Murphy Oil Corporation Announces Second Quarter 2024 Financial and Operational Results, Revises Capital Allocation Framework to Accelerate Shareholder Returns, Increases Share Repurchase Authorization

Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the second quarter ended June 30, 2024, including net income attributable to Murphy of $128 million, or $0.83 net income per diluted share. Excluding discontinued operations and other items affecting comparability between periods, adjusted net income attributable to Murphy was $124 million, or $0.81 adjusted net income per diluted share.

Unless otherwise noted, the financial and operating highlights and metrics discussed in this commentary exclude noncontrolling interest (NCI).¹

Highlights for the second quarter include:

• Produced 181 thousand barrels of oil equivalent per day (MBOEPD), with 91 thousand barrels of oil per day (MBOPD)
• Achieved record high peak gross production rate of 496 million cubic feet per day (MMCFD) in Tupper Montney
• Drilled a discovery at the non-operated Ocotillo #1 exploration well in Mississippi Canyon 40 in the Gulf of Mexico
• Repurchased $56 million of stock, or 1.4 million shares, at an average price of $41.03 per share
• Repurchased $50 million of senior notes due 2027 and 2028 in open market transactions
• Maintained quarterly dividend of $0.30 per share or $1.20 per share annualized

Subsequent to the second quarter:

• Revised capital allocation framework, progressing to Murphy 3.0, which increases shareholder returns while maintaining $1.0 billion total long-term debt goal
• Repurchased $44 million of stock, or 1.1 million shares, at an average price of $38.62 per share
• Increased share repurchase authorization by $500 million, with $800 million currently remaining
• Published the company’s sixth annual sustainability report

“We have made incredible progress advancing our priorities of Delever, Execute, Explore, Return since they were first announced more than three years ago. From outperformance across our onshore assets to continued execution offshore in the second quarter, we have generated ample cash flow to fund our operations and repurchase more than $50 million of stock and $50 million of long-term debt. I am pleased with our recent exploration success at the non-operated Ocotillo well in the Gulf of Mexico, and I look forward to drilling our two exploration wells in Vietnam beginning in the third quarter,” said Roger W. Jenkins, Chief Executive Officer. “Further, I am excited to announce today that we are moving into Murphy 3.0 of our capital allocation framework so that we may increase our shareholder returns primarily through share repurchases, while remaining focused on achieving our $1.0 billion total long-term debt goal.”

SECOND QUARTER 2024 RESULTS

The company recorded net income attributable to Murphy of $128 million, or $0.83 net income per diluted share, for the second quarter 2024. Adjusted net income, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, was $124 million, or $0.81 adjusted net income per diluted share for the same period. Details for second quarter results and an adjusted net income reconciliation can be found in the attached schedules.

Earnings before interest, taxes, depreciation and amortization (EBITDA) attributable to Murphy were $389 million. Earnings before interest, tax, depreciation, amortization and exploration expenses (EBITDAX) attributable to Murphy were $431 million. Adjusted EBITDA attributable to Murphy was $396 million. Adjusted EBITDAX attributable to Murphy was $438 million. Reconciliations for second quarter EBITDA, EBITDAX, adjusted EBITDA and adjusted EBITDAX can be found in the attached schedules.

Second quarter production averaged 181 MBOEPD and included 50 percent oil volumes, or 91 MBOPD. Onshore production was approximately 5.4 MBOEPD above guidance for the quarter primarily due to stronger well performance. This offset 2.4 MBOEPD of unplanned downtime in the Gulf of Mexico and 2.4 MBOEPD of additional downtime at non-operated Terra Nova.

Accrued capital expenditures (CAPEX) for second quarter 2024 totaled $292 million, excluding NCI. Details for second quarter production and CAPEX can be found in the attached schedules.

CAPITAL ALLOCATION FRAMEWORK

Murphy had approximately $1.1 billion of liquidity on June 30, 2024, with no borrowings on the $800 million senior unsecured credit facility and $334 million of cash and cash equivalents, inclusive of NCI.

Debt Reduction

During the second quarter, Murphy repurchased $50 million of senior notes in open market transactions, comprised of $26.5 million of 5.875 percent senior notes due 2027 and $23.5 million of 6.375 percent senior notes due 2028. As of June 30, 2024, Murphy’s total debt was $1.28 billion, and consisted of long-term, fixed-rate notes with a weighted average maturity of 7.8 years and a weighted average coupon of 6.2 percent.

Share Repurchases

During the second quarter, Murphy repurchased $56 million of stock, or 1.4 million shares, at an average price of $41.03 per share. Subsequent to second quarter, Murphy repurchased $44 million of stock, or 1.1 million shares, at an average price of $38.62 per share. Additionally, the Board of Directors increased the share repurchase authorization by $500 million.

As of August 7, 2024, Murphy had repurchased $150 million of stock in 2024, or 3.8 million shares, at an average price of $39.70 per share. Murphy currently has $800 million remaining under the share repurchase authorization and 150.1 million shares outstanding.

Accelerating Shareholder Returns

Murphy’s Board of Directors has approved a revision to the capital allocation framework that allows the company to move into Murphy 3.0 when the company reaches long-term debt of $1.3 billion, which it has achieved. Murphy will now allocate a minimum of 50 percent of adjusted free cash flow to shareholder returns, primarily through share buybacks. The remainder of adjusted free cash flow will be allocated to the balance sheet. Murphy is committed to maintaining a $1.0 billion total long-term debt goal, which it is forecast to achieve by mid-2025 assuming a $75 per barrel West Texas Intermediate price.

“We first announced our capital allocation framework in August 2022, which detailed our plans to reduce debt, build an industry-leading balance sheet and return capital to shareholders. Since that time, I am pleased that we have repurchased $300 million of stock and increased our dividend by 70 percent. Additionally, since year-end 2020 we have reduced debt by $1.75 billion, or 57 percent, and achieved $87 million in annual interest expense savings,” said Jenkins. “During this time, we have maintained a disciplined capital program, supporting existing asset development and exploration, proved reserve growth, acquisitions and a field development project. As we approach our $1.0 billion total long-term debt goal, we wanted to accelerate returns to our shareholders.”

OPERATIONS SUMMARY

Onshore

In the second quarter of 2024, the onshore business produced approximately 99 MBOEPD, which included 28 percent liquids volumes.

Eagle Ford Shale – Production averaged 28 MBOEPD with 71 percent oil volumes and 86 percent liquids volumes in the second quarter, which exceeded guidance by 1,700 BOEPD primarily due to wells producing above expectation. Murphy brought online 11 operated wells in Catarina and four non-operated wells in Tilden during the quarter.

Tupper Montney – During the second quarter, natural gas production averaged 400 million cubic feet per day (MMCFD), which exceeded guidance by 20 MMCFD primarily due to improved well performance. As planned, Murphy brought online 13 wells during the quarter, completing its 2024 program. During the quarter, Murphy achieved a record high peak gross production rate of 496 MMCFD.

Kaybob Duvernay – Production averaged 4 MBOEPD with 72 percent liquids volumes in the second quarter. Murphy brought online three operated wells in the second quarter as planned.

Offshore

Excluding NCI, in the second quarter of 2024, the offshore business produced approximately 81 MBOEPD, which included 83 percent oil.

Gulf of Mexico – Production averaged approximately 74 MBOEPD, consisting of 82 percent oil during the second quarter. Murphy drilled the operated Mormont #3 (Green Canyon 478) well, and brought online the operated Khaleesi #4 (Green Canyon 389) well and non-operated Lucius #11 (Keathley Canyon 919) well as planned during the quarter. The company also progressed the operated Neidermeyer #1 (Mississippi Canyon 208) sidetrack well and the non-operated Kodiak #3 (Mississippi Canyon 727) well workover, and both wells were brought online in the third quarter.

Canada – In the second quarter, production averaged 8 MBOEPD, consisting of 100 percent oil.

Vietnam – Murphy advanced its Lac Da Vang field development project during the second quarter and awarded facilities and pipeline contracts. The remaining major contracts are expected to be awarded by year-end 2024. The project remains on schedule to achieve first oil in late 2026.

EXPLORATION

Gulf of Mexico – During the quarter, Murphy drilled a discovery at the non-operated Ocotillo #1 (Mississippi Canyon 40) exploration well and found 100 feet of net pay across two zones. Murphy holds a 33.33 percent working interest in the well.

Also during the quarter, Murphy concluded drilling the non-operated Orange #1 (Mississippi Canyon 216) exploration well. The well encountered non-commercial hydrocarbons and has been plugged and abandoned. Approximately $26 million of the net well cost before tax was expensed in the second quarter. Murphy holds a 50 percent working interest in the well.

2024 CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE

Murphy maintains its 2024 accrued CAPEX range of $920 million to $1.02 billion. The company also maintains its full year 2024 production range of 180 to 188 MBOEPD, consisting of approximately 95 MBOPD oil and 105 MBOEPD liquids volumes, equating to 52 percent oil and 57 percent liquids volumes, respectively. Currently the company expects to be at the lower end of the production range due to operational impacts in the Gulf of Mexico. The development plan of an operated well in the Samurai field was altered to a single zone to maximize total field recovery. Additionally, extended operations at the planned Neidermeyer #1 sidetrack well delayed the rig from commencing a well workover in the Dalmatian field.

Production for third quarter 2024 is estimated to be in the range of 181.5 to 189.5 MBOEPD with 91.5 MBOPD, or approximately 50 percent, oil volumes. This range is impacted by 9.4 MBOEPD of total downtime, comprised of 3.9 MBOEPD of assumed Gulf of Mexico storm downtime, 2.9 MBOEPD of planned onshore downtime and 2.6 MBOEPD of planned Gulf of Mexico downtime. Both production and CAPEX guidance ranges exclude NCI.

Detailed guidance for the third quarter and full year 2024 is contained in the attached schedules.

FIXED PRICE FORWARD SALES CONTRACTS

Murphy maintains fixed price forward sales contracts in Canada to lessen its dependence on variable AECO prices. These contracts are for physical delivery of natural gas volumes at a fixed price, with no mark-to-market income adjustments. Details for the current fixed price contracts can be found in the attached schedules.

CONFERENCE CALL AND WEBCAST SCHEDULED FOR AUGUST 8, 2024

Murphy will host a conference call to discuss second quarter 2024 financial and operating results on Thursday, August 8, 2024, at 9:00 a.m. EDT. The call can be accessed either via the Internet through the events calendar on the Murphy Oil Corporation Investor Relations website at http://ir.murphyoilcorp.com or via telephone by dialing toll-free 800-717-1738, reservation number 55528. For additional information, please refer to the Second Quarter 2024 Earnings Presentation available under the News and Events section of the Investor Relations website.

FINANCIAL DATA

Summary financial data and operating statistics for second quarter 2024, with comparisons to the same period from the previous year, are contained in the attached schedules. Additionally, a schedule indicating the impacts of items affecting comparability of results between periods, a reconciliation of EBITDA, EBITDAX, adjusted EBITDA and adjusted EBITDAX between periods, as well as guidance for the third quarter and full year 2024, are also included.

¹In accordance with GAAP, Murphy reports the 100 percent interest, including a 20 percent noncontrolling interest (NCI), in its subsidiary, MP Gulf of Mexico, LLC (MP GOM). The GAAP financials include the NCI portion of revenue, costs, assets and liabilities and cash flows. Unless otherwise noted, the financial and operating highlights and metrics discussed in this news release, but not the accompanying schedules, exclude the NCI, thereby representing only the amounts attributable to Murphy.

CAPITAL ALLOCATION FRAMEWORK

This news release contains references to the company’s capital allocation framework and adjusted free cash flow. In an effort to accelerate shareholder returns, Murphy’s Board of Directors has approved a revision to the framework that allows the company to move into Murphy 3.0 when the company reaches long-term debt of $1.3 billion, which the company has achieved. As a result, the company will begin allocating a minimum of 50 percent of adjusted free cash flow to share buybacks and potential dividend increases, with the remainder of adjusted free cash flow allocated to the balance sheet as the company maintains the $1.0 billion total long-term debt goal.

Adjusted free cash flow is defined as cash flow from operations before working capital change, less capital expenditures, distributions to NCI and projected payments, quarterly dividend and accretive acquisitions.

ABOUT MURPHY OIL CORPORATION

As an independent oil and natural gas exploration and production company, Murphy Oil Corporation believes in providing energy that empowers people by doing right always, staying with it and thinking beyond possible. Murphy challenges the norm, taps into its strong legacy and uses its foresight and financial discipline to deliver inspired energy solutions. Murphy sees a future where it is an industry leader who is positively impacting lives for the next 100 years and beyond. Additional information can be found on the company’s website at www.murphyoilcorp.com.

FORWARD-LOOKING STATEMENTS

This news release 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 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 news release. Murphy Oil Corporation undertakes no duty to publicly update or revise any forward-looking statements.

NON-GAAP FINANCIAL MEASURES

This news release contains certain non-GAAP financial measures that management believes are useful tools for internal use and the investment community in evaluating Murphy Oil Corporation’s overall financial performance. These non-GAAP financial measures are broadly used to value and compare companies in the crude oil and natural gas industry. Not all companies define these measures in the same way. In addition, these non-GAAP financial measures are not a substitute for financial measures prepared in accordance with GAAP and should therefore be considered only as supplemental to such GAAP financial measures. Please see the attached schedules for reconciliations of the differences between the non-GAAP financial measures used in this news release and the most directly comparable GAAP financial measures.

MURPHY OIL CORPORATION SUMMARIZED CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)
	Three Months Ended June 30,								Six Months Ended June 30,
(Thousands of dollars, except per share amounts)		2024				2023				2024				2023
Revenues and other income
Revenue from production	$	797,510			$	799,836			$	1,592,113			$	1,596,067
Sales of purchased natural gas		3,497				13,014				3,742				56,751
Total revenue from sales to customers		801,007				812,850				1,595,855				1,652,818
Gain on sale of assets and other income		1,764				1,738				3,328				3,486
Total revenues and other income		802,771				814,588				1,599,183				1,656,304
Costs and expenses
Lease operating expenses		259,628				194,292				493,892				394,276
Severance and ad valorem taxes		10,417				12,765				20,503				24,205
Transportation, gathering and processing		53,470				59,868				110,023				113,790
Costs of purchased natural gas		2,987				9,657				3,147				41,926
Exploration expenses, including undeveloped lease amortization		42,677				115,793				87,106				125,975
Selling and general expenses		22,893				25,345				54,054				43,653
Depreciation, depletion and amortization		215,543				215,667				426,677				411,337
Accretion of asset retirement obligations		13,053				11,364				25,827				22,521
Other operating (income) expense		(2,219	)			4,960				5,047				16,948
Impairment of assets		—				—				34,528				—
Total costs and expenses		618,449				649,711				1,260,804				1,194,631
Operating income from continuing operations		184,322				164,877				338,379				461,673
Other income (loss)
Other income (loss)		26,245				(7,694	)			37,796				(7,767	)
Interest expense, net		(20,986	)			(29,856	)			(41,007	)			(58,711	)
Total other income (loss)		5,259				(37,550	)			(3,211	)			(66,478	)
Income from continuing operations before income taxes		189,581				127,327				335,168				395,195
Income tax expense		32,676				34,870				62,733				88,703
Income from continuing operations		156,905				92,457				272,435				306,492
Loss from discontinued operations, net of income taxes		(643	)			(602	)			(1,515	)			(323	)
Net income including noncontrolling interest		156,262				91,855				270,920				306,169
Less: Net income (loss) attributable to noncontrolling interest		28,523				(6,431	)			53,179				16,239
NET INCOME ATTRIBUTABLE TO MURPHY	$	127,739			$	98,286			$	217,741			$	289,930
INCOME (LOSS) PER COMMON SHARE – BASIC
Continuing operations	$	0.84			$	0.63			$	1.44			$	1.86
Discontinued operations		—				—				(0.01	)			—
Net income	$	0.84			$	0.63			$	1.43			$	1.86
INCOME (LOSS) PER COMMON SHARE – DILUTED
Continuing operations	$	0.83			$	0.62			$	1.43			$	1.84
Discontinued operations		—				—				(0.01	)			—
Net income	$	0.83			$	0.62			$	1.42			$	1.84
Cash dividends per common share	$	0.300				0.275			$	0.600				0.550
Average common shares outstanding (thousands)
Basic		152,153				156,127				152,409				155,976
Diluted		153,144				157,299				153,480				157,308

MURPHY OIL CORPORATION CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)
	Three Months Ended June 30,								Six Months Ended June 30,
(Thousands of dollars)		2024				2023				2024				2023
Operating Activities
Net income including noncontrolling interest	$	156,262			$	91,855			$	270,920			$	306,169
Adjustments to reconcile net income to net cash provided by continuing operations activities
Depreciation, depletion and amortization		215,543				215,667				426,677				411,337
Impairment of assets		—				—				34,528				—
Unsuccessful exploration well costs and previously suspended exploration costs		25,843				95,682				58,280				96,533
Deferred income tax expense		34,450				43,515				53,928				92,557
Accretion of asset retirement obligations		13,053				11,364				25,827				22,521
Long-term non-cash compensation		11,972				13,540				21,823				22,076
Amortization of undeveloped leases		2,985				2,716				5,778				5,369
Loss from discontinued operations		643				602				1,515				323
Contingent consideration payment		—				(15,609	)			—				(139,574	)
Mark-to-market loss on contingent consideration		—				3,175				—				7,113
Other operating activities, net		(18,578	)			(52,307	)			(33,959	)			(59,417	)
Net decrease (increase) in non-cash working capital		25,479				59,691				1,126				(15,340	)
Net cash provided by continuing operations activities		467,652				469,891				866,443				749,667
Investing Activities
Property additions and dry hole costs		(267,791	)			(349,434	)			(516,876	)			(694,753	)
Net cash required by investing activities		(267,791	)			(349,434	)			(516,876	)			(694,753	)
Financing Activities
Borrowings on revolving credit facility		100,000				100,000				200,000				200,000
Repayment of revolving credit facility		(100,000	)			(100,000	)			(200,000	)			(200,000	)
Retirement of debt		(50,000	)			—				(50,000	)			—
Repurchase of common stock		(55,887	)			—				(105,887	)			—
Cash dividends paid		(45,772	)			(42,942	)			(91,545	)			(85,867	)
Withholding tax on stock-based incentive awards		(28	)			(3	)			(25,298	)			(14,220	)
Distributions to noncontrolling interest		(38,209	)			(6,304	)			(61,210	)			(15,983	)
Finance lease obligation payments		(167	)			(157	)			(331	)			(296	)
Contingent consideration payment		—				(12,565	)			—				(60,243	)
Issue costs of debt facility		—				(3	)			—				(20	)
Net cash required by financing activities		(190,063	)			(61,974	)			(334,271	)			(176,629	)
Effect of exchange rate changes on cash and cash equivalents		391				(1,511	)			1,249				(893	)
Net increase (decrease) in cash and cash equivalents		10,189				56,972				16,545				(122,608	)
Cash and cash equivalents at beginning of period		323,430				312,383				317,074				491,963
Cash and cash equivalents at end of period	$	333,619			$	369,355			$	333,619			$	369,355

MURPHY OIL CORPORATION SCHEDULE OF ADJUSTED NET INCOME (LOSS) (unaudited)
	Three Months Ended June 30,								Six Months Ended June 30,
(Millions of dollars, except per share amounts)		2024				2023				2024				2023
Net income attributable to Murphy (GAAP) 1	$	127.7			$	98.3			$	217.7			$	289.9
Discontinued operations loss		0.6				0.6				1.5				0.3
Net income from continuing operations attributable to Murphy		128.3				98.9				219.2				290.2
Adjustments:
Impairment of assets		—				—				34.5				—
Write-off of previously suspended exploration well		—				17.1				26.1				17.1
Foreign exchange (gain) loss		(5.5	)			7.9				(16.0	)			8.3
Mark-to-market loss on contingent consideration		—				3.2				—				7.1
Total adjustments, before taxes		(5.5	)			28.2				44.6				32.5
Income tax expense (benefit) related to adjustments		1.4				(2.7	)			(8.8	)			(3.6	)
Total adjustments after taxes		(4.1	)			25.5				35.8				28.9
Adjusted net income from continuing operations attributable to Murphy (Non-GAAP)	$	124.2			$	124.4			$	255.0			$	319.1
Adjusted net income from continuing operations per average diluted share (Non-GAAP)	$	0.81			$	0.79			$	1.66			$	2.03
1 Excludes amounts attributable to a noncontrolling interest in MP Gulf of Mexico, LLC (MP GOM).

Non-GAAP Financial Measures

Presented above is a reconciliation of Net income to Adjusted net income from continuing operations attributable to Murphy. Adjusted net income excludes certain items that management believes affect the comparability of results between periods. Management believes this is important information to provide because it is used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. Adjusted net income is a non-GAAP financial measure and should not be considered a substitute for Net income as determined in accordance with accounting principles generally accepted in the United States of America.

The pretax and income tax impacts for adjustments in the above table are shown below by area of operation and geographical location, and exclude the share attributable to noncontrolling interests.

	Three Months Ended June 30, 2024											Six Months Ended June 30, 2024
(Millions of dollars)	Pretax				Tax			Net				Pretax				Tax				Net
Exploration & Production:
United States	$	—			$	—		$	—			$	60.6			$	(12.9	)		$	47.7
Corporate		(5.5	)			1.4			(4.1	)			(16.0	)			4.1				(11.9	)
Total adjustments	$	(5.5	)		$	1.4		$	(4.1	)		$	44.6			$	(8.8	)		$	35.8

MURPHY OIL CORPORATION SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION AND AMORTIZATION (EBITDA) (unaudited)
	Three Months Ended June 30,							Six Months Ended June 30,
(Millions of dollars)		2024			2023				2024			2023
Net income attributable to Murphy (GAAP) 1	$	127.7			$	98.3		$	217.7			$	289.9
Income tax expense		32.6				34.9			62.7				88.7
Interest expense, net		21.0				29.9			41.0				58.7
Depreciation, depletion and amortization expense 1		207.4				210.1			410.1				399.3
EBITDA attributable to Murphy (Non-GAAP)	$	388.7			$	373.2		$	731.5			$	836.6
Impairment of asset		—				—			34.5				—
Write-off of previously suspended exploration well		—				17.1			26.1				17.1
Accretion of asset retirement obligations 1		11.7				10.1			23.1				20.0
Foreign exchange (gain) loss		(5.4	)			7.9			(15.9	)			8.3
Mark-to-market loss on contingent consideration		—				3.2			—				7.1
Discontinued operations loss		0.6				0.6			1.5				0.3
Adjusted EBITDA attributable to Murphy (Non-GAAP)	$	395.6			$	412.1		$	800.8			$	889.4
1 Excludes amounts attributable to a noncontrolling interest in MP GOM.

Non-GAAP Financial Measures

Presented above is a reconciliation of Net income to Earnings before interest, taxes, depreciation and amortization (EBITDA) and Adjusted EBITDA. Management believes EBITDA and Adjusted EBITDA are important information to provide because they are used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. EBITDA and Adjusted EBITDA are non-GAAP financial measures and should not be considered a substitute for Net income or Cash provided by operating activities as determined in accordance with accounting principles generally accepted in the United States of America.

MURPHY OIL CORPORATION SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION AND AMORTIZATION AND EXPLORATION (EBITDAX) (unaudited)
	Three Months Ended June 30,							Six Months Ended June 30,
(Millions of dollars)		2024			2023				2024			2023
Net income attributable to Murphy (GAAP) 1	$	127.7			$	98.3		$	217.7			$	289.9
Income tax expense		32.6				34.9			62.7				88.7
Interest expense, net		21.0				29.9			41.0				58.7
Depreciation, depletion and amortization expense 1		207.4				210.1			410.1				399.3
EBITDA attributable to Murphy (Non-GAAP)		388.7				373.2			731.5				836.6
Exploration expenses 1		42.7				89.5			87.1				99.7
EBITDAX attributable to Murphy (Non-GAAP)		431.4				462.7			818.6				936.3
Impairment of asset		—				—			34.5				—
Accretion of asset retirement obligations 1		11.7				10.1			23.1				20.0
Foreign exchange (gain) loss		(5.4	)			7.9			(15.9	)			8.3
Mark-to-market loss on contingent consideration		—				3.2			—				7.1
Discontinued operations loss		0.6				0.6			1.5				0.3
Adjusted EBITDAX attributable to Murphy (Non-GAAP)	$	438.3			$	484.5		$	861.8			$	972.0
1 Excludes amounts attributable to a noncontrolling interest in MP GOM.

Non-GAAP Financial Measures

Presented above is a reconciliation of Net income to Earnings before interest, taxes, depreciation and amortization, and exploration expenses (EBITDAX) and Adjusted EBITDAX. Management believes EBITDAX and Adjusted EBITDAX are important information to provide because they are used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. EBITDAX and Adjusted EBITDAX are non-GAAP financial measures and should not be considered a substitute for Net income or Cash provided by operating activities as determined in accordance with accounting principles generally accepted in the United States of America.

MURPHY OIL CORPORATION FUNCTIONAL RESULTS OF OPERATIONS (unaudited)
	Three Months Ended June 30, 2024					Three Months Ended June 30, 2023
(Millions of dollars)	Revenues		Income (Loss)			Revenues		Income (Loss)
Exploration and production
United States 1	$	679.5	$	185.7		$	696.2	$	168.9
Canada		119.0		8.9			118.3		2.5
Other		4.3		(10.1	)		—		(32.3	)
Total exploration and production		802.8		184.5			814.5		139.1
Corporate		—		(27.7	)		0.1		(46.6	)
Income from continuing operations		802.8		156.8			814.6		92.5
Discontinued operations, net of tax		—		(0.6	)		—		(0.6	)
Net income including noncontrolling interest	$	802.8	$	156.2		$	814.6	$	91.9
Net income attributable to Murphy			$	127.7				$	98.3

	Six Months Ended June 30, 2024					Six Months Ended June 30, 2023
(Millions of dollars)	Revenues		Income (Loss)			Revenues		Income (Loss)
Exploration and production
United States 1	$	1,339.1	$	320.2		$	1,378.5	$	394.9
Canada		255.9		28.3			274.1		24.4
Other		4.2		(20.9	)		3.6		(37.6	)
Total exploration and production		1,599.2		327.6			1,656.2		381.7
Corporate		—		(55.2	)		0.1		(75.2	)
Income from continuing operations		1,599.2		272.4			1,656.3		306.5
Discontinued operations, net of tax		—		(1.5	)		—		(0.3	)
Net income including noncontrolling interest	$	1,599.2	$	270.9		$	1,656.3	$	306.2
Net income attributable to Murphy			$	217.7				$	289.9
1 Includes amounts attributable to a noncontrolling interest in MP GOM.

MURPHY OIL CORPORATION OIL AND GAS OPERATING RESULTS (unaudited) THREE MONTHS ENDED JUNE 30, 2024, AND 2023
(Millions of dollars)	United States1			Canada			Other			Total
Three Months Ended June 30, 2024
Oil and gas sales and other operating revenues	$	679.5		$	115.5		$	4.3		$	799.3
Sales of purchased natural gas		—			3.5			—			3.5
Lease operating expenses		212.3			46.8			0.5			259.6
Severance and ad valorem taxes		10.0			0.4			—			10.4
Transportation, gathering and processing		34.2			19.3			—			53.5
Costs of purchased natural gas		—			2.9			—			2.9
Depreciation, depletion and amortization		175.0			37.0			0.9			212.9
Accretion of asset retirement obligations		10.7			2.2			0.2			13.1
Exploration expenses
Dry holes and previously suspended exploration costs		25.9			—			—			25.9
Geological and geophysical		3.1			0.1			5.0			8.2
Other exploration		1.6			—			4.1			5.7
Undeveloped lease amortization		2.1			—			0.9			3.0
Total exploration expenses		32.7			0.1			10.0			42.8
Selling and general expenses		(3.4	)		4.5			1.8			2.9
Other		(21.5	)		1.1			0.2			(20.2	)
Results of operations before taxes		229.5			4.7			(9.3	)		224.9
Income tax provisions (benefits)		43.8			(4.2	)		0.8			40.4
Results of operations (excluding Corporate segment)	$	185.7		$	8.9		$	(10.1	)	$	184.5
Three Months Ended June 30, 2023
Oil and gas sales and other operating revenues	$	696.2		$	105.3		$	—		$	801.5
Sales of purchased natural gas		—			13.0			—			13.0
Lease operating expenses		156.5			37.5			0.1			194.1
Severance and ad valorem taxes		12.4			0.4			—			12.8
Transportation, gathering and processing		39.9			20.1			—			60.0
Costs of purchased natural gas		—			9.7			—			9.7
Depreciation, depletion and amortization		178.0			35.0			—			213.0
Accretion of asset retirement obligations		9.3			1.9			0.1			11.3
Exploration expenses
Dry holes and previously suspended exploration costs		79.8			—			15.8			95.6
Geological and geophysical		0.4			0.1			10.0			10.5
Other exploration		1.7			—			5.3			7.0
Undeveloped lease amortization		2.1			—			0.6			2.7
Total exploration expenses		84.0			0.1			31.7			115.8
Selling and general expenses		(1.9	)		4.7			2.6			5.4
Other		0.5			5.4			1.4			7.3
Results of operations before taxes		217.5			3.5			(35.9	)		185.1
Income tax provisions (benefits)		48.6			1.0			(3.6	)		46.0
Results of operations (excluding Corporate segment)	$	168.9		$	2.5		$	(32.3	)	$	139.1
1 Includes amounts attributable to a noncontrolling interest in MP GOM.

MURPHY OIL CORPORATION OIL AND GAS OPERATING RESULTS (unaudited) SIX MONTHS ENDED JUNE 30, 2024, AND 2023
(Millions of dollars)	United States1			Canada		Other			Total
Six Months Ended June 30, 2024
Oil and gas sales and other operating revenues	$	1,339.1		$	252.2	$	4.2		$	1,595.5
Sales of purchased natural gas		—			3.7		—			3.7
Lease operating expenses		398.9			94.3		0.7			493.9
Severance and ad valorem taxes		19.8			0.7		—			20.5
Transportation, gathering and processing		70.8			39.2		—			110.0
Costs of purchased natural gas		—			3.1		—			3.1
Depreciation, depletion and amortization		349.0			71.3		0.9			421.2
Impairment of assets		34.5			—		—			34.5
Accretion of asset retirement obligations		21.1			4.3		0.4			25.8
Exploration expenses
Dry holes and previously suspended exploration costs		57.1			—		1.2			58.3
Geological and geophysical		3.7			0.1		5.8			9.6
Other exploration		3.0			0.1		10.4			13.5
Undeveloped lease amortization		4.1			—		1.7			5.8
Total exploration expenses		67.9			0.2		19.1			87.2
Selling and general expenses		(3.6	)		9.6		3.0			9.0
Other		(14.1	)		2.2		0.5			(11.4	)
Results of operations before taxes		394.8			31.0		(20.4	)		405.4
Income tax provisions		74.6			2.7		0.5			77.8
Results of operations (excluding Corporate segment)	$	320.2		$	28.3	$	(20.9	)	$	327.6
Six Months Ended June 30, 2023
Oil and gas sales and other operating revenues	$	1,378.5		$	217.2	$	3.6		$	1,599.3
Sales of purchased natural gas		—			56.8		—			56.8
Lease operating expenses		319.2			74.3		0.7			394.2
Severance and ad valorem taxes		23.5			0.7		—			24.2
Transportation, gathering and processing		77.3			36.5		—			113.8
Costs of purchased natural gas		—			41.9		—			41.9
Depreciation, depletion and amortization		338.2			66.7		0.9			405.8
Accretion of asset retirement obligations		18.4			3.9		0.2			22.5
Exploration expenses
Dry holes and previously suspended exploration costs		79.6			—		16.9			96.5
Geological and geophysical		0.7			0.1		10.5			11.3
Other exploration		3.3			0.1		9.4			12.8
Undeveloped lease amortization		4.1			0.1		1.2			5.4
Total exploration expenses		87.7			0.3		38.0			126.0
Selling and general expenses		4.5			7.1		2.8			14.4
Other		9.9			9.7		1.4			21.0
Results of operations before taxes		499.8			32.9		(40.4	)		492.3
Income tax provisions (benefits)		104.9			8.5		(2.8	)		110.6
Results of operations (excluding Corporate segment)	$	394.9		$	24.4	$	(37.6	)	$	381.7
1 Includes amounts attributable to a noncontrolling interest in MP GOM.

MURPHY OIL CORPORATION PRODUCTION-RELATED EXPENSES (unaudited)
	Three Months Ended June 30,						Six Months Ended June 30,
(Dollars per barrel of oil equivalents sold)	2024			2023			2024			2023
United States – Onshore
Lease operating expense	$	14.61		$	11.45		$	14.14		$	13.03
Severance and ad valorem taxes		3.73			3.68			3.66			3.92
Depreciation, depletion and amortization expense		29.64			26.44			29.04			26.30
United States – Offshore1
Lease operating expense	$	23.58		$	14.72		$	21.96		$	14.71
Severance and ad valorem taxes		0.07			0.07			0.06			0.08
Depreciation, depletion and amortization expense		13.44			11.44			13.45			11.33
Canada – Onshore
Lease operating expense	$	5.43		$	6.01		$	5.46		$	6.38
Severance and ad valorem taxes		0.06			0.07			0.06			0.07
Depreciation, depletion and amortization expense		4.76			5.65			4.86			5.82
Canada – Offshore
Lease operating expense	$	22.60		$	10.96		$	24.43		$	12.60
Depreciation, depletion and amortization expense		12.00			9.48			10.71			9.40
Total E&P continuing operations1
Lease operating expense	$	15.27		$	11.21		$	14.83		$	11.76
Severance and ad valorem taxes		0.61			0.74			0.62			0.72
Depreciation, depletion and amortization expense 2		12.52			12.28			12.64			12.10
Total oil and gas continuing operations – excluding noncontrolling interest
Lease operating expense 3	$	15.09		$	11.02		$	14.69		$	11.58
Severance and ad valorem taxes		0.64			0.76			0.64			0.75
Depreciation, depletion and amortization expense 2		12.52			12.37			12.65			12.19

1	Includes amounts attributable to a noncontrolling interest in MP GOM.
2	Excludes expenses attributable to the Corporate segment.
3	Lease operating expense per barrel of oil equivalent sold for total oil and gas continuing operations, excluding NCI and workover costs, was $10.42 and $10.02 for the three months ended June 30, 2024 and 2023, respectively and $10.58 and $10.66 for the six months ended June 30, 2024 and 2023.

MURPHY OIL CORPORATION CAPITAL EXPENDITURES (unaudited)
	Three Months Ended June 30,						Six Months Ended June 30,
(Millions of dollars)	2024			2023			2024			2023
Exploration and production
United States 1	$	225.8		$	245.5		$	414.3		$	500.2
Canada		42.2			75.4			109.5			143.5
Other		21.2			37.8			32.5			44.7
Total		289.2			358.7			556.3			688.4
Corporate		4.2			3.6			8.4			9.9
Total capital expenditures - continuing operations 1		293.4			362.3			564.7			698.3
Less: capital expenditures attributable to noncontrolling interest		1.6			29.9			8.9			38.8
Total capital expenditures - continuing operations attributable to Murphy 2		291.8			332.4			555.8			659.5
Charged to exploration expenses 3
United States 1		30.6			81.9			63.8			83.6
Canada		0.1			0.1			0.2			0.2
Other		9.1			31.2			17.4			36.8
Total charged to exploration expenses - continuing operations 1,3		39.8			113.2			81.4			120.6
Less: charged to exploration expenses attributable to noncontrolling interest		—			26.3			—			26.3
Total charged to exploration expenses - continuing operations attributable to Murphy 4		39.8			86.9			81.4			94.3
Total capitalized - continuing operations attributable to Murphy	$	252.0		$	245.5		$	474.4		$	565.2

1	Includes amounts attributable to a noncontrolling interest in MP GOM.
2	For the three months ended June 30, 2024, total capital expenditures attributable to Murphy, excluding acquisition-related costs of nil (2023: $32.3 million), is $291.8 million (2023: $300.1 million). For the six months ended June 30, 2024, total capital expenditures attributable to Murphy, excluding acquisition-related costs of nil (2023: $32.3 million), is $555.8 million (2023: $627.2 million).
3	For the three-month and six-month ended June 30, 2024, total charged to exploration expense attributable to Murphy, excludes amortization of undeveloped leases of $3.0 million (2023: $2.7 million) and $5.8 million (2023 $5.4 million), respectively.
4	For the three months ended June 30, 2024, total charged to exploration expense attributable to Murphy, excluding previously suspended exploration costs of nil (2023: $17.1 million), is $39.8 million (2023: $69.8 million). For the six months ended June 30, 2024, total charged to exploration expense excluding previously suspended exploration costs of $26.1 million (2023: $17.1 million), is $55.3 million (2023: $77.2 million).

MURPHY OIL CORPORATION CONSOLIDATED BALANCE SHEETS (unaudited)
(Thousands of dollars)	June 30, 2024				December 31, 2023
ASSETS
Current assets
Cash and cash equivalents	$	333,619			$	317,074
Accounts receivable, net		336,965				343,992
Inventories		51,811				54,454
Prepaid expenses		35,053				36,674
Total current assets		757,448				752,194
Property, plant and equipment, at cost less accumulated depreciation, depletion and amortization		8,214,554				8,225,197
Operating lease assets		885,582				745,185
Deferred income taxes		—				435
Deferred charges and other assets		36,134				43,686
Total assets	$	9,893,718			$	9,766,697
LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt, finance lease	$	739			$	723
Accounts payable		507,753				446,891
Income taxes payable		20,001				21,007
Other taxes payable		29,669				29,339
Operating lease liabilities		254,780				207,840
Other accrued liabilities		114,690				140,745
Total current liabilities		927,632				846,545
Long-term debt, including finance lease obligation		1,279,310				1,328,352
Asset retirement obligations		923,696				904,051
Deferred credits and other liabilities		291,110				309,605
Non-current operating lease liabilities		645,043				551,845
Deferred income taxes		324,379				276,646
Total liabilities	$	4,391,170			$	4,217,044
Equity
Common Stock, par $1.00	$	195,101			$	195,101
Capital in excess of par value		826,861				880,297
Retained earnings		6,672,275				6,546,079
Accumulated other comprehensive loss		(571,645	)			(521,117	)
Treasury stock		(1,798,872	)			(1,737,566	)
Murphy Shareholders' Equity		5,323,720				5,362,794
Noncontrolling interest		178,828				186,859
Total equity		5,502,548				5,549,653
Total liabilities and equity	$	9,893,718			$	9,766,697

MURPHY OIL CORPORATION PRODUCTION SUMMARY (unaudited)
	Three Months Ended June 30,						Six Months Ended June 30,
(Barrels per day unless otherwise noted)	2024			2023			2024			2023
Net crude oil and condensate
United States - Onshore	19,873			26,880			20,127			23,100
United States - Offshore 1	66,818			72,022			66,448			73,850
Canada - Onshore	2,978			3,097			2,617			3,190
Canada - Offshore	7,506			2,913			6,885			2,687
Other	245			212			245			240
Total net crude oil and condensate	97,420			105,124			96,322			103,067
Net natural gas liquids
United States - Onshore	4,125			4,328			4,145			4,243
United States - Offshore 1	4,505			6,291			4,596			6,316
Canada - Onshore	494			558			474			691
Total net natural gas liquids	9,124			11,177			9,215			11,250
Net natural gas – thousands of cubic feet per day
United States - Onshore	23,197			24,195			23,714			24,178
United States - Offshore 1	57,762			69,904			55,462			72,539
Canada - Onshore	406,856			352,265			381,155			328,878
Total net natural gas	487,815			446,364			460,331			425,595
Total net hydrocarbons - including NCI 2,3	187,847			190,695			182,259			185,250
Noncontrolling interest
Net crude oil and condensate – barrels per day	(6,717	)		(5,949	)		(6,608	)		(6,279	)
Net natural gas liquids – barrels per day	(217	)		(204	)		(214	)		(218	)
Net natural gas – thousands of cubic feet per day	(2,003	)		(1,751	)		(2,039	)		(2,051	)
Total noncontrolling interest 2,3	(7,268	)		(6,445	)		(7,162	)		(6,839	)
Total net hydrocarbons - excluding NCI 2,3	180,579			184,250			175,097			178,411

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.

MURPHY OIL CORPORATION WEIGHTED AVERAGE PRICE SUMMARY (unaudited)
	Three Months Ended June 30,						Six Months Ended June 30,
	2024			2023			2024			2023
Crude oil and condensate – dollars per barrel
United States - Onshore	$	80.71		$	72.39		$	78.76		$	73.47
United States - Offshore 1		81.67			73.82			79.61			73.54
Canada - Onshore 2		72.25			68.50			70.24			71.46
Canada - Offshore 2		84.34			80.14			85.25			79.26
Other 2		100.92			—			96.43			89.05
Natural gas liquids – dollars per barrel
United States - Onshore		19.48			16.60			20.08			19.28
United States - Offshore 1		22.77			20.16			23.56			22.89
Canada - Onshore 2		35.46			29.90			35.16			39.82
Natural gas – dollars per thousand cubic feet
United States - Onshore		1.59			1.88			1.77			2.19
United States - Offshore 1		2.00			2.33			2.32			2.81
Canada - Onshore 2		1.37			1.85			1.68			2.17
1 Prices include the effect of noncontrolling interest in MP GOM. 2 U.S. dollar equivalent.

MURPHY OIL CORPORATION FIXED PRICE FORWARD SALES AND COMMODITY HEDGE POSITIONS AS OF AUGUST 6, 2024 (unaudited)

Volumes (MMcf/d)

Price/MCF

Remaining Period

Area

Commodity

Type 1

Start Date

End Date

Canada

Natural Gas

Fixed price forward sales

162

C$2.39

7/1/2024

12/31/2024

Canada

Natural Gas

Fixed price forward sales

28

C$2.76

1/1/2025

12/31/2025

Canada

Natural Gas

Fixed price forward sales

50

C$3.03

1/1/2026

12/31/2026

Canada

Natural Gas

Fixed price forward sales

25

US$1.98

7/1/2024

10/31/2024

Canada

Natural Gas

Fixed price forward sales

15

US$1.98

11/1/2024

12/31/2024

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

MURPHY OIL CORPORATION THIRD QUARTER 2024 GUIDANCE
	Oil BOPD		NGLs BOPD		Gas MCFD		Total BOEPD
Production – net
United States – Eagle Ford Shale	23,800		4,400		25,200		32,400
– Gulf of Mexico excluding NCI	54,900		4,300		55,400		68,400
Canada – Tupper Montney	400		—		417,500		70,000
– Kaybob Duvernay	2,700		600		9,600		4,900
– Offshore	9,600		—		—		9,600
Other	200		—		—		200
Total net production (BOEPD) - excluding NCI 1	181,500 to 189,500
Exploration expense ($ millions)	$34
FULL YEAR 2024 GUIDANCE
Total net production (BOEPD) - excluding NCI 2	180,000 to 188,000
Capital expenditures – excluding NCI ($ millions) 3	$920 to $1,020
¹ Excludes noncontrolling interest of MP GOM of 6,300 BOPD of oil, 300 BOPD of NGLs, and 2,400 MCFD gas.
² Excludes noncontrolling interest of MP GOM of 6,600 BOPD of oil, 300 BOPD of NGLs, and 2,500 MCFD gas.
³ Excludes noncontrolling interest of MP GOM of $22 million.

 

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The Murphy Oil Stock at the time of publication of the news with a raise of +1,20 % to 33,60EUR on Tradegate stock exchange (07. August 2024, 22:26 Uhr).