		(4,973)	(7,094)
Capital lease obligation payments		(643)	(514)
Net cash (required) provided by financing activities		(585,593)	59,091
Cash Flows from Discontinued Operations
Operating activities	[1]	0	(1,202)
Investing activities	[1]	0	4,494
Financing activities	[1]	0	0
Net cash provided by discontinued operations	[1]	0	3,292
Effect of exchange rate changes on cash and cash equivalents		697	(585)
Net increase (decrease) in cash and cash equivalents		194,461	(87,124)
Cash and cash equivalents at beginning of period		310,606	306,760
Cash and cash equivalents at end of period		$ 505,067	$ 219,636

[1] Net cash provided by discontinued operations is not part of the cash flow reconciliation. See Notes to Consolidated Financial Statements, page 7.

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CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (unaudited) - USD ($) $ in Thousands	Total	Murphy Shareholders’ Equity	Cumulative Preferred Stock	Common Stock	Capital in Excess of Par Value	Retained Earnings	Accumulated Other Comprehensive Loss	Treasury Stock	Noncontrolling Interest
Balance at beginning of period at Dec. 31, 2019				$ 195,089	$ 949,445	$ 6,614,304	$ (574,161)	$ (1,717,217)	$ 337,151
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exercise of stock options, including income tax benefits				12	(156)
Restricted stock transactions and other					(33,649)
Share-based compensation					20,678
Net income (loss)	$ (976,841)					(976,841)			(122,869)
Cash dividends						(76,790)
Foreign currency translation gain (loss), net of income taxes	(39,520)						(39,520)
Retirement and postretirement benefit plans, net of income taxes							(45,219)
Deferred loss on interest rate hedges reclassified to interest expense, net of income taxes	905						905
Awarded restricted stock, net of forfeitures								26,556
Distributions to noncontrolling interest owners									(43,673)
Balance at end of period at Sep. 30, 2020	4,514,045	$ 4,343,436	$ 0	195,101	936,318	5,560,673	(657,995)	(1,690,661)	170,609
Balance at beginning of period at Jun. 30, 2020				195,101	931,429	5,823,426	(690,341)	(1,691,070)	204,937
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Restricted stock transactions and other					(409)
Share-based compensation					5,298
Net income (loss)	(243,553)					(243,553)			(23,055)
Cash dividends						(19,200)
Foreign currency translation gain (loss), net of income taxes	28,323						28,323
Retirement and postretirement benefit plans, net of income taxes							3,726
Deferred loss on interest rate hedges reclassified to interest expense, net of income taxes	297						297
Awarded restricted stock, net of forfeitures								409
Distributions to noncontrolling interest owners									(11,273)
Balance at end of period at Sep. 30, 2020	4,514,045	4,343,436	0	195,101	936,318	5,560,673	(657,995)	(1,690,661)	170,609
Balance at beginning of period at Dec. 31, 2020	4,394,147			195,101	941,692	5,369,538	(601,333)	(1,690,661)	179,810
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exercise of stock options, including income tax benefits					(661)			549
Restricted stock transactions and other					(38,749)
Share-based compensation					18,945
Net income (loss)	(242,064)					(242,064)			85,509
Cash dividends						(57,896)
Foreign currency translation gain (loss), net of income taxes	6,534						6,534
Retirement and postretirement benefit plans, net of income taxes							12,935
Deferred loss on interest rate hedges reclassified to interest expense, net of income taxes	1,690						1,690
Awarded restricted stock, net of forfeitures								33,888
Distributions to noncontrolling interest owners									(100,880)
Balance at end of period at Sep. 30, 2021	4,113,947	3,949,508	0	195,101	921,227	5,069,578	(580,174)	(1,656,224)	164,439
Balance at beginning of period at Jun. 30, 2021				195,101	915,181	4,980,428	(553,519)	(1,656,591)	161,228
Increase (Decrease) in Stockholders' Equity [Roll Forward]
Exercise of stock options, including income tax benefits					(35)			24
Restricted stock transactions and other					(402)
Share-based compensation					6,483
Net income (loss)	108,456					108,456			28,853
Cash dividends						(19,306)
Foreign currency translation gain (loss), net of income taxes	(31,308)						(31,308)
Retirement and postretirement benefit plans, net of income taxes							4,653
Deferred loss on interest rate hedges reclassified to interest expense, net of income taxes	0
Awarded restricted stock, net of forfeitures								343
Distributions to noncontrolling interest owners									(25,642)
Balance at end of period at Sep. 30, 2021	$ 4,113,947	$ 3,949,508	$ 0	$ 195,101	$ 921,227	$ 5,069,578	$ (580,174)	$ (1,656,224)	$ 164,439

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CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (unaudited) (Parenthetical) - $ / shares	Sep. 30, 2021	Sep. 30, 2020
Statement of Stockholders' Equity [Abstract]
Cumulative preferred stock, par value (in USD per share)	$ 100	$ 100
Cumulative preferred stock, authorized shares (in shares)	400,000	400,000
Cumulative preferred stock, shares issued (in shares)	0	0
Common stock, par value (in USD per share)	$ 1.00	$ 1.00
Common stock, authorized shares (in shares)	450,000,000	450,000,000
Common stock, shares issued (in shares)	195,100,628	195,100,628
Treasury stock, shares (in shares)	40,656,661	41,502,003

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Nature of Business and Interim Financial Statements

9 Months Ended

Sep. 30, 2021

Organization, Consolidation and Presentation of Financial Statements [Abstract]

Nature of Business and Interim Financial Statements

Note A – Nature of Business and Interim Financial Statements

NATURE OF BUSINESS – Murphy Oil Corporation is an international oil and natural gas exploration and production company that conducts its business through various operating subsidiaries.  The Company primarily produces oil and natural gas in the United States and Canada and conducts oil and natural gas exploration activities worldwide.

In connection with the LLOG Exploration Offshore L.L.C. and LLOG Bluewater Holdings, L.L.C., (LLOG) acquisition, we hold a 0.5% interest in two variable interest entities (VIEs), Delta House Oil and Gas Lateral LLC and Delta House Floating Production System (FPS) LLC (collectively Delta House). These VIEs have not been consolidated because we are not considered the primary beneficiary. These non-consolidated VIEs are not material to our financial position or results of operations. As of September 30, 2021, our maximum exposure to loss was $3.4 million (excluding operational impacts), which represents our net investment in Delta House. We have not provided any financial support to Delta House other than amounts previously required by our membership interest.

INTERIM FINANCIAL STATEMENTS – In the opinion of Murphy’s management, the unaudited financial statements presented herein include all accruals necessary to present fairly the Company’s financial position at September 30, 2021 and December 31, 2020, and the results of operations, cash flows and changes in stockholders’ equity for the interim periods ended September 30, 2021 and 2020, in conformity with accounting principles generally accepted in the United States of America (U.S.).  In preparing the financial statements of the Company in conformity with accounting principles generally accepted in the U.S., management has made a number of estimates and assumptions related to the reporting of assets, liabilities, revenues, and expenses and the disclosure of contingent assets and liabilities.  Actual results may differ from the estimates.

Consolidated financial statements and notes to consolidated financial statements included in this Form 10-Q report should be read in conjunction with the Company’s 2020 Form 10-K report, as certain notes and other pertinent information have been abbreviated or omitted in this report.  Financial results for the three-month and nine-month periods ended September 30, 2021 are not necessarily indicative of future results.

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New Accounting Principles and Recent Accounting Pronouncements

9 Months Ended

Sep. 30, 2021

Accounting Changes and Error Corrections [Abstract]

New Accounting Principles and Recent Accounting Pronouncements

Note B – New Accounting Principles and Recent Accounting Pronouncements

Accounting Principles Adopted

Income Taxes. In December 2019, the FASB issued ASU 2019-12, which removes certain exceptions for investments, intraperiod allocations and interim calculations, and adds guidance to reduce complexity in accounting for income taxes. The amendments in this ASU are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. Implementation on a prospective or retrospective basis varies by specific topics within the ASU. The Company adopted this guidance in the first quarter of 2021 and it did not have a material impact on its consolidated financial statements.

Recent Accounting Pronouncements

None affecting the Company.

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Revenue from Contracts with Customers

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Revenue from Contracts with Customers

Note C – Revenue from Contracts with Customers

Nature of Goods and Services

The Company explores for and produces crude oil, natural gas and natural gas liquids (collectively oil and natural gas) in select basins around the globe. The Company’s revenue from sales of oil and natural gas production activities are primarily subdivided into two key geographic segments: the U.S. and Canada.  Additionally, revenue from sales to customers is generated from three primary revenue streams: crude oil and condensate, natural gas liquids, and natural gas.

For operated oil and natural gas production where the non-operated working interest owner does not take-in-kind its proportionate interest in the produced commodity, the Company acts as an agent for the working interest owner and recognizes revenue only for its own share of the commingled production. The exception to this is the reporting of the noncontrolling interest in MP GOM as prescribed by ASC 810-10-45.

U.S. - In the United States, the Company primarily produces oil and natural gas from fields in the Eagle Ford Shale area of South Texas and in the Gulf of Mexico.  Revenue is generally recognized when oil and natural gas are transferred to the customer at the delivery point. Revenue recognized is largely index based with price adjustments for floating market differentials.

Canada - In Canada, contracts include long-term floating commodity index priced and natural gas physical forward sales fixed-price contracts. For the Offshore business in Canada, contracts are based on index prices and revenue is recognized at the time of vessel load based on the volumes on the bill of lading and point of custody transfer.

Disaggregation of Revenue

The Company reviews performance based on two key geographical segments and between onshore and offshore sources of revenue within these geographies.

For the three-month and nine-month periods ended September 30, 2021, the Company recognized $687.5 million and $2,038.9 million, respectively, from contracts with customers for the sales of oil, natural gas liquids and natural gas. For the three-month and nine-month periods ended September 30, 2020, the Company recognized $425.3 million and $1,311.6 million, respectively, from contracts with customers for the sales of oil, natural gas liquids and natural gas.

		Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars)		2021		2020	2021	2020
Net crude oil and condensate revenue
United States	Onshore	$	167,010	86,498	464,767	272,284
	Offshore	340,001		216,918	1,079,418	714,143
Canada	Onshore	29,110		32,358	89,708	67,268
	Offshore	20,499		19,173	70,333	54,864
Other		—		—	—	1,806
Total crude oil and condensate revenue		556,620		354,947	1,704,226	1,110,365
Net natural gas liquids revenue
United States	Onshore	16,356		6,766	33,480	16,145
	Offshore	11,046		4,765	31,866	13,255
Canada	Onshore	4,501		2,780	11,728	6,090
Total natural gas liquids revenue		31,903		14,311	77,074	35,490
Net natural gas revenue
United States	Onshore	11,127		4,529	24,442	14,177
	Offshore	17,444		9,827	56,855	35,487
Canada	Onshore	70,455		41,710	176,308	116,108
Total natural gas revenue		99,026		56,066	257,605	165,772
Total revenue from contracts with customers		687,549		425,324	2,038,905	1,311,627
(Loss) gain on derivative instruments		(59,164)		(5,290)	(499,794)	319,502
Gain on sale of assets and other income		2,315		1,831	21,217	6,006
Total revenue and other income		$	630,700	421,865	1,560,328	1,637,135

Contract Balances and Asset Recognition

As of September 30, 2021, and December 31, 2020, receivables from contracts with customers, net of royalties and associated payables, on the balance sheet from continuing operations, were $144.0 million and $135.2 million, respectively. Payment terms for the Company’s sales vary across contracts and geographical regions, with the majority of the cash receipts required within 30 days of billing. Based on a forward-looking expected loss model in accordance with ASU 2016-13, the Company did not recognize any impairment losses on receivables or contract assets arising from customer contracts during the reporting periods.

The Company has not entered into any revenue contracts that have financing components as at September 30, 2021.

The Company does not employ sales incentive strategies such as commissions or bonuses for obtaining sales contracts. For the periods presented, the Company did not identify any assets to be recognized associated with the costs to obtain a contract with a customer.

Performance Obligations

The Company recognizes oil and natural gas revenue when it satisfies a performance obligation by transferring control over a commodity to a customer.  Judgment is required to determine whether some customers simultaneously receive and consume the benefit of commodities. As a result of this assessment for the Company, each unit of measure of the specified commodity is considered to represent a distinct performance obligation that is satisfied at a point in time upon the transfer of control of the commodity.

For contracts with market or index-based pricing, which represent the majority of sales contracts, the Company has elected the allocation exception and allocates the variable consideration to each single performance obligation in the contract. As a result, there is no price allocation to unsatisfied remaining performance obligations for delivery of commodity product in subsequent periods.

The Company has entered into several long-term, fixed-price contracts in Canada. The underlying reason for entering a fixed price contract is generally unrelated to anticipated future prices or other observable data and serves a particular purpose in the company’s long-term strategy.

As of September 30, 2021, the Company had the following sales contracts in place which are expected to generate revenue from sales to customers for a period of more than 12 months starting at the inception of the contract:

Current Long-Term Contracts Outstanding at September 30, 2021
Location	Commodity	End Date		Description	Approximate Volumes
U.S.	Oil	Q4 2021		Fixed quantity delivery in Eagle Ford	17,000 BOED
U.S.	Natural Gas and NGL	Q1 2023		Deliveries from dedicated acreage in Eagle Ford	As produced
Canada	Natural Gas	Q4 2021		Contracts to sell natural gas at USD index pricing	10 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at USD index pricing	8 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at CAD fixed prices	5 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at USD fixed pricing	20 MMCFD
Canada	Natural Gas	Q4 2023	1	Contracts to sell natural gas at USD index pricing	25 MMCFD
Canada	Natural Gas	Q4 2023		Contracts to sell natural gas at CAD fixed prices	38 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at USD index pricing	31 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at CAD fixed prices	100 MMCFD
Canada	Natural Gas	Q4 2024	1	Contracts to sell natural gas at CAD fixed prices	34 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at USD fixed pricing	15 MMCFD
Canada	Natural Gas	Q4 2026	1	Contracts to sell natural gas at USD index pricing	49 MMCFD

1 These contracts are scheduled to commence after the balance sheet date, at various dates between Q4 2021 and Q1 2022.

Fixed price contracts are accounted for as normal sales and purchases for accounting purposes.

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Property, Plant and Equipment

9 Months Ended

Sep. 30, 2021

Property, Plant and Equipment [Abstract]

Property, Plant and Equipment

Note D – Property, Plant, and Equipment

Exploratory Wells

Under FASB guidance exploratory well costs should continue to be capitalized when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the Company is making sufficient progress assessing the reserves and the economic and operating viability of the project.

As of September 30, 2021, the Company had total capitalized exploratory well costs for continuing operations pending the determination of proved reserves of $186.6 million.  The following table reflects the net changes in capitalized exploratory well costs during the nine-month periods ended September 30, 2021 and 2020.

(Thousands of dollars)	2021		2020
Beginning balance at January 1	$	181,616	217,326
Additions pending the determination of proved reserves	5,007		9,941
Capitalized exploratory well costs charged to expense	—		(39,408)
Balance at September 30	$	186,623	187,859

The capitalized well costs charged to expense during 2020 represent a charge for asset impairments (see below).

The following table provides an aging of capitalized exploratory well costs based on the date the drilling was completed for each individual well and the number of projects for which exploratory well costs have been capitalized.  The projects are aged based on the last well drilled in the project.

	September 30,
	2021				2020
(Thousands of dollars)	Amount		No. of Wells	No. of Projects	Amount	No. of Wells	No. of Projects
Aging of capitalized well costs:
Zero to one year	$	3,297	2	2	8,000	1	—
One to two years	—		—	—	54,334	5	5
Two to three years	53,078		5	5	—	—	—
Three years or more	130,248		6	—	125,525	6	—
	$	186,623	13	7	187,859	12	5

Of the $183.3 million of exploratory well costs capitalized more than one year at September 30, 2021, $92.3 million is in Vietnam, $45.0 million is in the U.S., $25.9 million is in Brunei, $15.3 million is in Mexico, and $4.8 million is in Canada.  In all geographical areas, either further appraisal or development drilling is planned and/or development studies/plans are in various stages of completion. 

Impairments

During the first quarter of 2021, the Company recorded an impairment charge of $171.3 million for Terra Nova due to the status, including agreements with the partners, of operating and production plans.

In 2020, declines in future oil and natural gas prices (principally driven by reduced demand from the COVID-19 pandemic) led to impairments in certain of the Company’s U.S. Offshore and Other Foreign properties. The Company recorded pretax noncash impairment charges of $1,206.3 million to reduce the carrying values to their estimated fair values at select properties.

The fair values were determined by internal discounted cash flow models using estimates of future production, prices, costs and discount rates believed to be consistent with those used by principal market participants in the applicable region.

The following table reflects the recognized impairments for the nine months ended September 30, 2021 and 2020.

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
U.S.	$	—	1,152,515
Canada	171,296		—
Other Foreign	—		39,709
Corporate	—		14,060
	$	171,296	1,206,284

Divestments

During the first quarter of 2021, the King’s Quay FPS was sold to ArcLight Capital Partners, LLC (ArcLight) for proceeds of $267.7 million, which reimburses the Company for previously incurred capital expenditures.

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Assets Held for Sale and Discontinued Operations

9 Months Ended

Sep. 30, 2021

Discontinued Operations and Disposal Groups [Abstract]

Assets Held for Sale and Discontinued Operations

Note E – Assets Held for Sale and Discontinued Operations

The Company has accounted for its former U.K. and U.S. refining and marketing and Malaysian exploration and production operations as discontinued operations for all periods presented.  The results of operations associated with discontinued operations for the three-month and nine-month periods ended September 30, 2021 and 2020 were as follows:

	Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars)	2021		2020	2021		2020
Revenues	$	144	—	$	801	4,074
Costs and expenses
Other costs and expenses (benefits)	850		778	1,401		10,981
(Loss) income before taxes	(706)		(778)	(600)		(6,907)
Income tax expense	—		—	—		—
(Loss) income from discontinued operations	$	(706)	(778)	$	(600)	(6,907)

As of September 30, 2021, assets held for sale on the Consolidated Balance Sheet include the carrying value of the net property, plant equipment of CA-2 project in Brunei and the Company’s office building in El Dorado, Arkansas. As of June 30, 2021, the CA-1 asset in Brunei is no longer being marketed for sale.

As of December 31, 2020, assets held for sale included the King’s Quay Floating Production System (FPS) of $250.1 million (sold in March 2021), the Brunei exploration and production properties, and the Company’s office building in El Dorado, Arkansas.

(Thousands of dollars)	September 30, 2021		December 31, 2020
Current assets
Cash	$	—	10,185
Inventories	—		406
Property, plant, and equipment, net	40,987		307,704
Deferred income taxes and other assets	—		9,441
Total current assets associated with assets held for sale	$	40,987	327,736
Current liabilities
Accounts payable	$	—	5,306
Other accrued liabilities	—		45
Current maturities of long-term debt (finance lease)	—		737
Taxes payable	—		1,510
Long-term debt (finance lease)	—		6,513
Asset retirement obligation	—		261
Total current liabilities associated with assets held for sale	$	—	14,372

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Financing Arrangements and Debt

9 Months Ended

Sep. 30, 2021

Debt Disclosure [Abstract]

Financing Arrangements and Debt

Note F – Financing Arrangements and Debt

As of September 30, 2021, the Company had a $1.6 billion revolving credit facility (RCF). The RCF is a senior unsecured guaranteed facility which expires in November 2023. At September 30, 2021, the Company had no outstanding borrowings under the RCF and $31.4 million of outstanding letters of credit, which reduce the borrowing capacity of the RCF. At September 30, 2021, the interest rate in effect on borrowings under the facility was 1.78%. At September 30, 2021, the Company was in compliance with all covenants related to the RCF.

In March 2021, the Company issued $550.0 million of new notes that bear interest at a rate of 6.375% and mature on July 15, 2028. The Company incurred transaction costs of $8.1 million on the issuance of these new notes and the Company will pay interest semi-annually on January 15 and July 15 of each year, beginning July 15, 2021. The proceeds of the $550.0 million notes, along with cash on hand, were used to redeem and cancel $259.3 million of the Company’s 4.00% notes due June 2022 and $317.1 million of the Company’s 4.95% notes due December 2022 (originally issued as 3.70% notes due 2022; collectively

the 2022 Notes). The cost of the debt extinguishment of $36.9 million is included in Interest expense, net on the Consolidated Statement of Operations for the nine months ended September 30, 2021. The cash costs of $34.2 million are shown as a financing activity on the Consolidated Statement of Cash Flows for the nine months ended September 30, 2021.

In August 2021, the Company redeemed $150.0 million aggregate principal amount of its 6.875% senior notes due 2024 (2024 Notes). The cost of the debt extinguishment of $3.5 million is included in Interest expense, net on the Consolidated Statement of Operations for the nine months ended September 30, 2021. The cash costs of $2.6 million are shown as a financing activity on the Consolidated Statement of Cash Flows for the nine months ended September 30, 2021.

The Company also has a shelf registration statement on file with the U.S. Securities and Exchange Commission that permits the offer and sale of debt and/or equity securities through October 15, 2024.

Subsequent to quarter end, the Company issued a notice of partial redemption with respect to $150.0 million aggregate principal amount of its 6.875% senior notes due 2024 (2024 Notes). The Company will redeem the 2024 Notes at the applicable redemption price set forth in the indenture governing the 2024 Notes, plus accrued and unpaid interest, if any, to the date of redemption. The redemption date of the 2024 Notes will be December 2, 2021.

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Other Financial Information

9 Months Ended

Sep. 30, 2021

Other Financial Information [Abstract]

Other Financial Information

Note G – Other Financial Information

Additional disclosures regarding cash flow activities are provided below.

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Net (increase) decrease in operating working capital, excluding cash and cash equivalents:
Decrease in accounts receivable ¹	$	75,100	251,706
Decrease in inventories	9,718		4,747
(Increase) in prepaid expenses	(6,682)		(17,400)
Increase (decrease) in accounts payable and accrued liabilities ¹	40,687		(264,078)
(Decrease) in income taxes payable	(1,493)		(1,236)
Net (increase) decrease in noncash operating working capital	$	117,330	(26,261)
Supplementary disclosures:
Cash income taxes paid, net of refunds	$	1,685	(12,559)
Interest paid, net of amounts capitalized of $11.6 million in 2021 and $5.9 million in 2020	127,793		139,651
Non-cash investing activities:
Asset retirement costs capitalized ²	$	36,300	6,342
Decrease in capital expenditure accrual	31,301		74,742

1 Excludes receivable/payable balances relating to mark-to-market of derivative instruments and contingent consideration relating to acquisitions.

2 Excludes non-cash capitalized cost offset by impairment of $74.4 million in the first quarter of 2021 and a gain in other operating income of $71.8 million following a commercial agreement to sanction an asset life extension project at Terra Nova in the third quarter of 2021, which extended the life of Terra Nova by approximately 10 years.

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Employee and Retiree Benefit Plans

9 Months Ended

Sep. 30, 2021

Retirement Benefits [Abstract]

Employee and Retiree Benefit Plans

Note H – Employee and Retiree Benefit Plans

The Company has defined benefit pension plans that are principally noncontributory and cover most full-time employees.  All pension plans are funded except for the U.S. and Canadian nonqualified supplemental plan and the U.S. director’s plan.  All U.S. tax qualified plans meet the funding requirements of federal laws and regulations.  Contributions to foreign plans are based on local laws and tax regulations.  The Company also sponsors health care and life insurance benefit plans, which are not funded, that cover most retired U.S. employees.  The health care benefits are contributory; the life insurance benefits are noncontributory.

The table that follows provides the components of net periodic benefit expense for the three-month and nine-month periods ended September 30, 2021 and 2020.

	Three Months Ended September 30,
	Pension Benefits			Other Postretirement Benefits
(Thousands of dollars)	2021		2020	2021	2020
Service cost	$	1,770	1,664	328	342
Interest cost	4,258		4,827	521	612
Expected return on plan assets	(6,038)		(5,773)	—	—
Amortization of prior service cost (credit)	155		149	—	—
Recognized actuarial loss	5,269		5,690	(8)	(24)
Net periodic benefit expense	$	5,414	6,557	841	930
	Nine Months Ended September 30,
	Pension Benefits			Other Postretirement Benefits
(Thousands of dollars)	2021		2020	2021	2020
Service cost	$	5,306	5,996	981	1,235
Interest cost	12,844		16,381	1,563	2,200
Expected return on plan assets	(18,326)		(18,414)	—	—
Amortization of prior service cost (credit)	467		515	—	—
Recognized actuarial loss	15,829		14,223	(23)	(24)
Net periodic benefit expense	$	16,120	18,701	2,521	3,411
Other - curtailment	—		586	—	(1,825)
Other - special termination benefits	—		8,435	—	—
Total net periodic benefit expense	$	16,120	27,722	2,521	1,586

The components of net periodic benefit expense, other than the service cost, curtailment and special termination benefits components, are included in the line item “Interest and other income (loss)” in Consolidated Statements of Operations.

During the nine-month period ended September 30, 2021, the Company made contributions of $31.0 million to its defined benefit pension and postretirement benefit plans. Remaining funding in 2021 for the Company’s defined benefit pension and postretirement plans is anticipated to be $10.9 million.

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Incentive Plans

9 Months Ended

Sep. 30, 2021

Share-based Payment Arrangement [Abstract]

Incentive Plans

Note I – Incentive Plans

The costs resulting from all share-based and cash-based incentive plans are recognized as an expense in the Consolidated Statements of Operations using a fair value-based measurement method over the periods that the awards vest.

The 2017 Annual Incentive Plan (2017 Annual Plan) authorizes the Executive Compensation Committee (the Committee) to establish specific performance goals associated with annual cash awards that may be earned by officers, executives and certain other employees.  Cash awards under the 2017 Annual Plan are determined based on the Company’s actual financial and operating results as measured against the performance goals established by the Committee. 

The 2020 Long-Term Incentive Plan (2020 Long-Term Plan) authorizes the Committee to make grants of the Company’s Common Stock to employees.  These grants may be in the form of stock options (nonqualified or incentive), stock appreciation rights (SAR), restricted stock, restricted stock units (RSU), performance units, performance shares, dividend equivalents and

other stock-based incentives.  The 2020 Long-Term Plan expires in 2030.  A total of five million shares are issuable during the life of the 2020 Long-Term Plan. Shares issued pursuant to awards granted under this Plan may be shares that are authorized and unissued or shares that were reacquired by the Company, including shares purchased in the open market. Share awards that have been canceled, expired, forfeited or otherwise not issued under an award shall not count as shares issued under this Plan.

During the first nine months of 2021, the Committee granted the following awards from the 2020 Long-Term Plan:

2020 Long-Term Incentive Plan

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Performance Based RSUs 1	1,156,800	February 2, 2021	$	16.03	Monte Carlo at Grant Date
Time Based RSUs 2	385,600	February 2, 2021	$	12.30	Average Stock Price at Grant Date
Cash Settled RSUs 3	1,022,700	February 2, 2021	$	12.30	Average Stock Price at Grant Date

1 Performance based RSUs are scheduled to vest over a three year performance period.

2 Time based RSUs are generally scheduled to vest over three years from the date of grant.

3 Cash settled RSUs are scheduled to vest over three years from the date of grant.

The Company also has a Stock Plan for Non-Employee Directors that permits the issuance of restricted stock, restricted stock units and stock options or a combination thereof to the Company’s Non-Employee Directors.

At the Company’s annual stockholders’ meeting held on May 12, 2021, shareholders approved the replacement of the 2018 Stock Plan for Non-Employee Directors (2018 NED Plan) with the 2021 Stock Plan for Non-Employee Directors (2021 NED Plan). The 2021 NED Plan permits the issuance of restricted stock, restricted stock units and stock options or a combination thereof to the Company’s Non-Employee Directors. The Company currently has outstanding incentive awards issued to Directors under the 2021 NED Plan and the 2018 NED Plan. All awards on or after May 12, 2021, will be made under the 2021 NED Plan.

During the first nine months of 2021, the Committee granted the following awards to Non-Employee Directors:

2018 Stock Plan for Non-Employee Directors

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Time Based RSUs 1	182,652	February 3, 2021	$	13.14	Closing Stock Price at Grant Date

1 Non-employee directors time-based RSUs are scheduled to vest in February 2022.

2021 Stock Plan for Non-Employee Directors

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Time Based RSUs 1	5,655	June 10, 2021	$	23.58	Closing Stock Price at Grant Date

1 Non-employee directors time-based RSUs are scheduled to vest in February 2022.

All stock option exercises are non-cash transactions for the Company.  The employee receives net shares, after applicable withholding obligations, upon each stock option exercise. The actual income tax benefit realized from the tax deductions related to stock option exercises of the share-based payment arrangements were immaterial for the nine-month period ended September 30, 2021.

Amounts recognized in the financial statements with respect to share-based plans are shown in the following table:

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Compensation charged against income before tax benefit	$	29,145	17,542
Related income tax benefit recognized in income	4,120		2,278

Certain incentive compensation granted to the Company’s named executive officers, to the extent their total compensation exceeds $1.0 million per executive per year, is not eligible for a U.S. income tax deduction under the Tax Cuts and Jobs Act (2017 Tax Act).

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Earnings Per Share

9 Months Ended

Sep. 30, 2021

Earnings Per Share [Abstract]

Earnings Per Share

Note J – Earnings Per Share

Net (loss) income attributable to Murphy was used as the numerator in computing both basic and diluted income per Common share for the three-month and nine-month periods ended September 30, 2021 and 2020.  The following table reports the weighted-average shares outstanding used for these computations.

	Three Months Ended September 30,		Nine Months Ended September 30,
(Weighted-average shares)	2021	2020	2021	2020
Basic method	154,439,313	153,596,109	154,239,440	153,479,654
Dilutive stock options and restricted stock units ¹	1,492,949	—	—	—
Diluted method	155,932,262	153,596,109	154,239,440	153,479,654

1 Due to a net loss recognized by the Company for the nine-month period ended September 30, 2021 and the three-month and nine-month periods ended September 30, 2020, no unvested stock awards were included in the computation of diluted earnings per share because the effect would have been antidilutive.

The following table reflects certain options to purchase shares of common stock that were outstanding during the periods presented but were not included in the computation of diluted shares above because the incremental shares from the assumed conversion were antidilutive.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Antidilutive stock options excluded from diluted shares	1,316,222		2,111,068		1,502,758		2,305,973
Weighted average price of these options	$	34.42	$	38.54	$	34.97	$	40.15

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Income Taxes

9 Months Ended

Sep. 30, 2021

Income Tax Disclosure [Abstract]

Income Taxes

Note K – Income Taxes

The Company’s effective income tax rate is calculated as the amount of income tax expense (benefit) divided by income (loss) from continuing operations before income taxes.  For the three-month and nine-month periods ended September 30, 2021 and 2020, the Company’s effective income tax rates were as follows:

	2021	2020
Three months ended September 30,	21.1%	19.1%
Nine months ended September 30,	28.6%	18.6%

The effective tax rate for the three-month period ended September 30, 2021 was above the U.S. statutory tax rate of 21% primarily due to income generated in Canada, which has a higher tax rate, offset by no tax applied to the pre-tax income of the noncontrolling interest in MP GOM, which has the impact of decreasing the effective tax rate on income.

The effective tax rate for the three-month period ended September 30, 2020 was below the statutory tax rate of 21% due to exploration expenses in certain foreign jurisdictions in which no income tax benefit is available, as well as no tax benefit available from the pre-tax loss of the noncontrolling interest in MP GOM.

The effective tax rate for the nine-month period ended September 30, 2021 was above the U.S. statutory tax rate of 21% primarily due to no tax applied to the pre-tax income of the noncontrolling interest in MP GOM, which has the impact of increasing the effective tax rate on an overall loss.

The effective tax rate for the nine-month period ended September 30, 2020 was below the statutory tax rate of 21% due to exploration expenses in certain foreign jurisdictions in which no income tax benefit is available, as well as no tax benefit available from the pre-tax loss of the noncontrolling interest in MP GOM. These items reduced the tax credit on a reported pre-tax net loss.

The Company’s tax returns in multiple jurisdictions are subject to audit by taxing authorities, and currently the Company is under audit in several of these jurisdictions.  These audits often take multiple years to complete and settle.  Although the Company believes that recorded liabilities for unsettled issues are adequate, additional gains or losses could occur in future years from resolution of outstanding unsettled matters.  As of September 30, 2021, the earliest years remaining open for audit and/or settlement in our major taxing jurisdictions are as follows: United States – 2016; Canada – 2016; Malaysia – 2014; and

United Kingdom – 2018. Following the divestment of Malaysia in the third quarter of 2019, the Company has retained certain possible liabilities and rights to income tax receivables relating to Malaysia for the years prior to 2019. The Company believes current recorded liabilities are adequate

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Financial Instruments and Risk Management

9 Months Ended

Sep. 30, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Financial Instruments and Risk Management

Note L – Financial Instruments and Risk Management

Murphy uses derivative instruments, such as swaps and zero-cost commodity price collar contracts, to manage certain risks related to commodity prices, foreign currency exchange rates and interest rates.  The use of derivative instruments for risk management is covered by operating policies and is closely monitored by the Company’s senior management.  The Company does not hold any derivatives for speculative purposes and it does not use derivatives with leveraged or complex features.  Derivative instruments are traded with creditworthy major financial institutions or over national exchanges such as the New York Mercantile Exchange (NYMEX).  The Company has a risk management control system to monitor commodity price risks and any derivatives obtained to manage a portion of such risks.  For accounting purposes, the Company has not designated commodity and foreign currency derivative contracts as hedges, and therefore, it recognizes all gains and losses on these derivative contracts in its Consolidated Statements of Operations.  

Certain interest rate derivative contracts were previously accounted for as hedges and the gain or loss associated with recording the fair value of these contracts was deferred in Accumulated other comprehensive loss and amortized to the income statement over time. During the nine-month period ended September 30, 2021, the Company redeemed all of the remaining notes due 2022 and expensed the remainder of the previously deferred loss on the interest rate swap of $2.1 million to Interest expense in the Consolidated Statement of Operations.

Commodity Price Risks

The Company has entered into crude oil swaps and collar contracts. Under the swaps contracts, which mature monthly, the Company pays the average monthly price in effect and receives the fixed contract price on a notional amount of sales volume, thereby fixing the price for the commodity sold. Under the collar contracts, which also mature monthly, the Company purchased a put option and sold a call option with no net premiums paid to or received from counterparties. Upon maturity, collar contracts require payments by the Company if the NYMEX average closing price is above the ceiling price or payments to the Company if the NYMEX average closing price is below the floor price.

At September 30, 2021, volumes per day associated with outstanding crude oil derivative contracts and the weighted average prices for these contracts are as follows:

	September 30, 2021
	2021		2022
NYMEX WTI swap contracts:
Volume per day (Bbl):	45,000		20,000
Price per Bbl:	$	42.77	$	44.88
NYMEX WTI collar contracts:
Volume per day (Bbl):	—		16,000
Price per Bbl:
Ceiling:	$	—	$	71.83
Floor:	—		60.38

Foreign Currency Exchange Risks

The Company is subject to foreign currency exchange risk associated with operations in countries outside the U.S. The Company had no foreign currency exchange derivatives outstanding at September 30, 2021 and 2020.

At September 30, 2021 and December 31, 2020, the fair value of derivative instruments not designated as hedging instruments are presented in the following table.

	September 30, 2021			December 31, 2020
(Thousands of dollars)	Asset (Liability) Derivatives			Asset (Liability) Derivatives
Type of Derivative Contract	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity swaps	Accounts receivable	$	—	Accounts receivable	13,050
	Accounts payable	(312,448)		Accounts payable	(89,842)
	Deferred credits and other liabilities	(41,645)		Deferred credits and other liabilities	(12,833)
Commodity collars	Accounts receivable	—		Accounts receivable	—
	Accounts payable	(15,929)		Accounts payable	—

For the three-month and nine-month periods ended September 30, 2021 and 2020, the gains and losses recognized in the Consolidated Statements of Operations for derivative instruments not designated as hedging instruments are presented in the following table.

		Gain (Loss)			Gain (Loss)
(Thousands of dollars)	Statement of Operations Location	Three Months Ended September 30,			Nine months ended September 30,
Type of Derivative Contract		2021		2020	2021	2020
Commodity swaps	(Loss) gain on derivative instruments	$	(43,235)	(5,290)	(483,865)	319,502
Commodity collars	(Loss) gain on derivative instruments	(15,929)		—	(15,929)	—

Fair Values – Recurring

The Company carries certain assets and liabilities at fair value in its Consolidated Balance Sheets.  The fair value hierarchy is based on the quality of inputs used to measure fair value, with Level 1 being the highest quality and Level 3 being the lowest quality.  Level 1 inputs are quoted prices in active markets for identical assets or liabilities.  Level 2 inputs are observable inputs other than quoted prices included within Level 1.  Level 3 inputs are unobservable inputs which reflect assumptions about pricing by market participants.

The carrying value of assets and liabilities recorded at fair value on a recurring basis at September 30, 2021 and December 31, 2020, are presented in the following table.

	September 30, 2021					December 31, 2020
(Thousands of dollars)	Level 1		Level 2	Level 3	Total	Level 1	Level 2	Level 3	Total
Assets:
Commodity swaps	$	—	—	—	—	—	13,050	—	13,050
	$	—	—	—	—	—	13,050	—	13,050
Liabilities:
Commodity collars	$	—	15,929	—	15,929	—	—	—	—
Nonqualified employee savings plan	17,180		—	—	17,180	14,988	—	—	14,988
Commodity swaps	—		354,093	—	354,093	—	102,675	—	102,675
Contingent consideration	—		—	238,115	238,115	—	—	133,004	133,004
	$	17,180	370,022	238,115	625,317	14,988	102,675	133,004	250,667

The fair value of commodity (WTI crude oil) derivative contracts in 2021 and 2020 were based on active market quotes for WTI crude oil.  The before tax income effect of changes in the fair value of crude oil derivative contracts is recorded in Gain (loss) on derivative instruments in the Consolidated Statements of Operations. 

The nonqualified employee savings plan is an unfunded savings plan through which participants seek a return via phantom investments in equity securities and/or mutual funds.  The fair value of this liability was based on quoted prices for these equity securities and mutual funds.  The income effect of changes in the fair value of the nonqualified employee savings plan is recorded in Selling and general expenses in the Consolidated Statements of Operations. 

The contingent consideration, related to two acquisitions in 2019 and 2018, is valued using a Monte Carlo simulation model. The income effect of changes in the fair value of the contingent consideration is recorded in Other expense (benefit) in the Consolidated Statements of Operations. Contingent consideration is payable annually in years 2022 to 2026.The Company offsets certain assets and liabilities related to derivative contracts when the legal right of offset exists. There were no offsetting positions recorded at September 30, 2021 and December 31, 2020.

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Accumulated Other Comprehensive Loss

9 Months Ended

Sep. 30, 2021

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

Accumulated Other Comprehensive Loss

Note M – Accumulated Other Comprehensive Loss

The components of Accumulated other comprehensive loss on the Consolidated Balance Sheets at December 31, 2020 and September 30, 2021 and the changes during the nine-month period ended September 30, 2021, are presented net of taxes in the following table.

(Thousands of dollars)	Foreign Currency Translation Gains (Losses)		Retirement and Postretirement Benefit Plan Adjustments		Deferred Loss on Interest Rate Derivative Hedges		Total
Balance at December 31, 2020	$	(324,011)	(275,632)		(1,690)		(601,333)
Components of other comprehensive income (loss):
Before reclassifications to income and retained earnings	6,534		—		—		6,534
Reclassifications to income	—		12,935	¹	1,690	²	14,625
Net other comprehensive income (loss)	6,534		12,935		1,690		21,159
Balance at September 30, 2021	$	(317,477)	(262,697)		—		(580,174)

1 Reclassifications before taxes of $16,282 are included in the computation of net periodic benefit expense for the nine-month period ended September 30, 2021.  See Note H for additional information.  Related income taxes of $3,347 are included in Income tax expense (benefit) for the nine-month period ended September 30, 2021.

2 Reclassifications before taxes of $2,140 are included in Interest expense, net, for the nine-month period ended September 30, 2021.  Related income taxes of $450 are included in Income tax expense (benefit) for the nine-month period ended September 30, 2021. See Note L for additional information.

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Environmental and Other Contingencies

9 Months Ended

Sep. 30, 2021

Environmental Remediation Obligations [Abstract]

Environmental and Other Contingencies

Note N – Environmental and Other Contingencies

The Company’s operations and earnings have been and may be affected by various forms of governmental action both in the United States and throughout the world.  Examples of such governmental action include, but are by no means limited to:  tax legislation changes, including tax rate changes, and retroactive tax claims; royalty and revenue sharing increases; import and export controls; price controls; currency controls; allocation of supplies of crude oil and petroleum products and other goods; expropriation of property; restrictions and preferences affecting the issuance of oil and natural gas or mineral leases; restrictions on drilling and/or production; laws and regulations intended for the promotion of safety and the protection and/or remediation of the environment; governmental support for other forms of energy; and laws and regulations affecting the Company’s relationships with employees, suppliers, customers, stockholders and others. Governmental actions are often motivated by political considerations and may be taken without full consideration of their consequences or may be taken in response to actions of other governments.  It is not practical to attempt to predict the likelihood of such actions, the form the actions may take or the effect such actions may have on the Company.

ENVIRONMENTAL, HEALTH AND SAFETY MATTERS – Murphy and other companies in the oil and natural gas industry are subject to numerous federal, state, local and foreign laws and regulations dealing with the environment and protection of health and safety. The principal environmental, health and safety laws and regulations to which Murphy is subject address such matters as the generation, storage, handling, use, disposal and remediation of petroleum products, wastewater and hazardous materials; the emission and discharge of such materials to the environment, including greenhouse gas emissions; wildlife, habitat and water protection; the placement, operation and decommissioning of production equipment; and the health and

safety of our employees, contractors and communities where our operations are located. These laws and regulations also generally require permits for existing operations, as well as the construction or development of new operations and the decommissioning facilities once production has ceased.

Violation of environmental, health and safety laws, regulations and permits can result in the imposition of significant civil and criminal penalties, injunctions and construction bans or delays. A discharge of hazardous substances into the environment

could, to the extent such event is not insured, subject the Company to substantial expense, including both the cost to comply with applicable laws and regulations and claims by neighboring landowners and other third parties for any personal injury and property damage that might result. Item 103 of SEC Regulation S-K requires disclosure of certain environmental matters when a governmental authority is a party to the proceedings and such proceedings involve potential monetary sanctions that the Company reasonably believes will exceed a specified threshold. Pursuant to recent SEC amendments to this item, the Company will be using a threshold of $1.0 million for such proceedings.

The Biden administration has indicated that it intends to increase regulatory oversight of the oil and gas industry, with a focus on climate change and greenhouse gas emissions (including methane emissions). The Biden administration has issued a number of executive orders that address climate change, including creation of climate-related task forces, directives to federal agencies to procure carbon-free electricity, and a goal of a carbon pollution-free power sector by 2035 and a net-zero emissions U.S. economy by 2050. The Biden administration has also issued orders related to oil and gas activities on federal lands, infrastructure and environmental justice. In addition, an international climate agreement (the Paris Agreement) was agreed to at the 2015 United Nations Framework Convention on Climate Change in Paris, France. The Paris Agreement entered into force in November 2016. Although the U.S. officially withdrew from the Paris Agreement on November 4, 2020, on January 20, 2021, President Biden began the 30-day process of rejoining the Paris Agreement, which became effective for the U.S. on February 19, 2021.

The Company currently owns or leases, and has in the past owned or leased, properties at which hazardous substances have been or are being handled. Hazardous substances may have been disposed of or released on or under the properties owned or leased by the Company or on or under other locations where these wastes have been taken for disposal. In addition, many of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons or other wastes were not under Murphy’s control. Under existing laws, the Company could be required to investigate, remove or remediate previously disposed wastes (including wastes disposed of or released by prior owners or operators), to investigate and clean up contaminated property (including contaminated groundwater) or to perform remedial plugging operations to prevent future contamination. Certain of these historical properties are in various stages of negotiation, investigation, and/or cleanup, and the Company is investigating the extent of any such liability and the availability of applicable defenses. The Company has retained certain liabilities related to environmental matters at formerly owned U.S. refineries that were sold in 2011. The Company also obtained insurance covering certain levels of environmental exposures related to past operations of these refineries. Murphy USA Inc. has retained any environmental exposure associated with Murphy’s former U.S. marketing operations that were spun-off in August 2013. The Company believes costs related to these sites will not have a material adverse effect on Murphy’s net income, financial condition or liquidity in a future period.

There is the possibility that environmental expenditures could be required at currently unidentified sites, and additional expenditures could be required at known sites. However, based on information currently available to the Company, the amount of future investigation and remediation costs incurred at known or currently unidentified sites is not expected to have a material adverse effect on the Company’s future net income, cash flows or liquidity.

LEGAL MATTERS – Murphy and its subsidiaries are engaged in a number of other legal proceedings, all of which Murphy considers routine and incidental to its business. Based on information currently available to the Company, the ultimate resolution of environmental and legal matters referred to in this note is not expected to have a material adverse effect on the Company’s net income, financial condition or liquidity in a future period.

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Business Segments

9 Months Ended

Sep. 30, 2021

Segment Reporting [Abstract]

Business Segments

Note O – Business Segments

Information about business segments and geographic operations is reported in the following table.  For geographic purposes, revenues are attributed to the country in which the sale occurs.  Corporate, including interest income, other gains and losses (including foreign exchange gains/losses and realized and unrealized gains/losses on crude oil contracts), interest expense and unallocated overhead, is shown in the tables to reconcile the business segments to consolidated totals.

	Total Assets at September 30, 2021		Three Months Ended September 30, 2021		Three Months Ended September 30, 2020
(Millions of dollars)			External Revenues	Income (Loss)	External Revenues	Income (Loss)
Exploration and production ¹
United States	$	6,586.3	565.2	168.1	330.8	(172.6)
Canada	2,241.2		124.6	73.9	96.3	(8.6)
Other	264.6		—	(5.2)	—	(11.7)
Total exploration and production	9,092.1		689.8	236.8	427.1	(192.9)
Corporate	1,237.8		(59.1)	(98.8)	(5.2)	(72.9)
Continuing operations	10,329.9		630.7	138.0	421.9	(265.8)
Discontinued operations, net of tax	1.0		—	(0.7)	—	(0.8)
Total	$	10,330.9	630.7	137.3	421.9	(266.6)
			Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
(Millions of dollars)			External Revenues	Income (Loss)	External Revenues	Income (Loss)
Exploration and production ¹
United States			1,704.4	481.8	1,070.6	(1,011.7)
Canada			349.2	(37.7)	245.2	(35.0)
Other			—	(22.5)	1.8	(73.0)
Total exploration and production			2,053.6	421.6	1,317.6	(1,119.7)
Corporate			(493.3)	(577.6)	319.5	26.9
Continuing operations			1,560.3	(156.0)	1,637.1	(1,092.8)
Discontinued operations, net of tax			—	(0.6)	—	(6.9)
Total			1,560.3	(156.6)	1,637.1	(1,099.7)

1 Additional details about results of oil and natural gas operations are presented in the table on pages 25 and 26.

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New Accounting Principles and Recent Accounting Pronouncements (Policies)

9 Months Ended

Sep. 30, 2021

Accounting Changes and Error Corrections [Abstract]

Nature of Business

NATURE OF BUSINESS – Murphy Oil Corporation is an international oil and natural gas exploration and production company that conducts its business through various operating subsidiaries.  The Company primarily produces oil and natural gas in the United States and Canada and conducts oil and natural gas exploration activities worldwide.

Accounting Principles Adopted and Recent Accounting Pronouncements

Accounting Principles Adopted

Income Taxes. In December 2019, the FASB issued ASU 2019-12, which removes certain exceptions for investments, intraperiod allocations and interim calculations, and adds guidance to reduce complexity in accounting for income taxes. The amendments in this ASU are effective for fiscal years, and interim periods within those fiscal years, beginning after December 15, 2020. Implementation on a prospective or retrospective basis varies by specific topics within the ASU. The Company adopted this guidance in the first quarter of 2021 and it did not have a material impact on its consolidated financial statements.

Recent Accounting Pronouncements

None affecting the Company.

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Revenue from Contracts with Customers (Tables)

9 Months Ended

Sep. 30, 2021

Revenue from Contract with Customer [Abstract]

Disaggregation of Revenue

For the three-month and nine-month periods ended September 30, 2021, the Company recognized $687.5 million and $2,038.9 million, respectively, from contracts with customers for the sales of oil, natural gas liquids and natural gas. For the three-month and nine-month periods ended September 30, 2020, the Company recognized $425.3 million and $1,311.6 million, respectively, from contracts with customers for the sales of oil, natural gas liquids and natural gas.

		Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars)		2021		2020	2021	2020
Net crude oil and condensate revenue
United States	Onshore	$	167,010	86,498	464,767	272,284
	Offshore	340,001		216,918	1,079,418	714,143
Canada	Onshore	29,110		32,358	89,708	67,268
	Offshore	20,499		19,173	70,333	54,864
Other		—		—	—	1,806
Total crude oil and condensate revenue		556,620		354,947	1,704,226	1,110,365
Net natural gas liquids revenue
United States	Onshore	16,356		6,766	33,480	16,145
	Offshore	11,046		4,765	31,866	13,255
Canada	Onshore	4,501		2,780	11,728	6,090
Total natural gas liquids revenue		31,903		14,311	77,074	35,490
Net natural gas revenue
United States	Onshore	11,127		4,529	24,442	14,177
	Offshore	17,444		9,827	56,855	35,487
Canada	Onshore	70,455		41,710	176,308	116,108
Total natural gas revenue		99,026		56,066	257,605	165,772
Total revenue from contracts with customers		687,549		425,324	2,038,905	1,311,627
(Loss) gain on derivative instruments		(59,164)		(5,290)	(499,794)	319,502
Gain on sale of assets and other income		2,315		1,831	21,217	6,006
Total revenue and other income		$	630,700	421,865	1,560,328	1,637,135

Current Long-Term Contracts Outstanding

As of September 30, 2021, the Company had the following sales contracts in place which are expected to generate revenue from sales to customers for a period of more than 12 months starting at the inception of the contract:

Current Long-Term Contracts Outstanding at September 30, 2021
Location	Commodity	End Date		Description	Approximate Volumes
U.S.	Oil	Q4 2021		Fixed quantity delivery in Eagle Ford	17,000 BOED
U.S.	Natural Gas and NGL	Q1 2023		Deliveries from dedicated acreage in Eagle Ford	As produced
Canada	Natural Gas	Q4 2021		Contracts to sell natural gas at USD index pricing	10 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at USD index pricing	8 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at CAD fixed prices	5 MMCFD
Canada	Natural Gas	Q4 2022		Contracts to sell natural gas at USD fixed pricing	20 MMCFD
Canada	Natural Gas	Q4 2023	1	Contracts to sell natural gas at USD index pricing	25 MMCFD
Canada	Natural Gas	Q4 2023		Contracts to sell natural gas at CAD fixed prices	38 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at USD index pricing	31 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at CAD fixed prices	100 MMCFD
Canada	Natural Gas	Q4 2024	1	Contracts to sell natural gas at CAD fixed prices	34 MMCFD
Canada	Natural Gas	Q4 2024		Contracts to sell natural gas at USD fixed pricing	15 MMCFD
Canada	Natural Gas	Q4 2026	1	Contracts to sell natural gas at USD index pricing	49 MMCFD

1 These contracts are scheduled to commence after the balance sheet date, at various dates between Q4 2021 and Q1 2022.

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Property, Plant and Equipment (Tables)

9 Months Ended

Sep. 30, 2021

Property, Plant and Equipment [Abstract]

Net Changes in Capitalized Exploratory Well Costs

The following table reflects the net changes in capitalized exploratory well costs during the nine-month periods ended September 30, 2021 and 2020.

(Thousands of dollars)	2021		2020
Beginning balance at January 1	$	181,616	217,326
Additions pending the determination of proved reserves	5,007		9,941
Capitalized exploratory well costs charged to expense	—		(39,408)
Balance at September 30	$	186,623	187,859

Aging of Capitalized Exploratory Well Costs

The following table provides an aging of capitalized exploratory well costs based on the date the drilling was completed for each individual well and the number of projects for which exploratory well costs have been capitalized.  The projects are aged based on the last well drilled in the project.

	September 30,
	2021				2020
(Thousands of dollars)	Amount		No. of Wells	No. of Projects	Amount	No. of Wells	No. of Projects
Aging of capitalized well costs:
Zero to one year	$	3,297	2	2	8,000	1	—
One to two years	—		—	—	54,334	5	5
Two to three years	53,078		5	5	—	—	—
Three years or more	130,248		6	—	125,525	6	—
	$	186,623	13	7	187,859	12	5

Schedule of Recognized Impairments

The following table reflects the recognized impairments for the nine months ended September 30, 2021 and 2020.

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
U.S.	$	—	1,152,515
Canada	171,296		—
Other Foreign	—		39,709
Corporate	—		14,060
	$	171,296	1,206,284

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Assets Held for Sale and Discontinued Operations (Tables)

9 Months Ended

Sep. 30, 2021

Discontinued Operations and Disposal Groups [Abstract]

Results of Operations Associated with Discontinued Operations

The results of operations associated with discontinued operations for the three-month and nine-month periods ended September 30, 2021 and 2020 were as follows:

	Three Months Ended September 30,			Nine Months Ended September 30,
(Thousands of dollars)	2021		2020	2021		2020
Revenues	$	144	—	$	801	4,074
Costs and expenses
Other costs and expenses (benefits)	850		778	1,401		10,981
(Loss) income before taxes	(706)		(778)	(600)		(6,907)
Income tax expense	—		—	—		—
(Loss) income from discontinued operations	$	(706)	(778)	$	(600)	(6,907)

Major Categories of Assets and Liabilities Reflected as Held for Sale

(Thousands of dollars)	September 30, 2021		December 31, 2020
Current assets
Cash	$	—	10,185
Inventories	—		406
Property, plant, and equipment, net	40,987		307,704
Deferred income taxes and other assets	—		9,441
Total current assets associated with assets held for sale	$	40,987	327,736
Current liabilities
Accounts payable	$	—	5,306
Other accrued liabilities	—		45
Current maturities of long-term debt (finance lease)	—		737
Taxes payable	—		1,510
Long-term debt (finance lease)	—		6,513
Asset retirement obligation	—		261
Total current liabilities associated with assets held for sale	$	—	14,372

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Other Financial Information (Tables)

9 Months Ended

Sep. 30, 2021

Other Financial Information [Abstract]

Noncash Operating Working Capital (Increase) Decrease

Additional disclosures regarding cash flow activities are provided below.

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Net (increase) decrease in operating working capital, excluding cash and cash equivalents:
Decrease in accounts receivable ¹	$	75,100	251,706
Decrease in inventories	9,718		4,747
(Increase) in prepaid expenses	(6,682)		(17,400)
Increase (decrease) in accounts payable and accrued liabilities ¹	40,687		(264,078)
(Decrease) in income taxes payable	(1,493)		(1,236)
Net (increase) decrease in noncash operating working capital	$	117,330	(26,261)
Supplementary disclosures:
Cash income taxes paid, net of refunds	$	1,685	(12,559)
Interest paid, net of amounts capitalized of $11.6 million in 2021 and $5.9 million in 2020	127,793		139,651
Non-cash investing activities:
Asset retirement costs capitalized ²	$	36,300	6,342
Decrease in capital expenditure accrual	31,301		74,742

1 Excludes receivable/payable balances relating to mark-to-market of derivative instruments and contingent consideration relating to acquisitions.

2 Excludes non-cash capitalized cost offset by impairment of $74.4 million in the first quarter of 2021 and a gain in other operating income of $71.8 million following a commercial agreement to sanction an asset life extension project at Terra Nova in the third quarter of 2021, which extended the life of Terra Nova by approximately 10 years.

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Employee and Retiree Benefit Plans (Tables)

9 Months Ended

Sep. 30, 2021

Retirement Benefits [Abstract]

Components of Net Periodic Benefit Expense

The table that follows provides the components of net periodic benefit expense for the three-month and nine-month periods ended September 30, 2021 and 2020.

	Three Months Ended September 30,
	Pension Benefits			Other Postretirement Benefits
(Thousands of dollars)	2021		2020	2021	2020
Service cost	$	1,770	1,664	328	342
Interest cost	4,258		4,827	521	612
Expected return on plan assets	(6,038)		(5,773)	—	—
Amortization of prior service cost (credit)	155		149	—	—
Recognized actuarial loss	5,269		5,690	(8)	(24)
Net periodic benefit expense	$	5,414	6,557	841	930
	Nine Months Ended September 30,
	Pension Benefits			Other Postretirement Benefits
(Thousands of dollars)	2021		2020	2021	2020
Service cost	$	5,306	5,996	981	1,235
Interest cost	12,844		16,381	1,563	2,200
Expected return on plan assets	(18,326)		(18,414)	—	—
Amortization of prior service cost (credit)	467		515	—	—
Recognized actuarial loss	15,829		14,223	(23)	(24)
Net periodic benefit expense	$	16,120	18,701	2,521	3,411
Other - curtailment	—		586	—	(1,825)
Other - special termination benefits	—		8,435	—	—
Total net periodic benefit expense	$	16,120	27,722	2,521	1,586

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Incentive Plans (Tables)

9 Months Ended

Sep. 30, 2021

Share-based Payment Arrangement [Abstract]

Summary of Awards Granted

During the first nine months of 2021, the Committee granted the following awards from the 2020 Long-Term Plan:

2020 Long-Term Incentive Plan

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Performance Based RSUs 1	1,156,800	February 2, 2021	$	16.03	Monte Carlo at Grant Date
Time Based RSUs 2	385,600	February 2, 2021	$	12.30	Average Stock Price at Grant Date
Cash Settled RSUs 3	1,022,700	February 2, 2021	$	12.30	Average Stock Price at Grant Date

1 Performance based RSUs are scheduled to vest over a three year performance period.

2 Time based RSUs are generally scheduled to vest over three years from the date of grant.

3 Cash settled RSUs are scheduled to vest over three years from the date of grant.

During the first nine months of 2021, the Committee granted the following awards to Non-Employee Directors:

2018 Stock Plan for Non-Employee Directors

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Time Based RSUs 1	182,652	February 3, 2021	$	13.14	Closing Stock Price at Grant Date

1 Non-employee directors time-based RSUs are scheduled to vest in February 2022.

2021 Stock Plan for Non-Employee Directors

Type of Award	Number of Awards Granted	Grant Date	Grant Date Fair Value		Valuation Methodology
Time Based RSUs 1	5,655	June 10, 2021	$	23.58	Closing Stock Price at Grant Date

1 Non-employee directors time-based RSUs are scheduled to vest in February 2022.

Share-Based Plans, Amounts Recognized in the Financial Statements

Amounts recognized in the financial statements with respect to share-based plans are shown in the following table:

	Nine Months Ended September 30,
(Thousands of dollars)	2021		2020
Compensation charged against income before tax benefit	$	29,145	17,542
Related income tax benefit recognized in income	4,120		2,278

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Earnings Per Share (Tables)

9 Months Ended

Sep. 30, 2021

Earnings Per Share [Abstract]

Weighted-Average Shares Outstanding for Computation of Basic and Diluted Income per Common Share

The following table reports the weighted-average shares outstanding used for these computations.

	Three Months Ended September 30,		Nine Months Ended September 30,
(Weighted-average shares)	2021	2020	2021	2020
Basic method	154,439,313	153,596,109	154,239,440	153,479,654
Dilutive stock options and restricted stock units ¹	1,492,949	—	—	—
Diluted method	155,932,262	153,596,109	154,239,440	153,479,654

1 Due to a net loss recognized by the Company for the nine-month period ended September 30, 2021 and the three-month and nine-month periods ended September 30, 2020, no unvested stock awards were included in the computation of diluted earnings per share because the effect would have been antidilutive.

Anti Dilutive Securities Not Included in Computation of Diluted EPS

The following table reflects certain options to purchase shares of common stock that were outstanding during the periods presented but were not included in the computation of diluted shares above because the incremental shares from the assumed conversion were antidilutive.

	Three Months Ended September 30,				Nine Months Ended September 30,
	2021		2020		2021		2020
Antidilutive stock options excluded from diluted shares	1,316,222		2,111,068		1,502,758		2,305,973
Weighted average price of these options	$	34.42	$	38.54	$	34.97	$	40.15

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Income Taxes (Tables)

9 Months Ended

Sep. 30, 2021

Income Tax Disclosure [Abstract]

Effective Income Tax Rates

For the three-month and nine-month periods ended September 30, 2021 and 2020, the Company’s effective income tax rates were as follows:

	2021	2020
Three months ended September 30,	21.1%	19.1%
Nine months ended September 30,	28.6%	18.6%

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Financial Instruments and Risk Management (Tables)

9 Months Ended

Sep. 30, 2021

Derivative Instruments and Hedging Activities Disclosure [Abstract]

Schedule of Crude Oil Derivative Contracts

At September 30, 2021, volumes per day associated with outstanding crude oil derivative contracts and the weighted average prices for these contracts are as follows:

	September 30, 2021
	2021		2022
NYMEX WTI swap contracts:
Volume per day (Bbl):	45,000		20,000
Price per Bbl:	$	42.77	$	44.88
NYMEX WTI collar contracts:
Volume per day (Bbl):	—		16,000
Price per Bbl:
Ceiling:	$	—	$	71.83
Floor:	—		60.38

Fair Value of Derivative Instruments Not Designated as Hedging Instruments

At September 30, 2021 and December 31, 2020, the fair value of derivative instruments not designated as hedging instruments are presented in the following table.

	September 30, 2021			December 31, 2020
(Thousands of dollars)	Asset (Liability) Derivatives			Asset (Liability) Derivatives
Type of Derivative Contract	Balance Sheet Location	Fair Value		Balance Sheet Location	Fair Value
Commodity swaps	Accounts receivable	$	—	Accounts receivable	13,050
	Accounts payable	(312,448)		Accounts payable	(89,842)
	Deferred credits and other liabilities	(41,645)		Deferred credits and other liabilities	(12,833)
Commodity collars	Accounts receivable	—		Accounts receivable	—
	Accounts payable	(15,929)		Accounts payable	—

Recognized Gains and Losses for Derivative Instruments Not Designated as Hedging Instruments

For the three-month and nine-month periods ended September 30, 2021 and 2020, the gains and losses recognized in the Consolidated Statements of Operations for derivative instruments not designated as hedging instruments are presented in the following table.

		Gain (Loss)			Gain (Loss)
(Thousands of dollars)	Statement of Operations Location	Three Months Ended September 30,			Nine months ended September 30,
Type of Derivative Contract		2021		2020	2021	2020
Commodity swaps	(Loss) gain on derivative instruments	$	(43,235)	(5,290)	(483,865)	319,502
Commodity collars	(Loss) gain on derivative instruments	(15,929)		—	(15,929)	—

Carrying Value of Assets and Liabilities Recorded at Fair Value on Recurring Basis

The carrying value of assets and liabilities recorded at fair value on a recurring basis at September 30, 2021 and December 31, 2020, are presented in the following table.

	September 30, 2021					December 31, 2020
(Thousands of dollars)	Level 1		Level 2	Level 3	Total	Level 1	Level 2	Level 3	Total
Assets:
Commodity swaps	$	—	—	—	—	—	13,050	—	13,050
	$	—	—	—	—	—	13,050	—	13,050
Liabilities:
Commodity collars	$	—	15,929	—	15,929	—	—	—	—
Nonqualified employee savings plan	17,180		—	—	17,180	14,988	—	—	14,988
Commodity swaps	—		354,093	—	354,093	—	102,675	—	102,675
Contingent consideration	—		—	238,115	238,115	—	—	133,004	133,004
	$	17,180	370,022	238,115	625,317	14,988	102,675	133,004	250,667

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Accumulated Other Comprehensive Loss (Tables)

9 Months Ended

Sep. 30, 2021

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

Components of Accumulated Other Comprehensive Loss

The components of Accumulated other comprehensive loss on the Consolidated Balance Sheets at December 31, 2020 and September 30, 2021 and the changes during the nine-month period ended September 30, 2021, are presented net of taxes in the following table.

(Thousands of dollars)	Foreign Currency Translation Gains (Losses)		Retirement and Postretirement Benefit Plan Adjustments		Deferred Loss on Interest Rate Derivative Hedges		Total
Balance at December 31, 2020	$	(324,011)	(275,632)		(1,690)		(601,333)
Components of other comprehensive income (loss):
Before reclassifications to income and retained earnings	6,534		—		—		6,534
Reclassifications to income	—		12,935	¹	1,690	²	14,625
Net other comprehensive income (loss)	6,534		12,935		1,690		21,159
Balance at September 30, 2021	$	(317,477)	(262,697)		—		(580,174)

1 Reclassifications before taxes of $16,282 are included in the computation of net periodic benefit expense for the nine-month period ended September 30, 2021.  See Note H for additional information.  Related income taxes of $3,347 are included in Income tax expense (benefit) for the nine-month period ended September 30, 2021.

2 Reclassifications before taxes of $2,140 are included in Interest expense, net, for the nine-month period ended September 30, 2021.  Related income taxes of $450 are included in Income tax expense (benefit) for the nine-month period ended September 30, 2021. See Note L for additional information.

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Business Segments (Tables)

9 Months Ended

Sep. 30, 2021

Segment Reporting [Abstract]

Segment Information

Information about business segments and geographic operations is reported in the following table.  For geographic purposes, revenues are attributed to the country in which the sale occurs.  Corporate, including interest income, other gains and losses (including foreign exchange gains/losses and realized and unrealized gains/losses on crude oil contracts), interest expense and unallocated overhead, is shown in the tables to reconcile the business segments to consolidated totals.

	Total Assets at September 30, 2021		Three Months Ended September 30, 2021		Three Months Ended September 30, 2020
(Millions of dollars)			External Revenues	Income (Loss)	External Revenues	Income (Loss)
Exploration and production ¹
United States	$	6,586.3	565.2	168.1	330.8	(172.6)
Canada	2,241.2		124.6	73.9	96.3	(8.6)
Other	264.6		—	(5.2)	—	(11.7)
Total exploration and production	9,092.1		689.8	236.8	427.1	(192.9)
Corporate	1,237.8		(59.1)	(98.8)	(5.2)	(72.9)
Continuing operations	10,329.9		630.7	138.0	421.9	(265.8)
Discontinued operations, net of tax	1.0		—	(0.7)	—	(0.8)
Total	$	10,330.9	630.7	137.3	421.9	(266.6)
			Nine Months Ended September 30, 2021		Nine Months Ended September 30, 2020
(Millions of dollars)			External Revenues	Income (Loss)	External Revenues	Income (Loss)
Exploration and production ¹
United States			1,704.4	481.8	1,070.6	(1,011.7)
Canada			349.2	(37.7)	245.2	(35.0)
Other			—	(22.5)	1.8	(73.0)
Total exploration and production			2,053.6	421.6	1,317.6	(1,119.7)
Corporate			(493.3)	(577.6)	319.5	26.9
Continuing operations			1,560.3	(156.0)	1,637.1	(1,092.8)
Discontinued operations, net of tax			—	(0.6)	—	(6.9)
Total			1,560.3	(156.6)	1,637.1	(1,099.7)

1 Additional details about results of oil and natural gas operations are presented in the table on pages 25 and 26.

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Nature of Business and Interim Financial Statements - Narrative (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($) entity
Organization, Consolidation and Presentation of Financial Statements [Abstract]
Ownership percentage in variable interest entity	0.50%
Number of variable interest entities (in entities) | entity	2
Maximum exposure to loss | $	$ 3.4

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Revenue from Contracts with Customers (Narrative) (Details) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021 USD ($)	Sep. 30, 2020 USD ($)	Sep. 30, 2021 USD ($) revenueStream segment	Sep. 30, 2020 USD ($)	Dec. 31, 2020 USD ($)
Revenue from Contract with Customer [Abstract]
Number of geographic segments (in segments) | segment			2
Number of revenue streams (in revenue streams) | revenueStream			3
Revenue from sales to customers	$ 687,549	$ 425,324	$ 2,038,905	$ 1,311,627
Receivables from contracts with customers	$ 144,000		$ 144,000		$ 135,200

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Revenue from Contracts with Customers (Disaggregation of Revenue) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 687,549	$ 425,324	$ 2,038,905	$ 1,311,627
(Loss) gain on derivative instruments	(59,164)	(5,290)	(499,794)	319,502
Gain on sale of assets and other income	2,315	1,831	21,217	6,006
Total revenues and other income	630,700	421,865	1,560,328	1,637,135
Net crude oil and condensate revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	556,620	354,947	1,704,226	1,110,365
Net natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	31,903	14,311	77,074	35,490
Net natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	99,026	56,066	257,605	165,772
United States | Net crude oil and condensate revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	167,010	86,498	464,767	272,284
United States | Net natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	16,356	6,766	33,480	16,145
United States | Net natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	11,127	4,529	24,442	14,177
United States Offshore | Net crude oil and condensate revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	340,001	216,918	1,079,418	714,143
United States Offshore | Net natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	11,046	4,765	31,866	13,255
United States Offshore | Net natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	17,444	9,827	56,855	35,487
Canada     | Net crude oil and condensate revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	29,110	32,358	89,708	67,268
Canada     | Net natural gas liquids revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	4,501	2,780	11,728	6,090
Canada     | Net natural gas revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	70,455	41,710	176,308	116,108
Canada Offshore | Net crude oil and condensate revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	20,499	19,173	70,333	54,864
Other | Net crude oil and condensate revenue
Disaggregation of Revenue [Line Items]
Total revenue from contracts with customers	$ 0	$ 0	$ 0	$ 1,806

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Revenue from Contracts with Customers (Current Long-Term Contracts Outstanding) (Details) Boe in Thousands	Sep. 30, 2021 Boe MMcf
Q4 2021 | United States
Disaggregation of Revenue [Line Items]
Revenue, remaining performance obligation, oil quantity per day | Boe	17
Q4 2021 | Canada | Contracts to sell natural gas at USD index pricing
Disaggregation of Revenue [Line Items]
Remaining performance obligation	10
Q4 2022 | Canada | Contracts to sell natural gas at USD index pricing
Disaggregation of Revenue [Line Items]
Remaining performance obligation	8
Q4 2022 | Canada | Contracts to sell natural gas at CAD fixed prices
Disaggregation of Revenue [Line Items]
Remaining performance obligation	5
Q4 2022 | Canada | Contracts to sell natural gas at USD index pricing
Disaggregation of Revenue [Line Items]
Remaining performance obligation	20
Q4 2023 | Canada | Contracts to sell natural gas at USD index pricing
Disaggregation of Revenue [Line Items]
Remaining performance obligation	25
Q4 2023 | Canada | Contracts to sell natural gas at CAD fixed prices
Disaggregation of Revenue [Line Items]
Remaining performance obligation	38
Q4 2024 | Canada | Contracts to sell natural gas at USD index pricing
Disaggregation of Revenue [Line Items]
Remaining performance obligation	31
Q4 2024 | Canada | Contracts to sell natural gas at USD index pricing
Disaggregation of Revenue [Line Items]
Remaining performance obligation	15
Q4 2024 | Canada | Contracts to sell natural gas at CAD fixed prices
Disaggregation of Revenue [Line Items]
Remaining performance obligation	100
Q4 2024 | Canada | Contracts to sell natural gas at CAD fixed prices
Disaggregation of Revenue [Line Items]
Remaining performance obligation	34
Q4 2026 | Canada | Contracts to sell natural gas at USD index pricing
Disaggregation of Revenue [Line Items]
Remaining performance obligation	49

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Property, Plant and Equipment (Net Changes in Capitalized Exploratory Well Costs) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Movement in Property, Plant and Equipment [Roll Forward]
Beginning balance	$ 181,616	$ 217,326
Additions pending the determination of proved reserves	5,007	9,941
Capitalized exploratory well costs charged to expense	0	(39,408)
Ending balance	$ 186,623	$ 187,859

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Property, Plant and Equipment (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended		12 Months Ended
	Mar. 31, 2021	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020	Dec. 31, 2019
Property, Plant and Equipment [Line Items]
Well costs		$ 186,623	$ 187,859	$ 181,616	$ 217,326
Exploratory well costs capitalized more than one year		183,300
Impairment of oil and gas Properties	$ 171,300	171,296	1,206,284	$ 1,206,300
Proceeds from sale of oil and gas property and equipment	$ 267,700
Vietnam
Property, Plant and Equipment [Line Items]
Exploratory well costs capitalized more than one year		92,300
United States
Property, Plant and Equipment [Line Items]
Exploratory well costs capitalized more than one year		45,000
Impairment of oil and gas Properties		0	1,152,515
Brunei
Property, Plant and Equipment [Line Items]
Exploratory well costs capitalized more than one year		25,900
MEXICO
Property, Plant and Equipment [Line Items]
Exploratory well costs capitalized more than one year		15,300
Canada
Property, Plant and Equipment [Line Items]
Exploratory well costs capitalized more than one year		4,800
Impairment of oil and gas Properties		$ 171,296	$ 0

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Property, Plant and Equipment (Aging of Capitalized Exploratory Well Costs) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2021 USD ($) well project	Sep. 30, 2020 USD ($) well project	Dec. 31, 2020 USD ($)	Dec. 31, 2019 USD ($)
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 186,623	$ 187,859	$ 181,616	$ 217,326
No. of Wells (in wells) | well	13	12
No. of Projects (in projects) | project	7	5
Zero to one year
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 3,297	$ 8,000
No. of Wells (in wells) | well	2	1
No. of Projects (in projects) | project	2	0
One to two years
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 0	$ 54,334
No. of Wells (in wells) | well	0	5
No. of Projects (in projects) | project	0	5
Two to three years
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 53,078	$ 0
No. of Wells (in wells) | well	5	0
No. of Projects (in projects) | project	5	0
Three years or more
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 130,248	$ 125,525
No. of Wells (in wells) | well	6	6
No. of Projects (in projects) | project	0	0

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Property, Plant and Equipment (Schedule of Recognized Impairments) (Details) - USD ($) $ in Thousands	3 Months Ended	9 Months Ended		12 Months Ended
	Mar. 31, 2021	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Property, Plant and Equipment [Line Items]
Impairment of oil and gas Properties	$ 171,300	$ 171,296	$ 1,206,284	$ 1,206,300
Corporate
Property, Plant and Equipment [Line Items]
Impairment of oil and gas Properties		0	14,060
United States
Property, Plant and Equipment [Line Items]
Impairment of oil and gas Properties		0	1,152,515
Canada
Property, Plant and Equipment [Line Items]
Impairment of oil and gas Properties		171,296	0
Other Foreign
Property, Plant and Equipment [Line Items]
Impairment of oil and gas Properties		$ 0	$ 39,709

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Assets Held for Sale and Discontinued Operations (Results of Operations Associated with Discontinued Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
(Loss) income from discontinued operations	$ (706)	$ (778)	$ (600)	$ (6,907)
Discontinued Operation | U.K. and U.S. Refining And Marketing Operations
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Revenues	144	0	801	4,074
Other costs and expenses (benefits)	850	778	1,401	10,981
(Loss) income before taxes	(706)	(778)	(600)	(6,907)
Income tax expense	0	0	0	0
(Loss) income from discontinued operations	$ (706)	$ (778)	$ (600)	$ (6,907)
Discontinued operations, held-for-sale or disposed of by sale | King's Quay Floating Production System
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Total current assets associated with assets held for sale					$ 250,100

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Assets Held for Sale and Discontinued Operations (Major Categories of Assets and Liabilities Reflected as Held for Sale) (Details) - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Current liabilities
Total current liabilities associated with assets held for sale	$ 0	$ 14,372
Discontinued operations, held-for-sale or disposed of by sale | Brunei Exploration And Production Operations
Current assets
Cash	0	10,185
Inventories	0	406
Property, plant, and equipment, net	40,987	307,704
Deferred income taxes and other assets	0	9,441
Total current assets associated with assets held for sale	40,987	327,736
Current liabilities
Accounts payable	0	5,306
Other accrued liabilities	0	45
Current maturities of long-term debt (finance lease)	0	737
Taxes payable	0	1,510
Long-term debt (finance lease)	0	6,513
Asset retirement obligation	0	261
Total current liabilities associated with assets held for sale	$ 0	$ 14,372

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Financing Arrangements and Debt (Narrative) (Details) - USD ($)	1 Months Ended	3 Months Ended	9 Months Ended
	Aug. 31, 2021	Mar. 31, 2021	Sep. 30, 2021	Sep. 30, 2020	Nov. 04, 2021	Aug. 05, 2021
Line of Credit Facility [Line Items]
Early redemption of debt cost			$ 36,756,000	$ 0
6.375% notes due July 2028
Line of Credit Facility [Line Items]
Debt instrument, face amount		$ 550,000,000
Stated interest rate		6.375%
Transaction costs		$ 8,100,000
4.00% notes due June 2022
Line of Credit Facility [Line Items]
Stated interest rate		4.00%
Repayments of debt		$ 259,300,000
4.95% notes due December 2022
Line of Credit Facility [Line Items]
Stated interest rate		4.95%
Repayments of debt		$ 317,100,000
3.70% notes due 2022
Line of Credit Facility [Line Items]
Stated interest rate		3.70%
4.00%, and 4.95% Notes due 2022
Line of Credit Facility [Line Items]
Cost of debt extinguishment			36,900,000
Early redemption of debt cost			34,200,000
6.875% notes due 2024
Line of Credit Facility [Line Items]
Stated interest rate						6.875%
Loss on extinguishment of debt	$ (3,500,000)
Early redemption of debt cost	$ 2,600,000
Partial redemption						$ 150,000,000
6.875% notes due 2024 | Subsequent Event
Line of Credit Facility [Line Items]
Stated interest rate					6.875%
Partial redemption					$ 150,000,000
2018 Revolving Credit Facility
Line of Credit Facility [Line Items]
Amount outstanding			$ 0
Interest rate			1.78%
2018 Revolving Credit Facility | Letter of Credit
Line of Credit Facility [Line Items]
Credit facility maximum borrowing capacity			$ 1,600,000,000
Amount outstanding			$ 31,400,000

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Other Financial Information (Noncash Operating Working Capital (Increase) Decrease) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Mar. 31, 2021	Sep. 30, 2021	Sep. 30, 2020
Net (increase) decrease in operating working capital, excluding cash and cash equivalents:
Decrease in accounts receivable			$ 75,100	$ 251,706
Decrease in inventories			9,718	4,747
(Increase) in prepaid expenses			(6,682)	(17,400)
Increase (decrease) in accounts payable and accrued liabilities			40,687	(264,078)
(Decrease) in income taxes payable			(1,493)	(1,236)
Net (increase) decrease in noncash operating working capital			117,330	(26,261)
Supplementary disclosures:
Cash income taxes paid, net of refunds			1,685	(12,559)
Interest paid, net of amounts capitalized of $11.6 million in 2021 and $5.9 million in 2020			127,793	139,651
Capitalized interest paid			11,600	5,900
Non-cash investing activities:
Asset retirement costs capitalized			36,300	6,342
Decrease in capital expenditure accrual			$ 31,301	$ 74,742
Impairment of asset retirement obligation		$ 74,400
Other operating income	$ 71,800
Asset life extension period			10 years

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Employee and Retiree Benefit Plans (Components of Net Periodic Benefit Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Pension Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 1,770	$ 1,664	$ 5,306	$ 5,996
Interest cost	4,258	4,827	12,844	16,381
Expected return on plan assets	(6,038)	(5,773)	(18,326)	(18,414)
Amortization of prior service cost (credit)	155	149	467	515
Recognized actuarial loss	5,269	5,690	15,829	14,223
Net periodic benefit expense	5,414	6,557	16,120	18,701
Other - curtailment			0	586
Other - special termination benefits			0	8,435
Net periodic benefit expense			16,120	27,722
Other Postretirement Benefits
Defined Benefit Plan Disclosure [Line Items]
Service cost	328	342	981	1,235
Interest cost	521	612	1,563	2,200
Expected return on plan assets	0	0	0	0
Amortization of prior service cost (credit)	0	0	0	0
Recognized actuarial loss	(8)	(24)	(23)	(24)
Net periodic benefit expense	$ 841	$ 930	2,521	3,411
Other - curtailment			0	(1,825)
Other - special termination benefits			0	0
Net periodic benefit expense			$ 2,521	$ 1,586

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Employee and Retiree Benefit Plans (Narrative) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2021 USD ($)
Retirement Benefits [Abstract]
Contributions to benefit plans	$ 31.0
Expected benefit plan contributions to be made during the year	$ 10.9

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Incentive Plans (Summary of Awards Granted) (Details)	9 Months Ended
	Sep. 30, 2021 USD ($) $ / shares shares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Threshold of executive compensation not eligible for U.S. income tax deduction | $	$ 1,000,000
2020 Long-Term Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Maximum number of shares available for issuance (in shares)	5,000,000,000,000
Performance-Based RSUs | 2020 Long-Term Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in period (in shares)	1,156,800
Fair value per share at grant date (in USD per share) | $ / shares	$ 16.03
Award vesting period	3 years
Time-Based RSUs | 2020 Long-Term Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in period (in shares)	385,600
Fair value per share at grant date (in USD per share) | $ / shares	$ 12.30
Award vesting period	3 years
Time-Based RSUs | 2018 NED Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in period (in shares)	182,652
Fair value per share at grant date (in USD per share) | $ / shares	$ 13.14
Time-Based RSUs | 2021 NED Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in period (in shares)	5,655
Fair value per share at grant date (in USD per share) | $ / shares	$ 23.58
Cash Settled RSUs | 2020 Long-Term Plan
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Grants in period (in shares)	1,022,700
Fair value per share at grant date (in USD per share) | $ / shares	$ 12.30
Award vesting period	3 years

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Incentive Plans (Share-Based Plans, Amounts Recognized) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020
Share-based Payment Arrangement [Abstract]
Compensation charged against income before tax benefit	$ 29,145	$ 17,542
Related income tax benefit recognized in income	$ 4,120	$ 2,278

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Earnings Per Share (Weighted-Average Shares Outstanding for Computation of Basic and Diluted Income per Common Share) (Details) - USD ($)	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Earnings Per Share [Abstract]
Basic method (in shares)	154,439,313	153,596,109	154,239,440	153,479,654
Dilutive stock options and restricted stock units (in shares)	1,492,949	0	0	0
Diluted method (in shares)	155,932,262	153,596,109	154,239,440	153,479,654
Unvested stock awards	$ 0	$ 0	$ 0	$ 0

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Earnings Per Share (Antidilutive Securities Not Included in Computation of Diluted EPS) (Details) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Earnings Per Share [Abstract]
Antidilutive stock options excluded from diluted shares (in shares)	1,316,222	2,111,068	1,502,758	2,305,973
Weighted average price of these options (in USD per share)	$ 34.42	$ 38.54	$ 34.97	$ 40.15

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Income Taxes (Effective Income Tax Rates) (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Income Tax Disclosure [Abstract]
Effective income tax rate	21.10%	19.10%	28.60%	18.60%

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Financial Instruments and Risk Management (Narrative) (Details) barrels_per_day in Thousands, $ in Millions	9 Months Ended	12 Months Ended	24 Months Ended
	Sep. 30, 2021 USD ($) barrels_per_day contract OffsettingPosition $ / bbl	Dec. 31, 2021 barrels_per_day $ / bbl	Dec. 31, 2019 Acquisition	Dec. 31, 2020 OffsettingPosition	Sep. 30, 2020 contract
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Amount of loss reclassified to interest expense | $	$ (2.1)
Number of foreign currency derivatives (in contracts) | contract	0				0
Number of businesses acquired (in acquisitions) | Acquisition			2
Number of offsetting positions (in offsetting positions) | OffsettingPosition	0			0
Commodity derivative contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Daily production commitment (barrels per day) | barrels_per_day	45
Average forward price (in dollars per barrel) | $ / bbl	42.77
Forecast | Commodity derivative contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Daily production commitment (barrels per day) | barrels_per_day		20
Average forward price (in dollars per barrel) | $ / bbl		44.88

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Financial Instruments and Hedging Activities - Crude Oil Derivative Contracts (Details) barrels_per_day in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2021 barrels_per_day $ / bbl	Dec. 31, 2021 barrels_per_day $ / bbl
Commodity derivative contracts
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Oil and Gas Delivery Commitments and Contracts, Daily Production | barrels_per_day	45
Average forward price (in dollars per barrel)	42.77
Commodity derivative contracts | Forecast
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Oil and Gas Delivery Commitments and Contracts, Daily Production | barrels_per_day		20
Average forward price (in dollars per barrel)		44.88
Commodity collars
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Oil and Gas Delivery Commitments and Contracts, Daily Production | barrels_per_day	0
Commodity collars | Minimum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Average forward price (in dollars per barrel)	0
Commodity collars | Maximum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Average forward price (in dollars per barrel)	0
Commodity collars | Forecast
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Oil and Gas Delivery Commitments and Contracts, Daily Production | barrels_per_day		16
Commodity collars | Forecast | Minimum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Average forward price (in dollars per barrel)		60.38
Commodity collars | Forecast | Maximum
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Average forward price (in dollars per barrel)		71.83

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Financial Instruments and Risk Management (Fair Value of Derivative Instruments Not Designated as Hedging Instruments) (Details) - Not Designated as Hedging Instrument - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Commodity derivative contracts | Obligations
Derivatives, Fair Value [Line Items]
Derivative liability	$ (41,645)	$ (12,833)
Commodity derivative contracts | Accounts receivable
Derivatives, Fair Value [Line Items]
Derivative asset	0	13,050
Commodity derivative contracts | Accounts payable
Derivatives, Fair Value [Line Items]
Derivative liability	(312,448)	(89,842)
Commodity collars | Accounts receivable
Derivatives, Fair Value [Line Items]
Derivative asset	0	0
Commodity collars | Accounts payable
Derivatives, Fair Value [Line Items]
Derivative liability	$ (15,929)	$ 0

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Financial Instruments and Risk Management (Recognized Gains and Losses for Derivative Instruments Not Designated as Hedging Instruments) (Details) - Not Designated as Hedging Instrument - (Loss) gain on derivative instruments - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
Commodity derivative contracts
Derivative Instruments, Gain (Loss) [Line Items]
(Loss) gain on derivative instruments	$ (43,235)	$ (5,290)	$ (483,865)	$ 319,502
Commodity collars
Derivative Instruments, Gain (Loss) [Line Items]
(Loss) gain on derivative instruments	$ (15,929)	$ 0	$ (15,929)	$ 0

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Financial Instruments and Risk Management (Carrying Value of Assets and Liabilities Recorded at Fair Value on Recurring Basis) (Details) - Fair Value - USD ($) $ in Thousands	Sep. 30, 2021	Dec. 31, 2020
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	$ 0	$ 13,050
Liabilities	625,317	250,667
Commodity swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	13,050
Commodity swaps	354,093	102,675
Commodity collars
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nonqualified employee savings plan	15,929	0
Nonqualified employee savings plan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nonqualified employee savings plan	17,180	14,988
Contingent consideration
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration	238,115	133,004
Level 1
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	17,180	14,988
Level 1 | Commodity swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Commodity swaps	0	0
Level 1 | Commodity collars
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nonqualified employee savings plan	0	0
Level 1 | Nonqualified employee savings plan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nonqualified employee savings plan	17,180	14,988
Level 1 | Contingent consideration
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration	0	0
Level 2
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	13,050
Liabilities	370,022	102,675
Level 2 | Commodity swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	13,050
Commodity swaps	354,093	102,675
Level 2 | Commodity collars
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nonqualified employee savings plan	15,929	0
Level 2 | Nonqualified employee savings plan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nonqualified employee savings plan	0	0
Level 2 | Contingent consideration
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration	0	0
Level 3
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Liabilities	238,115	133,004
Level 3 | Commodity swaps
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets	0	0
Commodity swaps	0	0
Level 3 | Commodity collars
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nonqualified employee savings plan	0	0
Level 3 | Nonqualified employee savings plan
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Nonqualified employee savings plan	0	0
Level 3 | Contingent consideration
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Contingent consideration	$ 238,115	$ 133,004

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Accumulated Other Comprehensive Loss (Components of Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period			$ 4,394,147
Components of other comprehensive income (loss):
Before reclassifications to income and retained earnings			6,534
Reclassifications to income			14,625
Other comprehensive (loss) income	$ (26,655)	$ 32,346	21,159	$ (83,834)
Balance at end of period	4,113,947	$ 4,514,045	4,113,947	$ 4,514,045
Reclassifications before taxes, included in net periodic benefit expense			2,140
Reclassifications, income tax expense			450
Foreign Currency Translation Gains (Losses)
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period			(324,011)
Components of other comprehensive income (loss):
Before reclassifications to income and retained earnings			6,534
Reclassifications to income			0
Other comprehensive (loss) income			6,534
Balance at end of period	(317,477)		(317,477)
Retirement and Postretirement Benefit Plan Adjustments
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period			(275,632)
Components of other comprehensive income (loss):
Before reclassifications to income and retained earnings			0
Reclassifications to income			12,935
Other comprehensive (loss) income			12,935
Balance at end of period	(262,697)		(262,697)
Reclassifications before taxes, included in net periodic benefit expense			16,282
Deferred Loss on Interest Rate Derivative Hedges
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period			(1,690)
Components of other comprehensive income (loss):
Before reclassifications to income and retained earnings			0
Reclassifications to income			1,690
Other comprehensive (loss) income			1,690
Balance at end of period	0		0
Reclassifications, income tax expense			3,347
Total
AOCI Including Portion Attributable to Noncontrolling Interest, Net of Tax [Roll Forward]
Balance at beginning of period			(601,333)
Components of other comprehensive income (loss):
Balance at end of period	$ (580,174)		$ (580,174)

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Environmental and Other Contingencies (Details) $ in Millions	Sep. 30, 2021 USD ($)
Environmental Remediation Obligations [Abstract]
Threshold for disclosure of monetary sanctions, environmental proceedings	$ 1.0

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Business Segments (Segment Information) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2021	Sep. 30, 2020	Sep. 30, 2021	Sep. 30, 2020	Dec. 31, 2020
Segment Reporting Information [Line Items]
Total Assets	$ 10,330,856		$ 10,330,856		$ 10,620,852
External Revenues	630,700	$ 421,865	1,560,328	$ 1,637,135
Income (Loss)	137,309	(266,608)	(156,555)	(1,099,710)
Continuing operations
Segment Reporting Information [Line Items]
Total Assets	10,329,900		10,329,900
External Revenues	630,700	421,900	1,560,300	1,637,100
Income (Loss)	138,000	(265,800)	(156,000)	(1,092,800)
Discontinued operations, net of tax
Segment Reporting Information [Line Items]
Total Assets	1,000		1,000
External Revenues	0	0	0	0
Income (Loss)	(700)	(800)	(600)	(6,900)
Corporate
Segment Reporting Information [Line Items]
Total Assets	1,237,800		1,237,800
External Revenues	(59,100)	(5,200)	(493,300)	319,500
Income (Loss)	(98,800)	(72,900)	(577,600)	26,900
Exploration and production | Operating Segments
Segment Reporting Information [Line Items]
Total Assets	9,092,100		9,092,100
External Revenues	689,800	427,100	2,053,600	1,317,600
Income (Loss)	236,800	(192,900)	421,600	(1,119,700)
Exploration and production | Operating Segments | United States
Segment Reporting Information [Line Items]
Total Assets	6,586,300		6,586,300
External Revenues	565,200	330,800	1,704,400	1,070,600
Income (Loss)	168,100	(172,600)	481,800	(1,011,700)
Exploration and production | Operating Segments | Canada
Segment Reporting Information [Line Items]
Total Assets	2,241,200		2,241,200
External Revenues	124,600	96,300	349,200	245,200
Income (Loss)	73,900	(8,600)	(37,700)	(35,000)
Exploration and production | Operating Segments | Other
Segment Reporting Information [Line Items]
Total Assets	264,600		264,600
External Revenues	0	0	0	1,800
Income (Loss)	$ (5,200)	$ (11,700)	$ (22,500)	$ (73,000)