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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 March 31, 2024
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
murphyoilcorplogo.jpg
MURPHY OIL CORPORATION
(Exact name of registrant as specified in its charter)
Delaware71-0361522
(State or other jurisdiction of incorporation or organization)(I.R.S. Employer Identification Number)
9805 Katy Fwy, Suite G-20077024
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 classTrading SymbolName of each exchange on which registered
Common Stock, $1.00 Par ValueMURNew 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. ☐ 
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 April 30, 2024 was 152,576,275.


MURPHY OIL CORPORATION
TABLE OF CONTENTS
Page
              Operations
1
PART I – FINANCIAL INFORMATION
ITEM 1.  FINANCIAL STATEMENTS
MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED BALANCE SHEETS
(UNAUDITED)

(Thousands of dollars, except share amounts)March 31,
2024		December 31,
2023
ASSETS
Current assets
Cash and cash equivalents$323,430 $317,074 
Accounts receivable, net
356,863 343,992 
Inventories49,662 54,454 
Prepaid expenses30,934 36,674 
Total current assets760,889 752,194 
Property, plant and equipment, at cost less accumulated depreciation, depletion and amortization of $13,309,133 in 2024 and $13,135,385 in 2023
8,188,903 8,225,197 
Operating lease assets681,766 745,185 
Deferred income taxes434 435 
Deferred charges and other assets36,668 43,686 
Total assets$9,668,660 $9,766,697 
LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt, finance lease$730 $723 
Accounts payable485,892 446,891 
Income taxes payable24,710 21,007 
Other taxes payable26,096 29,339 
Operating lease liabilities179,471 207,840 
Other accrued liabilities101,253 140,745 
Total current liabilities818,152 846,545 
Long-term debt, including finance lease obligation1,328,669 1,328,352 
Asset retirement obligations916,815 904,051 
Deferred credits and other liabilities303,951 309,605 
Non-current operating lease liabilities516,520 551,845 
Deferred income taxes292,048 276,646 
Total liabilities$4,176,155 $4,217,044 
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 2024 and 195,100,628 shares in 2023
195,101 195,101 
Capital in excess of par value816,815 880,297 
Retained earnings6,590,308 6,546,079 
Accumulated other comprehensive loss(555,735)(521,117)
Treasury stock(1,742,498)(1,737,566)
Murphy Shareholders' Equity5,303,991 5,362,794 
Noncontrolling interest188,514 186,859 
Total equity5,492,505 5,549,653 
Total liabilities and equity$9,668,660 $9,766,697 

See Notes to Consolidated Financial Statements, page 7.
2
MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED STATEMENTS OF OPERATIONS
(UNAUDITED)
Three Months Ended
March 31,
(Thousands of dollars, except per share amounts)20242023
Revenues and other income
Revenue from production$794,603 $796,231 
Sales of purchased natural gas245 43,737 
Total revenue from sales to customers794,848 839,968 
Gain on sale of assets and other income1,564 1,748 
Total revenues and other income796,412 841,716 
Costs and expenses
Lease operating expenses234,264 199,984 
Severance and ad valorem taxes10,086 11,440 
Transportation, gathering and processing56,553 53,922 
Costs of purchased natural gas160 32,269 
Exploration expenses, including undeveloped lease amortization44,429 10,182 
Selling and general expenses31,161 18,308 
Depreciation, depletion and amortization211,134 195,670 
Accretion of asset retirement obligations12,774 11,157 
Other operating expense7,266 11,988 
Impairment of assets34,528 – 
Total costs and expenses642,355 544,920 
Operating income from continuing operations154,057 296,796 
Other loss
Other income (loss)11,551 (73)
Interest expense, net(20,021)(28,855)
Total other loss(8,470)(28,928)
Income from continuing operations before income taxes145,587 267,868 
Income tax expense30,057 53,833 
Income from continuing operations115,530 214,035 
(Loss) gain from discontinued operations, net of income taxes(872)279 
Net income including noncontrolling interest114,658 214,314 
Less: Net income attributable to noncontrolling interest24,656 22,670 
NET INCOME ATTRIBUTABLE TO MURPHY$90,002 $191,644 
INCOME (LOSS) PER COMMON SHARE – BASIC
Continuing operations$0.60 $1.23 
Discontinued operations(0.01)– 
Net income$0.59 $1.23 
INCOME (LOSS) PER COMMON SHARE – DILUTED
Continuing operations$0.60 $1.22 
Discontinued operations(0.01)– 
Net income$0.59 $1.22 
Cash dividends per common share$0.300 $0.275 
Average common shares outstanding (thousands)
Basic152,664 155,857 
Diluted153,817 157,389 
See Notes to Consolidated Financial Statements, page 7.
3
MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)
(UNAUDITED)
Three Months Ended
March 31,
(Thousands of dollars)20242023
Net income including noncontrolling interest$114,658 $214,314 
Other comprehensive (loss) income, net of tax
Net (loss) gain from foreign currency translation
(35,528)3,669 
Retirement and postretirement benefit plans910 1,098 
Other comprehensive (loss) income (34,618)4,767 
Comprehensive income including noncontrolling interest$80,040 $219,081 
Less: Comprehensive income attributable to noncontrolling interest24,656 22,670 
COMPREHENSIVE INCOME ATTRIBUTABLE TO MURPHY$55,384 $196,411 

See Notes to Consolidated Financial Statements, page 7.
4
MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED STATEMENTS OF CASH FLOWS
(UNAUDITED)
Three Months Ended
March 31,
(Thousands of dollars)20242023
Operating Activities
Net income including noncontrolling interest$114,658 $214,314 
Adjustments to reconcile net income to net cash provided by continuing operations activities
Depreciation, depletion and amortization211,134 195,670 
Impairment of assets34,528 – 
Unsuccessful exploration well costs and previously suspended exploration costs 32,437 851 
Deferred income tax expense19,478 49,042 
Accretion of asset retirement obligations12,774 11,157 
Long-term non-cash compensation9,851 8,536 
Amortization of undeveloped leases2,793 2,653 
Loss (income) from discontinued operations
872 (279)
Contingent consideration payment– (123,965)
Mark to market loss on contingent consideration– 3,938 
Other operating activities, net(15,381)(7,110)
Net increase in noncash working capital(24,353)(75,031)
Net cash provided by continuing operations activities398,791 279,776 
Investing Activities
Property additions and dry hole costs(249,085)(345,319)
Net cash required by investing activities(249,085)(345,319)
Financing Activities
Borrowings on revolving credit facility 100,000 100,000 
Repayment of revolving credit facility (100,000)(100,000)
Repurchase of common stock(50,000)– 
Cash dividends paid(45,773)(42,925)
Withholding tax on stock-based incentive awards(25,270)(14,217)
Distributions to noncontrolling interest(23,001)(9,679)
Finance lease obligation payments(164)(139)
Contingent consideration payment– (47,678)
Issue costs of debt facility– (17)
Net cash required by financing activities(144,208)(114,655)
Effect of exchange rate changes on cash and cash equivalents858 618 
Net increase (decrease) in cash and cash equivalents
6,356 (179,580)
Cash and cash equivalents at beginning of period317,074 491,963 
Cash and cash equivalents at end of period$323,430 $312,383 

See Notes to Consolidated Financial Statements, page 7.
5
MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
CONSOLIDATED STATEMENTS OF STOCKHOLDERS’ EQUITY
(UNAUDITED)
Three Months Ended
March 31,
(Thousands of dollars except number of shares)20242023
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 March 31, 2024 and 195,100,628 shares at March 31, 2023
Balance at beginning and end of period195,101 195,101 
Capital in Excess of Par Value
Balance at beginning of period880,297 893,578 
Restricted stock transactions and other(70,387)(40,094)
Share-based compensation6,905 3,516 
Balance at end of period816,815 857,000 
Retained Earnings
Balance at beginning of period6,546,079 6,055,498 
Net income attributable to Murphy90,002 191,644 
Cash dividends paid(45,773)(42,925)
Balance at end of period6,590,308 6,204,217 
Accumulated Other Comprehensive Loss
Balance at beginning of period(521,117)(534,686)
Foreign currency translation (loss) gain, net of income taxes(35,528)3,669 
Retirement and postretirement benefit plans, net of income taxes910 1,098 
Balance at end of period(555,735)(529,919)
Treasury Stock
Balance at beginning of period(1,737,566)(1,614,717)
Repurchase of common stock(50,049)– 
Awarded restricted stock, net of forfeitures45,117 25,876 
Balance at end of period – 42,524,472 shares of common stock in 2024 and 39,002,553 shares of common stock in 2023, at cost
(1,742,498)(1,588,841)
Murphy Shareholders’ Equity5,303,991 5,137,558 
Noncontrolling Interest
Balance at beginning of period186,859 154,119 
Net income attributable to noncontrolling interest24,656 22,670 
Distributions to noncontrolling interest owners(23,001)(9,679)
Balance at end of period188,514 167,110 
Total Equity$5,492,505 $5,304,668 

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 (the Company or Murphy) on pages 2 through 6 of this Form 10-Q report.

Note A – Basis of Presentation
The unaudited financial statements presented herein, in the opinion of Murphy’s management, include all accruals necessary to present fairly the Company’s financial position as at March 31, 2024 and December 31, 2023, and the results of operations, statements of operations, cash flows and changes in stockholders’ equity for the interim periods ended March 31, 2024 and 2023, in conformity with U.S generally accepted accounting principles (GAAP). In preparing the financial statements of the Company in conformity with GAAP, management has made a number of estimates and assumptions that affect the reporting of amounts 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 2023 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 period ended March 31, 2024 are not necessarily indicative of future results.

Note B – New Accounting Principles and Recent Accounting Pronouncements
Accounting Principles Adopted
None affecting the Company.
Recent Accounting Pronouncements
Income Tax Disclosures. In December 2023 the Financial Accounting Standards Board (FASB) issued Accounting Standards Update (ASU) 2023-09 Income Taxes (Topic 740): Improvements to Income Tax Disclosures. The standard becomes effective for annual periods beginning after December 15, 2024. The update requires financial statements to include consistent categories and greater disaggregation of information in the rate reconciliation, as well as income taxes paid disaggregated by jurisdiction. Murphy is currently evaluating the impact of adopting this standard.

Reportable Segment Disclosures. In November 2023 the FASB issued ASU 2023-07 Segment Reporting (Topic 280): Improvements to Reportable Segment Disclosures. The standard becomes effective for fiscal years beginning after December 15, 2023, and interim periods within fiscal years beginning after December 15, 2024. The standard requires additional disclosures about operating segments, including segment expense information provided to the chief operating decision maker, and extends certain disclosure requirements to interim periods. The standard does not affect our determination of significant segments. Murphy is currently evaluating the impact of adopting this standard.

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 United States (U.S.) and Canada. Additionally, revenue from sales to customers is generated from three primary revenue streams: crude oil and condensate, natural gas liquids (NGL), 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 (NCI) in MP Gulf of Mexico, LLC (MP GOM) as prescribed by GAAP.
7
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Note C - Revenue from Contracts with Customers (Continued)
U.S. - In the U.S., 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. The Company also purchases natural gas in Canada to meet certain sales commitments.
Disaggregation of Revenue
The Company reviews performance based on two key geographical segments and between onshore and offshore sources of revenue within these geographies.
The Company’s revenues and other income for the three-month periods ended March 31, 2024 and 2023 were as follows.
Three Months Ended
March 31,
(Thousands of dollars)20242023
Net crude oil and condensate revenue
United States
Onshore$142,543 $130,081 
                     
Offshore 1
480,439 500,310 
Canada    
Onshore13,873 21,952 
Offshore54,775 16,130 
Other
(98)3,644 
Total crude oil and condensate revenue691,532 672,117 
Net natural gas liquids revenue
United States
Onshore7,836 8,270 
 
Offshore 1
10,374 14,629 
Canada
Onshore1,437 3,463 
Total natural gas liquids revenue19,647 26,362 
Net natural gas revenue
United States
Onshore4,276 5,450 
Offshore 1
12,889 22,132 
Canada
Onshore66,259 70,170 
Total natural gas revenue83,424 97,752 
Revenue from production794,603 796,231 
Sales of purchased natural gas
Canada
Onshore245 43,737 
Total sales of purchased natural gas245 43,737 
Total revenue from sales to customers794,848 839,968 
Gain on sale of assets and other income1,564 1,748 
Total revenues and other income$796,412 $841,716 
1 Includes revenue attributable to noncontrolling interest in MP GOM.
Contract Balances and Asset Recognition
As of March 31, 2024, and December 31, 2023, receivables from contracts with customers, net of royalties and associated payables, on the balance sheet from continuing operations, were $215.2 million and $193.7 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
8
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Note C - Revenue from Contracts with Customers (Continued)
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 of March 31, 2024.
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 March 31, 2024, the Company had the following sales contracts in place which are expected to generate revenue from sales to customers for a period over 12 months starting at the inception of the contract:
Long-Term Contracts Outstanding at March 31, 2024
LocationCommodityEnd DateDescriptionApproximate Volumes
U.S.Natural Gas and NGLQ1 2030Deliveries from dedicated acreage in Eagle FordAs produced
CanadaNatural GasQ4 2024Contracts to sell natural gas at USD index pricing31 MMCFD
CanadaNatural GasQ4 2024Contracts to sell natural gas at CAD fixed pricing124 MMCFD
CanadaNatural GasQ4 2024Contracts to sell natural gas at USD fixed pricing25 MMCFD
CanadaNatural GasQ4 2024Contracts to sell natural gas at CAD index pricing28 MMCFD
CanadaNatural GasQ4 2025Contracts to sell natural gas at USD index pricing25 MMCFD
CanadaNatural GasQ4 2026Contracts to sell natural gas at USD index pricing49 MMCFD
CanadaNatural GasQ4 2027Contracts to sell natural gas at USD index pricing30 MMCFD
CanadaNatural GasQ4 2028Contracts to sell natural gas at USD index pricing10 MMCFD
Fixed price contracts are accounted for as normal sales and purchases for accounting purposes.

9
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
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 March 31, 2024, the Company had total capitalized drilling costs pending the determination of proved reserves of $34.2 million. The following table reflects the net changes in capitalized exploratory well costs during the three-month periods ended March 31, 2024 and 2023.
(Thousands of dollars)20242023
Beginning balance at January 1$49,118 $171,860 
  Additions pending the determination of proved reserves11,538 24,685 
  Capitalized exploratory well costs charged to expense(26,471)– 
Balance at March 31$34,185 $196,545 
Capitalized well costs charged to dry hole expense of $26.5 million for the three months ended March 31, 2024 was related to the Hoffe Park #1 (Mississippi Canyon 166) exploratory well in the Gulf of Mexico. Capital additions include the Orange #1 (Mississippi Canyon 216) and Ocotillo #1 (Mississippi Canyon 40) exploratory wells in the Gulf of Mexico. The preceding table excludes well costs of $5.9 million incurred and expensed directly to dry hole during the three months ended March 31, 2024, mainly related to the Oso #1 (Atwater Valley 138) exploration well in the Gulf of Mexico.
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.
March 31,
20242023
(Thousands of dollars)AmountNo. of WellsNo. of ProjectsAmountNo. of WellsNo. of Projects
Aging of capitalized well costs:
Zero to one year$11,641 4 3 $40,236 2 2 
One to two years– – – 13,171 2 2 
Two to three years– – – – – – 
Three years or more22,544 3 3 143,138 5 4 
$34,185 7 6 $196,545 9 8 
Of the $22.5 million of exploratory well costs capitalized more than one year at March 31, 2024, $15.1 million was in Vietnam, $4.7 million was in Canada, and $2.7 million was in Brunei. In all geographical areas, either further appraisal or development drilling is planned and/or development studies/plans are in various stages of completion. 
Impairments
There were pre-tax impairments of $34.5 million in the three months ended March 31, 2024 related to Calliope field in the Mississippi Canyon block in the Gulf of Mexico in which operational issues led to a reserve reduction. There were no impairments in the three months ended March 31, 2023.
Divestitures
On September 15, 2023, the Company completed the divestment of certain non-core operated Kaybob Duvernay assets and all of our non-operated Placid Montney assets, located in Alberta, Canada for net cash proceeds of C$139.0 million. No gain or loss was recorded related to this transaction, and the effective date of the transaction was March 1, 2023.
10
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)


Note E – Financing Arrangements and Debt
As of March 31, 2024, the Company had an $800 million revolving credit facility (RCF). The RCF is a senior unsecured guaranteed facility which expires on November 17, 2027. At March 31, 2024, the Company had no outstanding borrowings under the RCF and $3.7 million of outstanding letters of credit, which reduce the borrowing capacity of the RCF. At March 31, 2024, the interest rate in effect on borrowings under the RCF would have been 7.68%. At March 31, 2024, the Company was in compliance with all covenants related to the RCF.
The Company also has a shelf registration statement on file with the U.S. Securities and Exchange Commission (SEC) that permits the offer and sale of debt and/or equity securities through October 15, 2024.

Note F – Other Financial Information
Additional disclosures regarding cash flow activities are provided below.
Three Months Ended
March 31,
(Thousands of dollars)20242023
Net (increase) decrease in operating working capital, excluding cash and cash equivalents:
(Increase) decrease in accounts receivable $(13,174)$(3,976)
(Increase) decrease in inventories4,860 (9,296)
Decrease in prepaid expenses5,110 3,813 
Increase (decrease) in accounts payable and accrued liabilities ¹(24,852)(63,800)
Increase (decrease) in income taxes payable3,703 (1,772)
Net increase in noncash working capital$(24,353)$(75,031)
Supplementary disclosures:
Cash income taxes paid, net of refunds$405 $3,342 
Interest paid, net of amounts capitalized of $3.9 million in 2024 and $3.3 million in 2023
11,062 19,358 
Non-cash investing activities:
Asset retirement costs capitalized$10,955 $2,396 
(Increase) decrease in capital expenditure accrual(12,948)15,973 
1 Excludes payable balances relating to contingent consideration for prior acquisitions.

11
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)

Note G – Asset Retirement Obligations
The asset retirement obligations liabilities (ARO) recognized by the Company are related to the estimated costs to dismantle and abandon its producing oil and natural gas properties and related equipment.
A reconciliation of the beginning and ending aggregate carrying amount of the ARO for the three-month periods ended March 31, 2024 and 2023 is shown in the following table.
(Thousands of dollars)March 31, 2024March 31, 2023
Balance at beginning of year$914,763 $911,653 
Accretion12,774 11,157 
Liabilities incurred8,960 3,605 
Revisions of previous estimates1,995 (822)
Liabilities settled(737)(4,855)
Changes due to translation of foreign currencies(3,143)394 
Balance at end of period934,612 921,132 
Current portion of liability 1
(17,797)(90,774)
Noncurrent portion of liability$916,815 $830,358 
1 Included in “Other accrued liabilities” on the Consolidated Balance Sheets.
The estimation of future ARO is based on a number of assumptions requiring professional judgment. The Company cannot predict the type of revisions to these assumptions that may be required in future periods due to the availability of additional information such as: prices for oil field services, technological changes, governmental requirements and other factors.

12
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Note H – Employee and Retiree Benefit Plans
The Company has defined benefit pension plans that are 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 meet the requirements of 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 periods ended March 31, 2024 and 2023.
Three Months Ended March 31,
Pension BenefitsOther Postretirement Benefits
(Thousands of dollars)2024202320242023
Service cost$1,706 $1,650 $135 $132 
Interest cost8,391 8,507 782 874 
Expected return on plan assets(8,357)(8,194)– – 
Estimated defined contribution provision55 – – – 
Amortization of prior service cost (credit)579 155 (133)(133)
Recognized actuarial loss (gain)2,360 2,401 (812)(781)
Total net periodic benefit expense$4,734 $4,519 $(28)$92 
The components of net periodic benefit expense, other than the service cost, are recorded in “Other income (loss)” in the Consolidated Statements of Operations.
During the three-month period ended March 31, 2024, the Company made contributions of $9.5 million to its defined benefit pension and postretirement benefit plans. Remaining funding in 2024 for the Company’s defined benefit pension and postretirement plans is anticipated to be $31.7 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 Annual Incentive Plan (AIP) authorizes the 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 AIP 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 term of the 2020 Long-Term Plan. Shares issued pursuant to awards granted under the 2020 Long-Term Plan may be shares that are authorized and unissued or shares that were reacquired by the Company, including shares purchased in the open market. Shares underlying awards that have been canceled, expired, forfeited or otherwise not issued under an award shall not count as shares issued under the Plan.
13
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Note I - Incentive Plans (Continued)
During the three months ended March 31, 2024, the Committee granted the following awards from the 2020 Long-Term Plan:
Type of AwardNumber of Awards GrantedGrant DateGrant Date
Fair Value		Valuation Methodology
Performance-based RSUs (TSR) 1
423,640 February 6, 2024$41.95 Monte Carlo
Performance-based RSUs (ROACE) 1
105,980 February 6, 2024$38.08 Average Stock Price
Time-based RSUs (Stock-Settled) 2
658,420 February 6, 2024$38.08 Average Stock Price
Time-based RSUs (Cash-Settled) 2
102,900 February 6, 2024$38.08 Average Stock Price
1 Performance-based RSUs are tied to the achievement of TSR and ROACE performance goals and scheduled to vest over a three-year performance period.
2 Time-based RSUs generally vest on the third anniversary of 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.
The Company currently has outstanding incentive awards issued to Directors under the 2021 Stock Plan for Non-Employee Directors (2021 NED Plan) and the 2018 Stock Plan for Non-Employee Directors. All awards on or after May 12, 2021, were made under the 2021 NED Plan.
During the three months ended March 31, 2024, the Committee granted the following awards to Non-Employee Directors under the 2021 NED Plan:
Type of AwardNumber of Awards GrantedGrant DateGrant Date Fair ValueValuation Methodology
Time-Based RSUs 1
47,412 February 07, 2024$37.97 Closing Stock Price
Time-Based RSUs 2
1,230 March 28, 2024$45.70 Closing Stock Price
1 Non-employee directors time-based RSUs are scheduled to vest on the first anniversary of the date of grant. Non-employee directors may elect to defer settlement of their vested time-based RSUs until (1) termination of service from the Board or (2) a future date selected by the director at the time of their deferral election. These unvested time-based RSUs are included in the table above, will vest in one year and become deferred RSUs.
2 Effective January 1, 2024, non-employee directors can elect to receive their annual cash retainers in the form of deferred RSUs. Director fees which are deferred into RSUs are calculated and expensed each quarter by taking fees earned in respect of the applicable quarter and dividing by the closing price of our common stock on the last trading day of the quarter. Each deferred RSU represents the right to receive one share of common stock following (1) termination of service from the Board or (2) a future date selected by the director at the time of their deferral election.
In 2017, the Company ceased granting stock options and SARs as a part of the Company’s long-term incentive compensation program. As of December 31, 2023 there were no outstanding stock options or SARs remaining.
Amounts recognized in the financial statements with respect to share-based plans are shown in the following table:
Three Months Ended
March 31,
(Thousands of dollars)20242023
Compensation charged against income before tax benefit$8,937 $11,196 
Related income tax benefit recognized in income1,014 1,581 
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).
14
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Note J – Earnings Per Share
Net income attributable to Murphy was used as the numerator in computing both basic and diluted income per common share for the three-month periods ended March 31, 2024 and 2023. The following table reports the weighted-average shares outstanding used for these computations.

Three Months Ended
March 31,
(Weighted-average shares)20242023
Basic method152,664,422 155,856,509 
Dilutive stock options and restricted stock units 1,152,204 1,532,057 
Diluted method153,816,626 157,388,566 

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 periods ended March 31, 2024 and 2023, the Company’s effective income tax rates were as follows:
20242023
Three months ended March 31,20.6%20.1%
The effective tax rate for the three-month periods ended March 31, 2024 and March 31, 2023, was below 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, and partially offset by several factors, including: the effects of income generated in foreign tax jurisdictions, certain of which have income tax rates higher than the U.S. Federal rate; U.S. state tax expense; and certain expenses, including exploration and other expenses in certain foreign jurisdictions, for which no income tax benefits are currently available.
The Company’s tax returns in multiple jurisdictions are subject to audit by taxing authorities. These audits often take 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. Additionally, the Company could be required to pay amounts into an escrow account as any matters are identified and appealed with the relevant taxing authorities. As of March 31, 2024, the earliest years remaining open for audit and/or settlement in our major taxing jurisdictions are as follows: U.S. – 2016; Canada – 2016; and Malaysia – 2017. The Company has retained certain possible liabilities and rights to income tax receivables relating to Malaysia for the years prior to 2019.

Note L – Financial Instruments and Risk Management
Murphy, at times, uses derivative instruments 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. 
15
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Note L – Financial Instruments and Risk Management (Continued)
Commodity Price Risks
During the first quarter of 2024 and 2023, the Company did not have any crude oil derivative contracts.
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 March 31, 2024 and 2023.
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 fair value measurements for these assets and liabilities at March 31, 2024 and December 31, 2023, are shown in the following table.
March 31, 2024December 31, 2023
(Thousands of dollars)Level 1Level 2Level 3TotalLevel 1Level 2Level 3Total
Liabilities:
Nonqualified employee savings plan$17,688 $– $– $17,688 $17,785 $– $– $17,785 
$17,688 $– $– $17,688 $17,785 $– $– $17,785 
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.
As of March 31, 2024 and December 31, 2023, there were no outstanding commodity WTI crude oil swaps and collars contracts subject to fair value measurement, nor were there any commodity swaps and collars liabilities.
In 2019, the Company acquired strategic deepwater Gulf of Mexico assets from LLOG Exploration Offshore L.L.C. and LLOG Bluewater Holdings, L.L.C. (LLOG). Under the terms of the transaction, in addition to the consideration paid, Murphy had an obligation to pay additional contingent consideration of up to $200 million in the event that certain revenue thresholds were exceeded between 2019 and 2022; and $50 million following first oil from certain development projects. The revenue threshold was not exceeded for 2019 or 2020; however, the threshold was met in 2021 and 2022.
In 2018, the Company, through a subsidiary, acquired Gulf of Mexico producing assets from Petrobras America Inc. (PAI), a subsidiary of Petróleo Brasileiro S.A. Under the terms of the transaction, in addition to the consideration paid, Murphy had an obligation to pay additional contingent consideration of up to $150 million if certain price and production thresholds were exceeded beginning in 2019 through 2025; and $50 million carry for PAI development costs in the St. Malo Field if certain enhanced oil recovery projects were undertaken. The price and production thresholds were not exceeded for 2019 and 2020; however, the thresholds were met in 2021 and 2022. As of December 31, 2021, Murphy had completely funded the carried interest.
As of the end of the second quarter of 2023, the Company had no remaining liabilities relating to prior acquisitions from PAI and LLOG. During the three months ended March 31, 2023, the Company paid a total of $171.7 million in contingent consideration payments. In the Consolidated Statements of Cash Flows, $124.0 million is shown in “Operating Activities” and $47.7 million is shown in “Financing Activities”.
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 March 31, 2024 and December 31, 2023.
The following table presents the carrying amounts and estimated fair values of financial instruments held by the Company at March 31, 2024 and December 31, 2023. The fair value of a financial instrument is the amount at which the instrument could be exchanged in a current transaction between willing parties. The table excludes
16
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Note L – Financial Instruments and Risk Management (Continued)
cash and cash equivalents, trade accounts receivable, trade accounts payable and accrued expenses, all of which had fair values approximating carrying amounts. The fair value of current and long-term debt was estimated based on rates offered to the Company at that time for debt of the same maturities. Substantially all of the Company’s long-term debt is actively traded in open markets, and accordingly, is classified as Level 1 in the fair value hierarchy. The Company has off-balance sheet exposures relating to certain letters of credit. The fair value of these, which represents fees associated with obtaining the instruments, was nominal.
March 31,December 31,
20242023
(Thousands of dollars)Carrying
Amount		Fair
Value		Carrying
Amount		Fair
Value
Financial liabilities:
Current and long-term debt$1,329,399 $1,284,012 $1,329,075 $1,265,185 

Note M – Accumulated Other Comprehensive Loss
The components of “Accumulated other comprehensive loss” on the Consolidated Balance Sheets at December 31, 2023 and March 31, 2024 and the changes during the three-month period ended March 31, 2024 are presented net of taxes in the following table.
(Thousands of dollars)Foreign
Currency
Translation
Gains (Losses)		Retirement
and
Postretirement
Benefit Plan
Adjustments		Total
Balance at December 31, 2023$(381,632)$(139,485)$(521,117)
Components of other comprehensive income (loss):
Before reclassifications to income(35,528)– (35,528)
Reclassifications to income ¹– 910 910 
Net other comprehensive income (loss)(35,528)910 (34,618)
Balance at March 31, 2024$(417,160)$(138,575)$(555,735)
1  Reclassifications before taxes of $1.2 million are included in the computation of net periodic benefit expense for the three-month period ended March 31, 2024. See Note H for additional information. Related income taxes of $0.3 million are included in "Income tax expense” on the Consolidated Statements of Operations for the three-month period ended March 31, 2024.

17
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
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 U.S. 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 gas or mineral leases; restrictions on drilling and/or production; laws, regulations and government action intended for the promotion of safety and the protection and/or remediation of the environment including in connection with the purported causes or potential impacts of climate change; governmental support for other forms of energy; and laws and regulations affecting the Company’s relationships with employees, suppliers, customers, stockholders and others. Given the factors involved in various government actions, including political considerations, it is difficult to predict their likelihood, the form they may take, or the effect they may have on the Company.
ENVIRONMENTAL MATTERS – Murphy and other companies in the oil and 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 (GHG) 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 of facilities once production has ceased.
Violation of federal or state 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 adequately insured, subject the Company to substantial expense, including both the cost to comply with applicable regulations and claims by neighboring landowners and other third parties for any personal injury and property damage that might result. In addition, 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 this item, the Company will be using a threshold of $1.0 million for such proceedings and the Company is not aware of environmental legal proceedings likely to exceed this $1.0 million threshold.
There continues to be an increase in regulatory oversight of the oil and gas industry at the federal level, with a focus on climate change and GHG emissions (including methane emissions). For example, federal methane regulations currently pending or enacted that would, among other things, require increased leak detection monitoring and repairs, stringent restrictions on venting and flaring, a new third-party monitoring program, and new fees on methane emissions from petroleum and natural gas facilities. In addition, there have been a number of executive orders issued 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. Executive orders have also been issued 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, the U.S. has since rejoined 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
18
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)
Note N – Environmental and Other Contingencies (Continued)

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 (including litigation related to climate change), 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 – Common Stock Issued and Outstanding
Activity in the number of shares of common stock issued and outstanding for the three-month periods ended March 31, 2024 and 2023 is shown below.
(Number of shares outstanding)
March 31, 2024March 31, 2023
Beginning of period152,748,642 155,467,319 
Restricted stock awards 1
1,100,759 630,756 
Treasury shares purchased
(1,273,245)– 
End of period152,576,156 156,098,075 
1 Shares issued upon exercise of stock options and award of restricted stock are less withholding for statutory income taxes owed upon issuance of shares.
On August 4, 2022, the Company’s Board of Directors authorized a share repurchase program of up to $300 million of the Company’s common stock. On October 30, 2023, the Company authorized an increase to the share repurchase program by an additional $300 million, bringing the total amount allowed to be repurchased under the program to $600 million. This repurchase program has no time limit and may be suspended or discontinued completely at any time without prior notice as determined by the Company at its discretion and dependent upon a variety of factors. The share repurchase program is a component of the Company’s capital allocation framework, the details of which can be found as part of the Company’s Form 8-K filed on August 4, 2022.
During the three months ended March 31, 2024, the Company repurchased 1.3 million shares of its common stock under the share repurchase program for $50.0 million, including excise taxes, commissions and fees. As of March 31, 2024, the Company has $400 million of its common stock remaining available to repurchase under the program.

19
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (CONTINUED)

Note P – 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, interest expense and unallocated overhead, is shown in the table to reconcile the business segments to consolidated totals. The Company has accounted for its former United Kingdom (U.K.), Malaysia, and U.S. refining and marketing operations as discontinued operations for all periods presented.
Total Assets at March 31, 2024Three Months Ended March 31, 2024Three Months Ended March 31, 2023
(Millions of dollars)External
Revenues		Income
(Loss)		External
Revenues		Income
(Loss)
Exploration and production ¹
United States$7,030.7 $659.6 $134.5 $682.3 $226.0 
Canada2,059.1 136.9 19.4 155.8 21.9 
Other210.2 (0.1)(10.8)3.6 (5.2)
Total exploration and production9,300.0 796.4 143.1 841.7 242.7 
Corporate368.0 – (27.6)– (28.7)
Continuing operations9,668.0 796.4 115.6 841.7 214.0 
Discontinued operations, net of tax0.7 – (0.9)– 0.3 
Total$9,668.7 $796.4 $114.7 $841.7 $214.3 
1 Additional detail about the results of oil and natural gas operations is presented in the Exploration and Production Continuing Operations table on page 23.


20
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS

The following Management’s Discussion and Analysis of Financial Condition and Results of Operations (MD&A) should be read together with the unaudited consolidated financial statements and accompanying notes for the quarter ended March 31, 2024 included under Item 1 Financial Statements of this Form 10-Q and the audited consolidated financial statements and related notes and MD&A included in Item 8 and 7, respectively, of our Annual Report on Form 10-K for the year ended December 31, 2023. This MD&A includes forward-looking statements that involve certain risks and uncertainties. See Forward-Looking Statements at the end of this section.
Overview
Murphy Oil Corporation is a global oil and gas exploration and production company, with both onshore and offshore operations and properties. The Company produces crude oil, natural gas and natural gas liquids primarily in the U.S. and Canada and explores for crude oil, natural gas and natural gas liquids in targeted areas worldwide. Our production in the U.S. is primarily from fields in the Gulf of Mexico and in the Eagle Ford Shale area of South Texas. In Canada, we produce from the Tupper Montney and Kaybob Duvernay fields in British Columbia and Alberta, and we produce from the Hibernia and Terra Nova fields, located offshore Newfoundland in the Jeanne d’Arc Basin.
Significant Company financial and operational highlights during the first quarter of 2024 were as follows:
•Production during the quarter was 176,671 barrels of oil equivalent per day (including NCI).
•Exploration areas expanded with the award of six deepwater blocks from Gulf of Mexico Federal Lease Sale 261
•Repurchased shares of our common stock under the share repurchase program for $50.0 million, including excise taxes, commissions and fees.

Murphy Oil Corporation’s net income from continuing operations, including noncontrolling interest, for the three months ended March 31, 2024 was $115.6 million, a decrease of $98.5 million compared to the same period of 2023. Lower net income from continuing operations was largely driven by higher lease operating expenses ($34.3 million), higher exploration expenses ($34.2 million), and higher impairment of assets ($34.5 million), partially offset by lower income tax expense ($23.8 million). Higher lease operating expenses related to workovers in the Gulf of Mexico and ramp up of production from the Terra Nova field in Canada Offshore following the completion of the asset life extension project in the fourth quarter of 2023. Higher exploration costs were the result of dry hole expense for the previously suspended exploration costs for Hoffe Park #1 (Mississippi Canyon166) and additional costs related to Oso #1 (Atwater Valley 138) exploration well in the Gulf of Mexico. The Mississippi Canyon Block 166 lease will expire in 2024 and there are no plans for additional exploration activities. The Oso #1 (Atwater Valley 138) exploration well encountered non-commercial hydrocarbons in the fourth quarter of 2023 and operations finished in the first quarter of 2024. Lower income tax expense was the result of lower pre-tax income.
For the three months ended March 31, 2024, total hydrocarbon production was 176,671 barrels of oil equivalent per day, a decrease of 2% compared to the same period in 2023. The decrease was principally due to lower production in the Gulf of Mexico due to increased downtime for workovers, which was substantially offset by an increase in volumes at Tupper Montney from new well production and lower royalty rates and an increase in production from the Terra Nova field in Canada Offshore due to the restart of production.

21
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Results of Operations
Murphy’s Net income (loss) by type of business and geographic segment is presented below.
Income (Loss)
Three Months Ended
March 31,
(Millions of dollars)20242023
Exploration and production
United States$134.5 $226.0 
Canada19.4 21.9 
Other (10.8)(5.2)
Total exploration and production
143.1 242.7 
Corporate and other(27.5)(28.7)
Income from continuing operations115.6 214.0 
Discontinued operations ¹(0.9)0.3 
Net income including noncontrolling interest114.7 214.3 
Net income attributable to noncontrolling interest
24.7 22.7 
Net income attributable to Murphy$90.0 $191.6 
1 The Company has presented its former U.K. and U.S. refining and marketing operations as discontinued operations in its consolidated financial statements. 
22
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Results of Operations (Continued)
Exploration and Production Continuing Operations
The following section of Exploration and Production (E&P) continuing operations excludes the Corporate segment, unless otherwise noted.
The following are summarized income statements for E&P continuing operations:
Three Months Ended
March 31,
(Millions of dollars)20242023
Revenues and other income
Revenue from production
$794.6 $796.2 
Sales of purchased natural gas
0.2 43.7 
Other income
1.6 1.8 
Total revenues and other income
796.4 841.7 
Cost and Expenses
Lease operating expenses234.3 200.0 
Severance and ad valorem taxes10.1 11.4 
Transportation, gathering and processing56.5 53.9 
Costs of purchased natural gas0.2 32.3 
Depreciation, depletion and amortization208.3 192.8 
Impairments of assets34.5 – 
Accretion of asset retirement obligations12.7 11.1 
Total exploration expenses44.4 10.3 
Selling and general expenses6.1 8.9 
Other 8.8 13.6 
Results of operations before taxes180.5 307.4 
Income tax provisions
37.4 64.7 
Results of operations (excluding Corporate segment) 1
$143.1 $242.7 
1 Includes results attributable to a noncontrolling interest in MP GOM.
23
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Results of Operations (Continued)
Pricing
The following table contains the weighted average sales prices for the three-month periods ended March 31, 2024 and 2023.
Three Months Ended
March 31,
(Weighted average sales prices)20242023
Crude oil and condensate – dollars per barrel
United States - Onshore
$76.85 $74.98 
United States - Offshore 1
77.58 73.27 
Canada - Onshore 2
67.59 74.29 
Canada - Offshore 2
85.99 77.93 
Other 2
– 89.05 
Natural gas liquids – dollars per barrel
United States - Onshore20.67 22.11 
United States - Offshore 1
24.32 25.63 
Canada - Onshore 2
34.84 46.59 
Natural gas – dollars per thousand cubic feet
United States - Onshore1.94 2.51 
United States - Offshore 1
2.66 3.27 
Canada - Onshore 2
2.05 2.55 
1  Prices include the effect of noncontrolling interest in MP GOM.
2 U.S. dollar equivalent.
The following table contains benchmark prices relevant to the Company for the three-month periods ended March 31, 2024 and 2023.
Three Months Ended
March 31,
(Average price for the period)20242023
Oil and NGLs
WTI ($/BBL)$76.96 $76.13 
Natural gas
NYMEX ($/MMBTU)2.42 2.67 
AECO (C$/MCF)
2.50 3.22 
24
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Results of Operations (Continued)
Production Volumes
The following table contains hydrocarbons produced during the three-month periods ended March 31, 2024 and 2023. For further discussion on volumes, please see Revenues from Production section on page 26.
Three Months Ended
March 31,
(Barrels per day unless otherwise noted)20242023
Net crude oil and condensate
United States - Onshore
20,382 19,277 
United States - Offshore 1
66,078 75,699 
Canada - Onshore
2,255 3,283 
Canada - Offshore
6,264 2,459 
Other245 269 
Total net crude oil and condensate
95,224 100,987 
Net natural gas liquids
United States - Onshore
4,166 4,157 
United States - Offshore 1
4,687 6,342 
Canada - Onshore
453 826 
Total net natural gas liquids
9,306 11,325 
Net natural gas – thousands of cubic feet per day
United States - Onshore
24,231 24,160 
United States - Offshore 1
53,161 75,203 
Canada - Onshore
355,455 305,232 
Total net natural gas
432,847 404,595 
Total net hydrocarbons - including NCI 2,3
176,671 179,745 
Noncontrolling interest
Net crude oil and condensate – barrels per day(6,499)(6,613)
Net natural gas liquids – barrels per day(211)(232)
   Net natural gas – thousands of cubic feet per day (2,074)(2,354)
Total noncontrolling interest 2,3
(7,056)(7,237)
Total net hydrocarbons - excluding NCI 2,3
169,615 172,508 
1 Includes net volumes attributable to a noncontrolling interest in MP GOM.
2 Natural gas converted on an energy equivalent basis of 6:1.
3 NCI – noncontrolling interest in MP GOM.

25
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Results of Operations (Continued)
Revenues from Production
The Company’s production revenues by country and product were as follows:
Three Months Ended
March 31,
(Millions of dollars)20242023
Revenues from production
United States - Oil
$623.0 $630.4 
United States - Natural gas liquids
18.2 22.9 
United States - Natural gas
17.2 27.6 
Canada - Oil
68.6 38.1 
Canada - Natural gas liquids
1.4 3.4 
Canada - Natural gas
66.3 70.2 
Other - Oil
(0.1)3.6 
Total revenue from production
$794.6 $796.2 
Revenue from production for the three months ended March 31, 2024 decreased by $1.6 million compared to the same period in 2023. Lower revenue from U.S. E&P was primarily attributable to lower sales volumes from the Gulf of Mexico due to increased downtime for workovers, partially offset by higher sales volumes at Eagle Ford Shale assets from new well production and higher realized prices at both Eagle Ford Shale assets and the Gulf of Mexico. Higher revenue from Canadian E&P was primarily attributable to higher sales volumes from Terra Nova and Tupper Montney fields, partially offset by lower pricing at Tupper Montney and lower sales volumes from Kaybob Duvernay fields. Tupper Montney had an increase in volumes as a result of new well production and lower royalty rates, while lower volumes at Kaybob Duvernay resulted from the divestiture of certain non-core operated assets and all of our non-operated Placid Montney assets during the second half of 2023. The Terra Nova field in Canada Offshore restarted production during the fourth quarter of 2023 after completion of the asset life extension project.
Natural gas is purchased and subsequently sold to third parties in order to provide operational flexibility and cost mitigation for transportation commitments. Sales of purchase natural gas is included in “Total revenues and other income” and cost to purchase natural gas is included in “Costs and Expenses” in the summarized income statements for E&P continuing operations on page 23.

26
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Results of Operations (Continued)
Lease Operating and Transportation, Gathering and Processing Expenses
The Company’s total lease operating expenses and transportation, gathering and processing (TGP) expenses by geographic area were as follows:
Three Months Ended
March 31,
(Millions of dollars)
(Dollars per equivalent barrel)
2024202320242023
Lease operating expenses
United States - Onshore
$35.6 $37.3 $13.68 $15.08 
United States - Offshore
151.0 125.3 20.34 14.69 
Canada - Onshore
31.0 33.7 5.49 6.81 
Canada - Offshore
16.5 3.1 25.91 15.06 
Other0.2 0.6 – 15.05 
Total lease operating expenses
$234.3 $200.0 $14.37 $12.35 
TGP expenses
United States - Onshore
2.7 4.1 1.04 1.70 
United States - Offshore
33.9 33.3 4.57 3.90 
Canada - Onshore
18.0 15.3 3.19 3.10 
Canada - Offshore
1.9 1.2 3.03 5.57 
Total TGP expenses
$56.5 $53.9 $3.47 $3.33 
Lease operating expenses and TGP expenses for the three months ended March 31, 2024 increased by $34.3 million and $2.6 million, respectively, compared to the same period in 2023. Higher lease operating expenses from US E&P was due to workovers in the Gulf of Mexico. Higher lease operating expenses and TGP from Canada E&P resulted from ramp up of production at the Terra Nova field since the completion of the asset life extension project in the fourth quarter of 2023.

Depreciation, Depletion and Amortization Expense
The Company’s depreciation, depletion and amortization (DD&A) expense by geographic area were as follows:
Three Months Ended
March 31,
(Millions of dollars)
(Dollars per equivalent barrel)
(Millions of dollars)2024202320242023
DD&A expense
United States - Onshore
$74.1 $64.6 $28.52 $26.18 
United States - Offshore
99.9 95.7 13.46 11.22 
Canada - Onshore
28.1 29.7 4.99 6.01 
Canada - Offshore
6.2 1.9 9.68 9.29 
Other– 0.9 20.38 21.62 
Total DD&A expense
$208.3 $192.8 $12.77 $11.90 
DD&A expense for the three months ended March 31, 2024 increased by $15.5 million, compared to the same period in 2023. Higher DD&A expense from U.S. E&P resulted from higher sales volumes from the Eagle Ford Shale assets and an overall increase in rates. Higher DD&A expense from Canada E&P was primarily the result of higher sales volumes from Tupper Montney and Terra Nova fields, partially offset by overall lower rates due to fewer sales volumes from Kaybob Duvernay and Placid Montney assets following the sale of a portion of non-core assets in the fourth quarter of 2023.
27
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Results of Operations (Continued)
Impairment of Assets
Impairment of assets for the three months ended March 31, 2024 was $34.5 million and related to Calliope field in Mississippi Canyon in the Gulf of Mexico, as a result of operational issues that led to a reserve reduction. There were no impairments in the three months ended March 31, 2023.

Exploration Expenses
The Company’s exploration expenses were as follows:
Three Months Ended
March 31,
(Millions of dollars)20242023
Exploration expenses
Dry holes and previously suspended exploration costs$32.4 $0.9 
Geological and geophysical1.4 0.8 
Other exploration7.8 5.9 
Undeveloped lease amortization2.8 2.7 
Total exploration expenses
$44.4 $10.3 
Exploration expenses for the three months ended March 31, 2024 increased by $34.1 million compared to the same period in 2023. Higher dry holes and previously suspended exploration costs primarily relate to the previously suspended costs for Hoffe Park #1 (Mississippi Canyon 166) and additional costs related to the Oso #1 (Atwater Valley 138) exploration well in the Gulf of Mexico. The Mississippi Canyon Block 166 lease will expire in 2024 and there are no plans for additional exploration activities. The Oso #1 (Atwater Valley 138) exploration well encountered non-commercial hydrocarbons in the fourth quarter of 2023 and finished operations in the first quarter of 2024.

Other Expenses
Other expenses for the three months ended March 31, 2024 decreased by $4.8 million compared to the same period in 2023. Other expenses were lower primarily due to an unfavorable contingent consideration adjustment of $3.9 million recorded in 2023 related to prior Gulf of Mexico acquisitions (see Note L).

Income Taxes
Income taxes for the three months ended March 31, 2024 decreased by $27.3 million, compared to the same period in 2023. Lower income taxes were primarily the result of lower pre-tax income.

28
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Results of Operations (Continued)
Corporate
Corporate activities include interest expense and income, foreign exchange effects and corporate overhead not allocated to E&P.
Corporate activities reported a loss of $27.5 million for the three months ended March 31, 2024, a favorable variance of $1.2 million compared to the same period of 2023. The favorable variance was primarily due to foreign exchange gains ($10.9 million) and lower interest expense ($9.0 million), partially offset by increased selling and general expense ($15.7 million) and lower income tax benefits ($3.4 million) .
Interest charges are lower for the three months ended March 31, 2024, primarily due to lower overall debt levels. Higher selling and general expenses were a result of the timing of corporate donations and an increase in provisions for incentive awards. Lower income tax benefit was a result of lower pre-tax losses.

Financial Condition
The Company’s primary sources of liquidity are cash on hand, net cash provided by continuing operations activities and available borrowing capacity under its senior unsecured RCF. The Company’s liquidity requirements consist primarily of capital expenditures, debt maturity, retirement and interest payments, working capital requirements, dividend payments, and, as applicable, share repurchases.

Cash Flows
The following table presents the Company’s cash flows for the periods presented:
Three Months Ended
March 31,
(Thousands of dollars)20242023
Net cash provided by (required by):
Net cash provided by continuing operations activities$398.8 $279.8 
Net cash required by investing activities
(249.1)(345.3)
Net cash required by financing activities
(144.2)(114.7)
Effect of exchange rate changes on cash and cash equivalents0.9 0.6 
Net increase (decrease) in cash and cash equivalents
$6.4 $(179.6)
Cash Provided by Continuing Operations Activities
Net cash provided by continuing operations activities for the three months ended March 31, 2024 was $119.0 million higher compared to the same period in 2023. The increase was primarily attributable to no contingent consideration payments related to prior Gulf of Mexico acquisitions in 2024 (2023: $124.0 million) and the timing of working capital settlements ($50.7 million), partially offset by higher lease operating expenses ($34.3 million) primarily related to workovers in the Gulf of Mexico. Payments of contingent consideration are shown both in “Operating Activities” and “Financing Activities” in the Company’s Consolidated Statements of Cash Flows; amounts considered as financing activities are those amounts paid up to the original estimated contingent consideration liability included in the purchase price allocation, at the time of acquisition. Any contingent consideration paid above the original estimated liability, included in the purchase price, are considered operating activities. During the three months ended March 31, 2023, the Company paid a total of $171.7 million in contingent consideration, of which $124.0 million is shown in “Operating Activities” and $47.7 million is shown in “Financing Activities” in the Company’s Consolidated Statements of Cash Flows. As of the end of the second quarter of 2023, the Company had no further obligation payable for contingent consideration relating to prior Gulf of Mexico acquisitions.
Cash Required by Investing Activities
Net cash required by investing activities for the three months ended March 31, 2024 was $96.2 million lower compared to the same period in 2023. The decrease was due to lower property additions and dry hole costs ($96.2 million).
29
ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Financial Condition (Continued)
A reconciliation of “Property additions and dry hole costs” in the Consolidated Statements of Cash Flows to total capital expenditures for continuing operations follows.
Three Months Ended
March 31,
(Millions of dollars)20242023
Property additions and dry hole costs per cash flow statements $249.1 $345.3 
Geophysical and other exploration expenses7.2 4.9 
Capital expenditure accrual changes and other15.0 (14.2)
Total capital expenditures$271.3 $336.0 
Total accrual basis capital expenditures are shown below.
Three Months Ended
March 31,
(Millions of dollars)20242023
Capital Expenditures
Exploration and production$267.1 $329.7 
Corporate4.2 6.3 
Total capital expenditures$271.3 $336.0 
Lower capital expenditures in the three months ended March 31, 2024 compared to the same period of 2023 was primarily attributable to lower development expenditures at Eagle Ford Shale assets, partially offset by higher development expenditures at various Gulf of Mexico fields.
Capital expenditures in 2024 primarily relate to development drilling and field development activities at Eagle Ford Shale assets ($53.4 million), development drilling and field development activities at Tupper Montney field ($47.8 million), development activities in the Gulf of Mexico, primarily related to Khaleesi, Mormont, Lucius and St. Malo fields ($106.4 million) and total exploration costs of $35.8 million. Total exploration costs in 2024 were in the Gulf of Mexico for the Orange #1 (Mississippi Canyon 216) and Ocotillo #1 (Mississippi Canyon 40) exploration wells and additional costs related to Oso #1 (Atwater Valley 138) exploration well which encountered non-commercial hydrocarbons in the fourth quarter of 2023 and finished operations in the first quarter of 2024.
Cash Required by Financing Activities
Net cash required by financing activities for the three months ended March 31, 2024 increased by $29.5 million compared to the same period in 2023. In 2024, the cash used in financing activities was principally for the repurchase of common shares ($50.0 million, excluding accrued excise tax), cash dividends to shareholders of $0.30 per share ($45.8 million), withholding tax on stock-based incentive awards ($25.3 million) and distributions to the noncontrolling interest in the Gulf of Mexico ($23.0 million). In 2023, there were payments of contingent consideration related to prior Gulf of Mexico acquisitions ($47.7 million) as discussed in the “Cash Provided by Operating Activities” section.

Liquidity
At March 31, 2024, the Company had approximately $1.1 billion of liquidity consisting of $323.4 million in cash and cash equivalents and $796.3 million available on its committed senior unsecured RCF with a major banking consortium.
The Company’s $800 million senior unsecured RCF expires in November 2027 and as of March 31, 2024, the Company had no outstanding borrowings under the RCF and $3.7 million of outstanding letters of credit, which reduce the borrowing capacity of the senior unsecured RCF. At March 31, 2024, the interest rate in effect on borrowings under the facility would have been 7.68%. At March 31, 2024, the Company was in compliance with all covenants related to the RCF.
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ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Financial Condition (Continued)
Cash and invested cash are maintained in several operating locations outside the U.S. As of March 31, 2024, cash and cash equivalents held outside the U.S. included U.S. dollar equivalents of approximately $98.1 million, the majority of which was held in Canada ($60.0 million), Mexico ($15.0 million) and the U.K. ($9.1 million). 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.
Working Capital
(Millions of dollars)March 31, 2024December 31, 2023
Working capital
Total current assets$760.9 $752.2 
Total current liabilities818.2 846.5 
Net working capital liability
$(57.3)$(94.3)
As of March 31, 2024, net working capital had a favorable increase of $37.0 million compared to December 31, 2023. The favorable increase was primarily attributable to lower other accrued liabilities ($39.5 million), lower operating lease liabilities ($28.4 million), higher accounts receivable ($12.9 million), and a higher cash balance ($6.4 million), partially offset by higher accounts payable ($39.0 million). Lower accrued liabilities were primarily due to incentive payments and lower operating lease liabilities were primarily due to 2024 payments reducing drilling rig and vessel lease liabilities. Higher accounts receivable and higher accounts payable were primarily due to the timing of cash receipts and cash payments, respectively.
Capital Employed
A summary of capital employed at March 31, 2024 and December 31, 2023 follows.
March 31, 2024December 31, 2023
(Millions of dollars)Amount%Amount%
Capital employed
Long-term debt$1,328.7 20.0 %$1,328.3 19.9 %
Murphy shareholders' equity5,304.0 80.0 %5,362.8 80.1 %
Total capital employed$6,632.7 100.0 %$6,691.1 100.0 %
At March 31, 2024, long-term debt of $1,328.7 million had increased by $0.4 million compared to December 31, 2023, primarily as a result of normal debt issuance cost amortization. The total of the fixed-rate notes had a weighted average maturity of 7.9 years and a weighted average coupon of 6.2%.
Murphy shareholders’ equity decreased by $58.8 million in 2024 primarily due to shares repurchased ($50.0 million, including excise tax), cash dividends paid ($45.8 million) and unrealized foreign currency translation losses ($35.5 million), partially offset by net income earned ($90.0 million). A summary of transactions in stockholders’ equity accounts is presented in the Consolidated Statements of Stockholders’ Equity on page 6 of this Form 10-Q report.

Critical Accounting Estimates
As of March 31, 2024, there have been no significant changes to our critical accounting estimates since our Annual Report on Form 10-K for the year ended December 31, 2023.

Accounting Changes and Recent Accounting Pronouncements
See Note B to the Consolidated Financial Statements regarding the impact or potential impact of recent accounting pronouncements upon our financial position and results of operations.

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ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Other Key Performance Metrics
The Company uses other operational performance and income metrics to review operational performance. Management uses adjusted net income, earnings before interest, taxes, depreciation and amortization (EBITDA) and adjusted EBITDA internally to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Adjusted net income also excludes certain items that management believes affect the comparability of results between periods. Management believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. Adjusted net income, 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 GAAP.
The following table reconciles reported net income attributable to Murphy to adjusted net income from continuing operations attributable to Murphy.
Three Months Ended
March 31,
(Millions of dollars)
20242023
Net income attributable to Murphy (GAAP) 1
$90.0 $191.6 
Discontinued operations loss (income)0.9 (0.3)
Net income from continuing operations attributable to Murphy
90.9 191.3 
Adjustments:
Impairment of assets34.5 – 
Write-off of previously suspended exploration well26.1 – 
Foreign exchange (gain) loss(10.5)0.4 
Mark-to-market loss on contingent consideration— 3.9 
Total adjustments, before taxes
50.1 4.3 
Income tax benefit related to adjustments
(10.2)(0.9)
Total adjustments after taxes39.9 3.4 
Adjusted net income from continuing operations attributable to Murphy
(Non-GAAP)
$130.8 $194.7 
Net income from continuing operations per average diluted share (GAAP)
$0.60 1.22 
Adjusted net income from continuing operations per average diluted share
(Non-GAAP)
$0.85 1.24 
1  Excludes amounts attributable to a noncontrolling interest in MP GOM.


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ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)
Other Key Performance Metrics (Continued)

The following table reconciles reported net income attributable to Murphy to EBITDA attributable to Murphy and adjusted EBITDA attributable to Murphy.
Three Months Ended
March 31,
(Millions of dollars)20242023
Net income attributable to Murphy (GAAP) 1
$90.0 $191.6 
Income tax expense30.1 53.8 
Interest expense, net20.0 28.9 
Depreciation, depletion and amortization expense 1
202.7 189.3 
EBITDA attributable to Murphy (Non-GAAP)342.8 463.6 
Impairment of asset34.5 – 
Write-off of previously suspended exploration well26.1 – 
Accretion of asset retirement obligations 1
11.4 9.9 
Foreign exchange (gain) loss(10.5)0.4 
Mark-to-market loss on contingent consideration– 3.9 
Discontinued operations loss (income)0.9 (0.3)
Adjusted EBITDA attributable to Murphy (Non-GAAP)$405.2 $477.5 
1  Excludes amounts attributable to a noncontrolling interest in MP GOM.


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ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)

Outlook
The oil and gas industry is impacted by global commodity pricing and as a result the prices for the Company’s primary products are often volatile and are affected by the levels of supply and demand for energy. As discussed in the Results of Operations section discussing revenues, on page 26, higher average crude oil price during the first quarter of 2024 compared to same period in 2023, directly impacted the Company’s product sales revenue.
As of close on April 30, 2024, forward price curves for existing forward contracts for the remainder of 2024 and 2025 are shown in the table below:
20242025
WTI ($/BBL)
79.9274.76
NYMEX ($/MMBTU)
2.613.52
AECO (US$ Equivalent/MCF)
1.352.43
Similar to the overall inflation and higher interest rates in the wider economy, the oil and gas industry and the Company is observing higher costs for goods and services used in E&P operations. Murphy continues to manage input costs through its dedicated procurement department focused on managing supply chain and other costs to deliver cash flow from operations.
We cannot predict what impact economic factors (including, but not limited to, inflation, global conflicts and possible economic recession) may have on future commodity pricing. Lower prices, should they occur, will result in lower profits and operating cash flows. For the second quarter of 2024, production is expected to average between 176 and 184 thousand barrels of oil equivalents per day (MBOEPD), excluding noncontrolling interest.
The Company’s capital expenditure spend for 2024 is expected to be between $920 million and $1,020 million, excluding noncontrolling interest. 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 capital program in 2024 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), in accordance with the Company’s capital allocation framework designed to allow for additional shareholder returns and debt reduction. Details of the framework can be found in the “Capital Allocation Framework” section of the Company’s Form 8-K filed on August 4, 2022. In 2023, the Company’s Board of Directors authorized a $300 million increase to the original share repurchase program announced in the Capital Allocation Framework, bringing the total amount allowed to be repurchased under the program to $600 million. As of March 31, 2024, the Company has $400 million remaining available to repurchase.
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 RCF (see Note E).
As of April 30, 2024, the Company has entered into forward fixed-price delivery contracts to manage risk associated with certain future oil and natural gas sales prices as follows:
Volumes
(MMcf/d)		Price/MCFRemaining Period
AreaCommodityTypeStart DateEnd Date
CanadaNatural GasFixed price forward sales162 C$2.394/1/202412/31/2024
CanadaNatural GasFixed price forward sales25 US$1.984/1/202410/31/2024
CanadaNatural GasFixed price forward sales15 US$1.9811/1/202412/31/2024
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ITEM 2.  MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS (CONTINUED)

Forward-Looking Statements
This Form 10-Q contains forward-looking statements within the meaning of 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, results and plans, are subject to inherent risks, uncertainties and assumptions (many of which are beyond our control) and are not guarantees of performance. In particular, statements, express or implied, concerning the Company’s future operating results or activities and returns or the Company's ability and decisions to replace or increase reserves, increase production, generate returns and rates of return, replace or increase drilling locations, reduce or otherwise control operating costs and expenditures, generate cash flows, pay down or refinance indebtedness, achieve, reach or otherwise meet initiatives, plans, goals, ambitions or targets with respect to emissions, safety matters or other ESG (environmental/social/governance) matters, make capital expenditures or pay and/or increase dividends or make share repurchases and other capital allocation decisions are forward-looking statements. Factors that could cause one or more of these future events, results or plans not to occur as implied by any forward-looking statement, which consequently could cause actual results or activities to differ materially from the expectations expressed or implied by such forward-looking statements, 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; geopolitical concerns; 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, banking system or economies in general, including inflation. 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 our most recent Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission (“SEC”) and on page 37 of this Form 10-Q report, and any subsequent Quarterly Report on Form 10-Q or Current Report on Form 8-K that we file, available from the SEC’s website and from Murphy Oil Corporation’s website at http://ir.murphyoilcorp.com. Investors and others should note that we may announce material information using SEC filings, press releases, public conference calls, webcasts and the investors page of our website. We may use these channels to distribute material information about the Company; therefore, we encourage investors, the media, business partners and others interested in the Company to review the information we post on our website. The information on our website is not part of, and is not incorporated into, this report. Murphy Oil Corporation undertakes no duty to publicly update or revise any forward-looking statements.
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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, at times, makes use of derivative financial and commodity instruments to manage risks associated with existing or anticipated transactions.
There were no derivative commodity contracts in place at March 31, 2024.
There were no derivative foreign exchange contracts in place at March 31, 2024.

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 March 31, 2024, 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.
36
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 gas business naturally lead to various risks and uncertainties. These risk factors are discussed in Item 1A Risk Factors in the Company’s 2023 Form 10-K filed on February 23, 2024. In March 2024, the SEC finalized its climate disclosure rule, SEC Release No. 34-99678, The Enhancement and Standardization of Climate-Related Disclosures for Investors, which requires registrants to provide certain climate-related information in their annual reports. In April 2024, the SEC stayed the climate disclosure rule pending judicial review. The Company has not identified any additional risk factors not previously disclosed in its 2023 Form 10-K report or noted above.

ITEM 2. UNREGISTERED SALES OF EQUITY SECURITIES AND USE OF PROCEEDS
Issuer Purchase of Equity Securities:
The following table summarizes repurchases of our common stock occurring in the first quarter 2024.
PeriodTotal Number of Shares Purchased
Average Price Paid Per Share1
Total Number of Shares Purchased as Part of Publicly Announced Plans or Programs
Maximum Approximate Dollar Value of Shares that May Yet Be Purchased Under Plans or Programs2,3
(in thousands)
January 1 through January 31, 2024– $– – $450,000 
February 1 through February 29, 20241,273,245 $39.25 1,273,245 $400,000 
March 1 through March 31, 2024– $— – $400,000 
1 Amounts exclude 1% excise tax and fees on share repurchases.
2 In August 2022, the Board authorized an initial share repurchase program of up to $300 million of the Company’s common stock. On October 30, 2023, the Board authorized an increase to the share repurchase program by an additional $300 million, bringing the total amount allowed to be repurchased under the program to $600 million. Pursuant to the share repurchase program, the Company may repurchase shares through open market purchases, privately negotiated transactions and other means in accordance with federal securities laws. This repurchase program has no time limit and may be suspended or discontinued completely at any time without prior notice as determined by the Company at its discretion.
3 Maximum approximate dollar values reported represent amounts at end of the month. Since the inception of the share repurchase program, the Company has repurchased 4,684,403 shares of its common stock in open-market transactions for $199.9 million, excluding taxes and fees.

37
ITEM 5. OTHER INFORMATION
During the three months ended March 31, 2024, no director or officer of the Company adopted or terminated a “Rule 10b5-1 trading arrangement” or “non-Rule 10b5-1 trading arrangement,” as each term is defined in Item 408(a) of Regulation S-K.

ITEM 6. EXHIBITS
The Exhibit Index on page 40 of this Form 10-Q report lists the exhibits that are hereby filed or incorporated by reference.
38
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/ PAUL D. VAUGHAN
Paul D. Vaughan
Vice President and Controller
(Chief Accounting Officer and Duly Authorized Officer)
May 2, 2024
(Date)
39
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.
101. INSInline XBRL Instance Document
101. SCHInline XBRL Taxonomy Extension Schema Document
101. CALInline XBRL Taxonomy Extension Calculation Linkbase Document
101. DEFInline XBRL Taxonomy Extension Definition Linkbase Document
101. LABInline XBRL Taxonomy Extension Labels Linkbase Document
101. PREInline XBRL Taxonomy Extension Presentation Linkbase
104
Cover Page Interactive Data File (formatted as Inline XBRL and contained in Exhibit 101)

40