mur-20250806

EXHIBIT 99.1

MURPHY OIL CORPORATION ANNOUNCES SECOND QUARTER RESULTS

Delivered Sequential Increase in Production to 190 MBOEPD and 90 MBOPD

Returned Over $190 Million to Shareholders in First Half 2025

HOUSTON, Texas, August 6, 2025 – Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the second quarter ended June 30, 2025.

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


(Millions of dollars, except volumes and per share amounts)	Three months ended June 30, 2025
Net income attributable to Murphy 1	$	22.3
Net income attributable to Murphy per common share - Diluted	$	0.16
Adjusted net income from continuing operations attributable to Murphy (Non-GAAP) 2	$	38.5
Adjusted net income from continuing operations per average common share -Diluted (Non-GAAP) 2	$	0.27
Adjusted EBITDA attributable to Murphy (Non-GAAP) 2	$	334.9
Adjusted EBITDAX attributable to Murphy (Non-GAAP) 2	$	345.2
Net cash provided by continuing operations activities	$	358.1
Free cash flow (Non-GAAP) 2	$	17.8

Oil production, net (BOPD) 1, 3	89,530
Total production, net (BOEPD) 1, 3	189,677
Accrued capital expenditures (CAPEX) 1	$	250.8
Lease operating expense ($/BOE) 1, 4	$	11.80

1 From continuing operations and excludes amounts attributable to a noncontrolling interest in MP Gulf of Mexico, LLC (MP GOM).

2 Adjusted net income from continuing operations attributable to Murphy, adjusted earnings before interest, taxes, depreciation and amortization attributable to Murphy (adjusted EBITDA), adjusted EBITDA less exploration expense attributable to Murphy (adjusted EBITDAX), and free cash flow are non-GAAP financial measures and are not prepared in accordance with U.S. generally accepted accounting principles (GAAP). Reconciliations can be found in the attached schedules.

3 Barrels of oil per day (BOPD) and barrels of oil equivalent per day (BOEPD).

4 Lease operating expense per barrel of oil equivalent sold for total oil and gas continuing operations.

Highlights for the second quarter include:

•Delivered sequential increase in production to 190,000 BOEPD and 90,000 BOPD; production outperformed high-end of guidance on strong new well productivity

•Returned $46 million to shareholders through quarterly dividend

•Reaffirmed full year CAPEX guidance at the midpoint of the range; full year total company production now trending at the midpoint of the range

Subsequent to the second quarter:

•Declared quarterly dividend of $0.325 per share or $1.30 per share annualized

•Closed Eagle Ford Shale acquisition for $23 million on July 1st

•Signed rig contract for Côte d’Ivoire three-well exploration program

•Published the 2025 Sustainability Report

“I am very pleased with our solid operational results in the second quarter which were achieved through strong new onshore well performance, continued Gulf of America workover progress, and field development execution at Lac Da Vang (Golden Camel). It’s an exciting time at Murphy as we look ahead to significant exploration and appraisal catalysts in the second half of the year,” said Eric M. Hambly, President and Chief Executive Officer. “In addition, this quarter we have introduced a Quarterly Stockholder Update which provides deeper insights and leadership perspectives on our business.”

RETURN OF CAPITAL

In the second quarter of 2025, return of capital totaled $46 million through the quarterly dividend. Through the first half of 2025, Murphy has returned $193 million to shareholders, which includes $100 million of share repurchases and $93 million in dividends.

The company had $550 million remaining under its share repurchase authorization and 142.7 million shares outstanding as of June 30, 2025.

FINANCIAL POSITION

Murphy had approximately $1.5 billion of liquidity on June 30, 2025, comprised of $1.15 billion undrawn under the $1.35 billion senior unsecured credit facility and $380 million of cash and cash equivalents, inclusive of NCI.

As of June 30, 2025, Murphy’s total debt of $1.48 billion was comprised of long-term, fixed-rate notes and $200 million drawn under the senior unsecured credit facility. The fixed-rate notes had a weighted average maturity of 8.9 years and a weighted average coupon of 6.1 percent.

ONSHORE OPERATIONS SUMMARY

In the second quarter of 2025, the onshore business produced approximately 118 MBOEPD, which included 31 percent liquids volumes.


Onshore	Oil Production (BOPD)	Total Production (BOEPD)	New Wells Online (Operated)
Eagle Ford Shale	29,000	39,000	24
Tupper Montney	—	75,000	5
Kaybob Duvernay	2,000	4,000	—

OFFSHORE OPERATIONS SUMMARY

Excluding NCI, in the second quarter of 2025, the offshore business produced approximately 72 MBOEPD, which included 82 percent oil.


Offshore	Oil production (BOPD)	Total Production (BOEPD)
Gulf of America	53,000	66,000
Canada	6,000	6,000

Gulf of America – Murphy completed the Samurai #3 workover and returned the well to production early in the second quarter. The Khaleesi #2 workover was completed and returned to production early in the third quarter.

Vietnam – During the second quarter, Murphy continued to advance the Lac Da Vang (Golden Camel) field development and the project remains on schedule for first oil in the second half of 2026. The total project has now achieved 2.5 million work hours with zero Lost Time Injuries.

2025 CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE

The table below illustrates third quarter 2025 production guidance by area.


3Q 2025 Guidance
Producing Asset	Oil (BOPD)	NGLs (BOPD)	Natural Gas (MCFD)	Total (BOEPD)
Eagle Ford Shale	33,200	6,200	33,500	45,000
Gulf of America, excl. NCI	45,600	3,600	46,800	57,000
Tupper Montney	200	—	450,800	75,300
Kaybob Duvernay	4,500	500	8,500	6,400
Offshore Canada	5,000	—	—	5,000
Other	300	—	—	300

Total Net Production, excl. NCI 1 (BOEPD)		185,000 to 193,000
Exploration Expense ($ MM)		$40

Full Year 2025 Guidance
Total Net Production, excl. NCI 2 (BOEPD)		174,500 to 182,500
Capital Expenditures, excl. NCI 3 ($ MM)		$1,135 to $1,285

¹ Excludes noncontrolling interest of MP GOM of 5,300 BOPD of oil, 300 BOPD of NGLs and 1,900 MCFD natural gas
² Excludes noncontrolling interest of MP GOM of 5,600 BOPD of oil, 200 BOPD of NGLs and 1,700 MCFD natural gas
³ Excludes noncontrolling interest of MP GOM of $40 million

The table below details the 2025 CAPEX plan by quarter.


2025 CAPEX 1 by Quarter ($ MM)
1Q 2025A	2Q 2025A	3Q 2025E	4Q 2025E	FY 2025E
$4032	$251	$2603	$296	$1,2102,3

1 Accrual CAPEX, based on midpoint of guidance range and excluding NCI

2 Includes net acquisition CAPEX of $104 million for the Pioneer FPSO and $1.4 million

for non-operated working interests near the Zephyrus field in the Gulf of America

3 Excludes $23 million Eagle Ford Shale acquisition

The table below details the 2025 onshore well delivery plan by quarter.


2025 Onshore Wells Online
	1Q 2025A	2Q 2025A	3Q 2025E	4Q 2025E	2025E Total
Eagle Ford Shale	-	24	10	-	34
Kaybob Duvernay	-	-	4	-	4
Tupper Montney	5	5	-	-	10
Non-Op Eagle Ford Shale	1	10	7	-	18

Note: All well counts are shown gross. Eagle Ford Shale non-operated working interest

averages 21 percent.

CONFERENCE CALL AND WEBCAST SCHEDULED FOR AUGUST 7, 2025

Murphy will host a conference call to discuss second quarter 2025 financial and operating results on Thursday, August 7, 2025, at 9:00 a.m. ET. 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 1-800-717-1738, reservation number 30769. For additional information, please refer to the Second Quarter 2025 Earnings Presentation and Quarterly Stockholder Update available under the News and Events section of the Investor Relations website.

FINANCIAL DATA

Summary financial data and operating statistics for second quarter 2025, 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 and a reconciliation of the non-GAAP financial measures of adjusted net income from continuing operations attributable to Murphy, EBITDA, EBITDAX, adjusted EBITDA, adjusted EBITDAX, free cash flow and adjusted free cash flow to the most directly comparable GAAP financial measures for such periods are also included.

ABOUT MURPHY OIL CORPORATION

Murphy Oil Corporation is an independent oil and natural gas company with a multi-basin onshore and offshore portfolio and significant exploration opportunities. The company has more than a century-long history of demonstrating strong execution and innovative, full-cycle development capabilities with a focus on value creation that drives shareholder returns. Murphy’s foresight and financial discipline, along with its culture of adaptability and accountability, will allow the company to continue its outstanding legacy and exceptional reputation. The company’s current operations include extensive inventory located onshore in the Eagle Ford Shale, Tupper Montney and Kaybob Duvernay, as well as offshore in the Gulf of America and Canada. Murphy also strives to create long-term shareholder value through offshore exploration and development in the Gulf of America, Vietnam and Côte d’Ivoire. 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 natural 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 US or global capital markets, credit markets, banking system or economies in general, including inflation, trade policies, tariffs and other trade restrictions. 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 US 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 US generally accepted accounting principles (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.

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.


Investor Contacts:
[email protected]


Kyle Sahni, 281-675-9369
Beth Heller, 281-675-9363

MURPHY OIL CORPORATION

CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(Thousands of dollars, except per share amounts)	2025		2024		2025		2024
Revenues and other income
Revenue from production	$	683,065	$	797,510	$	1,355,795	$	1,592,113
Sales of purchased natural gas	—		3,497		—		3,742
Total revenue from sales to customers	683,065		801,007		1,355,795		1,595,855
Gain on derivative instruments	10,808		—		1,349		—
Gain on sale of assets and other operating income	1,697		1,764		4,137		3,328
Total revenues and other income	695,570		802,771		1,361,281		1,599,183
Costs and expenses
Lease operating expenses	215,554		259,628		420,633		493,892
Severance and ad valorem taxes	10,828		10,417		19,478		20,503
Transportation, gathering and processing	54,070		53,470		102,921		110,023
Costs of purchased natural gas	—		2,987		—		3,147
Exploration expenses, including undeveloped lease amortization	10,399		42,677		24,887		87,106
Selling and general expenses	36,919		22,893		67,834		54,054

Depreciation, depletion and amortization	259,324		215,543		453,484		426,677
Accretion of asset retirement obligations	14,432		13,053		28,477		25,827
Impairment of assets	—		—		—		34,528
Other operating expense (income)	1,833		(2,219)		7,462		5,047
Total costs and expenses	603,359		618,449		1,125,176		1,260,804
Operating income from continuing operations	92,211		184,322		236,105		338,379
Other income (loss)
Other income (loss)	(32,304)		26,245		(29,902)		37,796
Interest expense, net	(25,053)		(20,986)		(48,576)		(41,007)
Total other income (loss)	(57,357)		5,259		(78,478)		(3,211)
Income from continuing operations before income taxes	34,854		189,581		157,627		335,168
Income tax expense	1,032		32,676		33,754		62,733
Income from continuing operations	33,822		156,905		123,873		272,435
Income (loss) from discontinued operations, net of income taxes	1,302		(643)		669		(1,515)
Net income including noncontrolling interest	35,124		156,262		124,542		270,920
Less: Net income attributable to noncontrolling interest	12,844		28,523		29,226		53,179
NET INCOME ATTRIBUTABLE TO MURPHY	$	22,280	$	127,739	$	95,316	$	217,741
NET INCOME (LOSS) PER COMMON SHARE – BASIC
Continuing operations	$	0.15	$	0.84	$	0.66	$	1.44
Discontinued operations	0.01		—		—		(0.01)
Net income	$	0.16	$	0.84	$	0.66	$	1.43
NET INCOME (LOSS) PER COMMON SHARE – DILUTED
Continuing operations	$	0.15	$	0.83	$	0.66	$	1.43
Discontinued operations	0.01		—		—		(0.01)
Net income	$	0.16	$	0.83	$	0.66	$	1.42
Cash dividends per common share	$	0.325	$	0.300	$	0.650	$	0.600
Average common shares outstanding (thousands)
Basic	142,721		152,153		143,502		152,409
Diluted	143,216		153,144		144,144		153,480

MURPHY OIL CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(Thousands of dollars)	2025		2024		2025		2024
Operating Activities
Net income including noncontrolling interest	$	35,124	$	156,262	$	124,542	$	270,920
Adjustments to reconcile net income to net cash provided by continuing operations activities

Depreciation, depletion and amortization	259,324		215,543		453,484		426,677
Accretion of asset retirement obligations	14,432		13,053		28,477		25,827
Long-term non-cash compensation	12,111		11,972		22,016		21,823
Deferred income tax expense	4,873		34,450		21,216		53,928
Amortization of undeveloped leases	2,255		2,985		3,909		5,778
Mark-to-market (gain) loss on derivative instruments	(10,287)		—		(1,371)		—
Unsuccessful exploration well costs and previously suspended exploration costs	(966)		25,843		(776)		58,280
(Income) loss from discontinued operations	(1,302)		643		(669)		1,515
Impairment of assets	—		—		—		34,528




Other operating activities, net	11,797		(18,578)		(2)		(33,959)
Net decrease in non-cash working capital	30,689		25,479		7,905		1,126

Net cash provided by continuing operations activities	358,050		467,652		658,731		866,443
Investing Activities
Property additions and dry hole costs	(309,641)		(267,791)		(678,043)		(516,876)
Acquisition of oil and natural gas properties	—		—		(1,383)		—


Net cash required by investing activities	(309,641)		(267,791)		(679,426)		(516,876)
Financing Activities



Borrowings on revolving credit facility	100,000		100,000		350,000		200,000
Repayment of revolving credit facility	(100,000)		(100,000)		(150,000)		(200,000)
Retirement of debt	—		(50,000)		—		(50,000)
Repurchase of common stock	(2,548)		(55,887)		(102,620)		(105,887)
Cash dividends paid	(46,386)		(45,772)		(93,412)		(91,545)
Withholding tax on stock-based incentive awards	19		(28)		(7,654)		(25,298)
Distributions to noncontrolling interest	(11,210)		(38,209)		(18,165)		(61,210)
Finance lease obligation payments	(370)		(167)		(486)		(331)
Issue costs of debt facility	(18)		—		(18)		—


Net required by financing activities	(60,513)		(190,063)		(22,355)		(334,271)






Effect of exchange rate changes on cash and cash equivalents	(1,179)		391		(888)		1,249
Net (decrease) increase in cash and cash equivalents	(13,283)		10,189		(43,938)		16,545
Cash and cash equivalents at beginning of period	392,914		323,430		423,569		317,074
Cash and cash equivalents at end of period	$	379,631	$	333,619	$	379,631	$	333,619

MURPHY OIL CORPORATION

CONDENSED CONSOLIDATED BALANCE SHEETS (unaudited)


(Thousands of dollars)	June 30, 2025		December 31, 2024 1
ASSETS

Cash and cash equivalents	$	379,631	$	423,569
Other current assets	382,494		361,710





Property, plant and equipment, net	8,347,423		8,054,653
Operating lease assets, net	673,223		777,536
Other long-term assets	56,744		50,011



Total assets	$	9,839,515	$	9,667,479
LIABILITIES AND EQUITY

Current maturities of long-term debt, finance lease	$	910	$	871
Accounts payable	509,225		472,165
Operating lease liabilities	190,659		253,208
Other current liabilities	208,503		216,570





Long-term debt, including finance lease obligation	1,474,959		1,274,502
Asset retirement obligations	980,109		960,804

Non-current operating lease liabilities	494,561		537,381
Other long-term liabilities	623,409		610,135


Total liabilities	$	4,482,335	$	4,325,636







Murphy Shareholders' Equity	5,198,526		5,194,250
Noncontrolling interest	158,654		147,593

Total liabilities and equity	$	9,839,515	$	9,667,479

1 Reclassified to conform to current presentation.

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)	2025		2024		2025		2024
Net income attributable to Murphy (GAAP) 1	$	22.3	$	127.7	$	95.3	$	217.7
Discontinued operations (income) loss	(1.3)		0.6		(0.7)		1.5
Net income from continuing operations attributable to Murphy	21.0		128.3		94.6		219.2
Adjustments:
Foreign exchange loss (gain)	34.3		(5.5)		34.3		(16.0)
Mark-to-market (gain) on derivative instruments	(10.3)		—		(1.4)		—
Impairment of assets	—		—		—		34.5
Write-off of previously suspended exploration well	—		—		—		26.1















Total adjustments, before taxes	24.0		(5.5)		32.9		44.6
Income tax (benefit) expense related to adjustments	(6.5)		1.4		(8.3)		(8.8)

Total adjustments, after taxes	17.5		(4.1)		24.6		35.8
Adjusted net income from continuing operations attributable to Murphy (Non-GAAP)	$	38.5	$	124.2	$	119.2	$	255.0
Adjusted net income from continuing operations per average diluted share (Non-GAAP)	$	0.27	$	0.81	$	0.83	$	1.66

1 Excludes amounts attributable to a noncontrolling interest in 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 GAAP.

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


	Three Months Ended June 30, 2025						Six Months Ended June 30, 2025
(Millions of dollars)	Pretax		Tax		Net		Pretax		Tax		Net








Corporate	$	24.0	$	(6.5)	$	17.5	$	32.9	$	(8.3)	$	24.6
Total adjustments	$	24.0	$	(6.5)	$	17.5	$	32.9	$	(8.3)	$	24.6

MURPHY OIL CORPORATION

SCHEDULE OF EBITDA, ADJUSTED EBITDA, EBITDAX AND ADJUSTED EBITDAX (unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(Millions of dollars)	2025		2024		2025		2024
Net income attributable to Murphy (GAAP) 1	$	22.3	$	127.7	$	95.3	$	217.7
Income tax expense	1.1		32.7		33.8		62.7
Interest expense, net	25.1		21.0		48.6		41.0
Depreciation, depletion and amortization expense 1	250.8		207.3		438.2		410.1
EBITDA attributable to Murphy (Non-GAAP)	299.3		388.7		615.9		731.5
Exploration expenses	10.3		42.7		24.8		87.1
EBITDAX attributable to Murphy (Non-GAAP)	$	309.6	$	431.4	$	640.7	$	818.6

EBITDA attributable to Murphy (Non-GAAP)	$	299.3	$	388.7	$	615.9	$	731.5
Foreign exchange loss (gain)	34.3		(5.4)		34.3		(15.9)
Accretion of asset retirement obligations 1	12.9		11.7		25.4		23.1
Mark-to-market (gain) on derivative instruments	(10.3)		—		(1.4)		—
Impairment of asset	—		—		—		34.5
Write-off of previously suspended exploration well	—		—		—		26.1


Discontinued operations (income) loss	(1.3)		0.6		(0.7)		1.5






Adjusted EBITDA attributable to Murphy (Non-GAAP)	$	334.9	$	395.6	$	673.5	$	800.8
Other exploration expenses 2	10.3		42.7		24.8		61.0
Adjusted EBITDAX attributable to Murphy (Non-GAAP)	$	345.2	$	438.3	$	698.3	$	861.8

1 Excludes amounts attributable to a noncontrolling interest in MP GOM.

2 Other exploration expenses consist of exploration expenses as reported in the consolidated statement of operations excluding amounts relating to the write-off of previously suspended exploration well included in Adjusted EBITDA calculation above.

Non-GAAP Financial Measures

Presented above is a reconciliation of net income to earnings before interest, taxes, depreciation and amortization (EBITDA), adjusted EBITDA, earnings before interest, taxes, depreciation and amortization, and exploration expenses (EBITDAX) and adjusted EBITDAX. Management believes EBITDA, adjusted EBITDA, 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. Adjusted EBITDAX exclude certain items that management believes affect the comparability of results between periods. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. EBITDA, adjusted EBITDA, 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 GAAP.

MURPHY OIL CORPORATION

SCHEDULE OF FREE CASH FLOW AND ADJUSTED FREE CASH FLOW (unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(Millions of dollars)	2025		2024		2025		2024
Net cash provided by continuing operations activities (GAAP)	$	358.1	$	467.7	$	658.7	$	866.4
Exclude: increase (decrease) in non-cash working capital	(30.7)		(25.5)		(7.9)		(1.1)
Operating cash flow excluding working capital adjustments	327.4		442.2		650.8		865.3
Less: property additions and dry hole costs 1	(309.6)		(267.8)		(678.0)		(516.9)
Free cash flow (Non-GAAP)	$	17.8	$	174.4	$	(27.2)	$	348.4
Less: cash dividends paid	(46.4)		(45.8)		(93.4)		(91.5)
Less: distributions to noncontrolling interest	(11.2)		(38.2)		(18.2)		(61.2)

Less: withholding tax on stock-based incentive awards	—		—		(7.7)		(25.3)
Less: acquisition of oil and natural gas properties	—		—		(1.4)		—
Adjusted free cash flow (Non-GAAP)	$	(39.8)	$	90.4	$	(147.9)	$	170.4

1 Property additions for the 2025 period includes a payment of $125.0 million for the purchase of a floating production, storage, and offloading vessel in U.S. Offshore, including amounts attributable to a noncontrolling interest in MP GOM.

Non-GAAP Financial Measures

Presented above is a reconciliation of net cash provided by continuing operations activities to free cash flow (FCF) and adjusted FCF. Management believes FCF and adjusted FCF are important information to provide because they are additional measures of liquidity and are used by management to evaluate the Company’s ability to internally generate cash, excluding the timing impacts of working capital, and to measure funds available for investing and financing activities. Management also believes this information may be useful to investors and analysts to monitor the Company’s financial health and its performance over time. Adjusted FCF excludes certain items that management believes affect the comparability of results between periods. FCF and adjusted FCF are non-GAAP and should not be considered a substitute for net cash provided by operating, investing, or financing activities as determined in accordance with GAAP.

MURPHY OIL CORPORATION

FUNCTIONAL RESULTS OF OPERATIONS (unaudited)


	Three Months Ended June 30, 2025				Three Months Ended June 30, 2024
(Millions of dollars)	Revenues		Income (Loss)		Revenues		Income (Loss)
Exploration and production
United States 1	$	553.5	$	86.5	$	679.5	$	185.7
Canada	128.3		10.5		119.0		8.9
Other	2.9		(7.3)		4.3		(10.1)
Total exploration and production	684.7		89.7		802.8		184.5
Corporate	10.9		(55.9)		—		(27.7)
Income from continuing operations	695.6		33.8		802.8		156.8
Discontinued operations, net of tax	—		1.3		—		(0.6)
Net income including noncontrolling interest	$	695.6	$	35.1	$	802.8	$	156.2
Less: Net income attributable to noncontrolling interest			12.8				28.5
Net income attributable to Murphy			$	22.3			$	127.7


	Six Months Ended June 30, 2025				Six Months Ended June 30, 2024
(Millions of dollars)	Revenues		Income (Loss)		Revenues		Income (Loss)
Exploration and production
United States ¹	$	1,063.0	$	194.4	$	1,339.1	$	320.2
Canada	294.0		52.0		255.9		28.3
Other	2.9		(18.5)		4.2		(20.9)
Total exploration and production	1,359.9		227.9		1,599.2		327.6
Corporate	1.4		(104.1)		—		(55.2)
Income from continuing operations	1,361.3		123.8		1,599.2		272.4
Discontinued operations, net of tax	—		0.7		—		(1.5)
Net income including noncontrolling interest	$	1,361.3	$	124.5	$	1,599.2	$	270.9
Less: Net income attributable to noncontrolling interest			29.2				53.2
Net income attributable to Murphy			$	95.3			$	217.7

1 Includes results 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)	2025		2024		2025		2024
United States – Onshore
Lease operating expense	$	8.20	$	14.61	$	10.08	$	14.14
Severance and ad valorem taxes	2.66		3.73		2.96		3.66
Depreciation, depletion and amortization expense	29.88		29.64		29.68		29.04

United States – Offshore 1
Lease operating expense	$	20.91	$	23.58	$	21.13	$	21.96
Severance and ad valorem taxes	0.14		0.07		0.11		0.06
Depreciation, depletion and amortization expense	16.93		13.44		16.21		13.45

Canada – Onshore
Lease operating expense	$	4.98	$	5.43	$	5.21	$	5.46
Severance and ad valorem taxes	0.05		0.06		0.05		0.06
Depreciation, depletion and amortization expense	4.20		4.76		4.29		4.86

Canada – Offshore
Lease operating expense	$	17.86	$	22.60	$	17.29	$	24.43
Depreciation, depletion and amortization expense	11.47		12.00		9.59		10.71

Total E&P continuing operations 1
Lease operating expense	$	11.95	$	15.27	$	12.83	$	14.83
Severance and ad valorem taxes	0.60		0.61		0.59		0.62
Depreciation, depletion and amortization expense 2	14.28		12.52		13.70		12.64

Total oil and gas continuing operations – excluding noncontrolling interest
Lease operating expense 3	$	11.80	$	15.09	$	12.67	$	14.69
Severance and ad valorem taxes	0.62		0.64		0.61		0.64
Depreciation, depletion and amortization expense 2	14.28		12.52		13.71		12.65

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 $8.76 and $10.42 for the three months ended June 30, 2025 and 2024, respectively and $9.50 and $10.58 for the six months ended June 30, 2025 and 2024, respectively.

MURPHY OIL CORPORATION

CAPITAL EXPENDITURES (unaudited)


	Three Months Ended June 30,				Six Months Ended June 30,
(Millions of dollars)	2025		2024		2025		2024
Exploration and production
United States 1	$	178.4	$	225.8	$	500.5	$	414.3
Canada	45.7		42.2		101.1		109.5
Other	26.7		21.2		69.8		32.5
Total	250.8		289.2		671.4		556.3

Corporate	2.8		4.2		7.0		8.4
Total capital expenditures - continuing operations 1	253.6		293.4		678.4		564.7

Less: capital expenditures attributable to noncontrolling interest	2.8		1.6		24.7		8.9
Total capital expenditures - continuing operations attributable to Murphy 2	250.8		291.8		653.7		555.8

Charged to exploration expenses 3
United States 1	2.2		30.6		7.3		63.8
Canada	—		0.1		0.1		0.2
Other	5.9		9.1		13.6		17.4
Total charged to exploration expenses - continuing operations 1,3	8.1		39.8		21.0		81.4

Less: charged to exploration expenses attributable to noncontrolling interest	0.1		—		0.1		—
Total charged to exploration expenses - continuing operations attributable to Murphy 4	8.0		39.8		20.9		81.4


Total capitalized - continuing operations attributable to Murphy	$	242.8	$	252.0	$	632.8	$	474.4

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

2 For the three months ended June 30, 2025 and 2024, there were no acquisition-related costs incurred. For the six months ended June 30, 2025, total capital expenditures attributable to Murphy, excluding acquisition-related costs of $105.6 million, primarily related to the purchase of a floating production, storage, and offloading vessel in U.S. Offshore (2024: nil), is $548.1 million (2024: $555.8 million).

3 For the three-month and six-month ended June 30, 2025, total charged to exploration expense attributable to Murphy, excludes amortization of undeveloped leases of $2.3 million (2024: $3.0 million) and $3.9 million (2024 $5.8 million), respectively.

4 For the three months ended June 30, 2025 and 2024, no amounts were expensed for previously suspended exploration costs. For the six months ended June 30, 2025, total charged to exploration expense attributable to Murphy, excluding previously suspended exploration costs of nil (2024: $26.1 million), is $20.9 million (2024: $55.3 million).

MURPHY OIL CORPORATION

PRODUCTION SUMMARY (unaudited)


	Three Months Ended June 30,		Six Months Ended June 30,
(Barrels per day unless otherwise noted)	2025	2024	2025	2024
Net crude oil and condensate
United States - Onshore	28,519	19,873	22,779	20,127
United States - Offshore 1	58,840	66,818	57,222	66,448
Canada - Onshore	2,307	2,978	2,445	2,617
Canada - Offshore	5,638	7,506	7,237	6,885
Other	296	245	275	245
Total net crude oil and condensate	95,600	97,420	89,958	96,322
Net natural gas liquids
United States - Onshore	5,557	4,125	4,818	4,145
United States - Offshore 1	4,720	4,505	4,265	4,596
Canada - Onshore	494	494	516	474
Total net natural gas liquids	10,771	9,124	9,599	9,215
Net natural gas – thousands of cubic feet per day
United States - Onshore	32,389	23,197	29,306	23,714
United States - Offshore 1	52,964	57,762	52,062	55,462
Canada - Onshore	454,310	406,856	400,898	381,155
Total net natural gas	539,663	487,815	482,266	460,331
Total net hydrocarbons - including NCI 2,3	196,315	187,847	179,935	182,259
Noncontrolling interest
Net crude oil and condensate – barrels per day	(6,070)	(6,717)	(5,925)	(6,608)
Net natural gas liquids – barrels per day	(244)	(217)	(207)	(214)
Net natural gas – thousands of cubic feet per day	(1,942)	(2,003)	(1,590)	(2,039)
Total noncontrolling interest 2,3	(6,638)	(7,268)	(6,397)	(7,162)
Total net hydrocarbons - excluding NCI 2,3	189,677	180,579	173,538	175,097

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

SALES SUMMARY (unaudited)


	Three Months Ended June 30,		Six Months Ended June 30,
(Barrels per day unless otherwise noted)	2025	2024	2025	2024
Net crude oil and condensate
United States - Onshore	28,520	19,873	22,779	20,127
United States - Offshore 1	58,469	67,507	56,313	67,781
Canada - Onshore	2,307	2,978	2,444	2,617
Canada - Offshore	7,762	5,645	9,436	6,322
Other	457	469	230	240
Total net crude oil and condensate	97,515	96,472	91,202	97,087
Net natural gas liquids
United States - Onshore	5,557	4,125	4,819	4,145
United States - Offshore 1	4,720	4,505	4,264	4,596
Canada - Onshore	494	494	516	474
Total net natural gas liquids	10,771	9,124	9,599	9,215
Net natural gas – thousands of cubic feet per day
United States - Onshore	32,388	23,197	29,306	23,714
United States - Offshore 1	52,964	57,762	52,062	55,462
Canada - Onshore	454,310	406,855	400,898	381,155
Total net natural gas	539,662	487,814	482,266	460,331
Total net hydrocarbons - including NCI 2,3	198,230	186,898	181,179	183,024
Noncontrolling interest
Net crude oil and condensate – barrels per day	(6,014)	(6,792)	(5,792)	(6,798)
Net natural gas liquids – barrels per day	(243)	(217)	(207)	(214)
Net natural gas – thousands of cubic feet per day	(1,942)	(2,003)	(1,590)	(2,039)
Total noncontrolling interest 2,3	(6,581)	(7,343)	(6,264)	(7,352)
Total net hydrocarbons - excluding NCI 2,3	191,649	179,555	174,915	175,672

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,
	2025		2024		2025		2024
Crude oil and condensate – dollars per barrel
United States - Onshore	$	64.00	$	80.71	$	66.84	$	78.76
United States - Offshore 1	64.48		81.67		68.23		79.61
Canada - Onshore 2	59.94		72.25		61.73		70.24
Canada - Offshore 2	64.76		84.34		70.39		85.25
Other 2	70.86		100.92		70.86		96.43
Natural gas liquids – dollars per barrel
United States - Onshore	19.56		19.48		21.07		20.08
United States - Offshore 1	19.35		22.77		22.75		23.56
Canada - Onshore 2	33.84		35.46		35.00		35.16
Natural gas – dollars per thousand cubic feet
United States - Onshore	2.75		1.59		3.03		1.77
United States - Offshore 1	3.47		2.00		3.89		2.32
Canada - Onshore 2	1.65		1.37		1.96		1.68

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 4, 2025 (unaudited)

Volumes
(MMCF/d)

Price/MCF

Remaining Period

Area

Commodity

Type 1

Start Date

End Date

Canada

Natural Gas

Fixed price forward sales

C$2.75

7/1/2025

12/31/2025

Canada

Natural Gas

Fixed price forward sales

C$3.03

1/1/2026

12/31/2026

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

Volumes

(MMCF/d)

Price/MCF

Remaining Period

Area

Commodity

Type

Start Date

End Date

United States

Natural Gas

Fixed price derivative swap

US$3.65

7/1/2025

9/30/2025

United States

Natural Gas

Fixed price derivative swap

US$3.74

10/1/2025

12/31/2025

Quarterly Stockholder Update by Murphy Oil Corporation

HOUSTON, Texas, August 6, 2025

Murphy Oil Corporation Stockholders,

This year Murphy Oil Corporation celebrates its 75th anniversary of incorporation. Over the last 75 years, Murphy has built a legacy based on a pioneering spirit and thoughtful decision making. Murphy is different from other independent exploration and production companies of its size. We have both onshore and offshore production, operate in the United States and internationally, and have a proven track record of successfully conducting offshore frontier exploration. While our company’s diversified business model is a key differentiator, it can be more complex to value compared to a pure-play US shale company. This letter aims to provide a deeper understanding of Murphy through additional context and leadership perspectives on key aspects of our business.

This letter also serves as a supplement to our earnings release for the second quarter of 2025, and both documents are being furnished simultaneously to the Securities and Exchange Commission and our stockholders. Please see the information regarding forward-looking statements and non-GAAP financial information included at the end of this letter. Unless otherwise noted, the financial and operating highlights and metrics discussed in this letter exclude noncontrolling interest (NCI).1

SECOND QUARTER 2025 SUMMARY

Murphy delivered solid operational and production performance in the second quarter while experiencing significantly lower commodities prices than we have seen in recent quarters. Second quarter oil, natural gas liquids, and natural gas production of 189.7 thousand barrels of oil equivalents per day (MBOEPD) exceeded the high end of our quarterly guidance range of 177.0 to 185.0 MBOEPD highlighted by oil production of 89.5 thousand barrels of oil per day (MBOPD) also exceeding guidance. Operating expenses in the second quarter were $11.80 per BOE, which is $1.94 per BOE lower than in the first quarter.

Realized oil prices were $64.31 per barrel in the second quarter, which is $7.89 per barrel or 11 percent less than in the first quarter. In addition, realized natural gas prices were $1.88 per thousand cubic feet (MCF) in the second quarter, which is $0.79 per MCF or 29.5 percent lower than in the first quarter. This latter reduction is

particularly significant as natural gas comprises 53 percent of our production mix. As a result, we recorded net income of $22.3 million, or $0.16 net income per diluted share, for the second quarter compared to $73.0 million, or $0.50 net income per diluted share in the first quarter, despite the large increase in production. Also in the second quarter, earnings before interest, taxes, depreciation and amortization (EBITDA) attributable to Murphy (non-GAAP) was $299.3 million, cash flow from operations was $358.1 million, and we generated free cash flow (non-GAAP) of $17.8 million.

These financial results reflect the extraordinary impact of commodity prices on our business and reinforce the importance of concentrating on the parts of our business we can control: production rates and costs, a solid balance sheet and a first rate exploration program followed by best-in-class oil field development skills.

OPERATIONAL UPDATE

During the second quarter of 2025 we made significant progress in many important areas of our business: the onshore new well delivery program, Gulf of America workovers, Lac Da Vang (Golden Camel) field development, and preparations for exploration and appraisal wells which are planned for the second half of the year.

At our Eagle Ford Shale (EFS) asset, we brought online 24 operated wells and 10 gross non-operated wells. All new EFS operated pads exceeded initial production expectations with our 16 new Karnes County wells delivering some of the highest initial production rates in Murphy EFS history (an average of 2,123 BOEPD per well). While the industry is experiencing declining EFS well performance, in contrast, we continue to enhance capital efficiency by modifying completion designs and operating practices to deliver improved well performance year over year. This also reflects the fact that we have a more deliberate EFS development schedule than most peers resulting in a more robust remaining tier-one well location inventory.

At our Tupper Montney asset, we brought online five new wells, rounding out our 10-well program for the year. We tested a new completion design for those 10 wells, with approximately 50 percent higher proppant loading, and we have seen excellent early performance from the wells. All 10 new Tupper wells have 30-day initial production rates (an average of 19.2 million cubic feet per day) that are in the Murphy top 20 all-time Tupper high performer list. I must admit that I am very proud of our onshore team who continues to deliver impressive operational and technical improvements despite a new well program that has limited “shots on goal” compared to shale-only industry peers.

Early in the second quarter in our offshore program, we completed the Samurai #3 workover and returned the well to production. Early in the third quarter, the Khaleesi #2 workover was completed, and the well was returned to production in July. Together these two workovers add 3.7 MBOEPD to our production totals in the third

quarter. In addition, we are progressing the Marmalard #3 workover and expect to resume production from the well in August. These three wells, because of their high production rates, are important cash flow generators and high rate-of-return investments. They also highlight the importance of the Gulf of America to the company’s production assets.

In Vietnam, our Lac Da Vang (Golden Camel) field development execution continues to be impressive as construction of the LDV-A platform’s jacket was completed in the third quarter and is being prepared for installation early in the fourth quarter. Furthermore, fabrication of the LDV-A platform’s topsides, the Floating Storage and Offloading (FSO) vessel’s hull and turret, pipelines, flexible risers, and subsea structures are all progressing on schedule for first oil in the fourth quarter of 2026.

PRODUCTION

As noted, second quarter production of 189.7 MBOEPD was 32.5 MBOEPD or 20.6 percent higher than first quarter production. This outperformance, as referenced above, was primarily driven by earlier online dates and higher than expected initial production rates from new onshore wells at Tupper Montney and Eagle Ford Shale. We now expect full year 2025 production to be closer to the midpoint of our guidance range of 174.5 to 182.5 MBOEPD.

Second quarter production at Tupper Montney was particularly significant as it averaged 447 million cubic feet per day (MMCFD) or 74.7 MBOEPD. With our new wells online, we produced at Tupper West plant capacity throughout May and June. At EFS we achieved second quarter production of 39.5 MBOEPD, significantly higher than our quarterly guidance of 34.2 MBOEPD. During the quarter, EFS achieved a peak rate over 54 MBOEPD, the highest rate delivered since December 2019.

Second quarter production from the Gulf of America averaged 65.7 MBOEPD, which was 1.1 MBOEPD higher than our quarterly guidance of 64.6 MBOEPD and nearly 4 MBOEPD higher than first quarter production. Our non-operated offshore Canada business delivered average production of 5.6 MBOEPD, which was lower than our quarterly guidance by 2.1 MBOEPD, due to higher than anticipated downtime.

CAPITAL EXPENDITURES

Capital expenditures (CAPEX) for the second quarter were $251 million and lower than our quarterly guidance of $300 million, primarily due to timing. In addition, second quarter CAPEX was $152 million lower than first quarter CAPEX primarily because of the unique $104 million Pioneer FPSO purchase in the first quarter.

Murphy’s onshore drilling and completions team continues to set new internal performance records. In the Catarina area of our Eagle Ford Shale asset, we increased the drilling Rate of Penetration (ROP) by 26 percent and reduced the spud-to-total depth timing by 20 percent compared to 2024. In the Tilden area, we

improved capital efficiency by drilling two long lateral U-turn wells instead of four shorter lateral wells, which reduced capital expenditure by 33 percent with no reduction in oil recovery per lateral foot. In Canada, we drilled the longest horizontal wells in Murphy history in Kaybob Duvernay. Our completions team continues to refine completion designs by optimizing fluid and proppant intensities and leveraging automated physics-based models to enhance flowback strategies, which have led to improved initial well performance.

In the third quarter, we expect CAPEX to be $260 million excluding acquisition costs. We continue to be comfortable with our full year 2025 CAPEX guidance of $1,135 to $1,285 million, which includes the Pioneer FPSO purchase but excludes a small Eagle Ford Shale acquisition discussed below.

OPERATING COSTS

As noted above, operating expenses in the second quarter averaged $11.80 per BOE, which is $1.94 per BOE, or 14.1 percent lower than in the first quarter, primarily due to higher production rates, lower Eagle Ford Shale operating costs, and lower offshore workover costs. In our offshore assets, most of the workover activity is behind us, so operating expenses in the second half of the year are expected to be more in line with historical trends. Accordingly, we anticipate operating expenses in the $10 to $12 per BOE range during the second half of 2025.

In our Eagle Ford Shale asset, we have made great progress reducing operating costs which are down $12 million or 18 percent in the first half of 2025 compared to the first half of 2024. On a unit basis operating costs per BOE in the first half of 2025 were down 30 percent compared to the first half of 2024. The primary drivers of reduced operating costs are workforce optimization, lower repairs and maintenance expenses, lower rental equipment costs, and reduced water disposal costs.

EXPLORATION AND APPRAISAL DRILLING

Murphy’s international frontier wildcat and Gulf of America nearfield exploration program remains a key differentiator from our peers. Our planned 2025 and 2026 exploration and appraisal activity will expose the company to transformational conventional volumes and will test for more than one billion BOEs in gross un-risked resource potential.

We are on schedule to drill key exploration and appraisal wells in the second half of the year. In the Gulf of America, the Cello #1 and Banjo #1 exploration wells will be drilled in the third and fourth quarters. Both wells are located in Mississippi Canyon 385, near our operated Delta House floating production system and will flow back through this system if we are successful.

In Vietnam, we will begin drilling a key appraisal well at our recent Hai Su Vang (Golden Sea Lion) oil discovery in the third quarter, with results expected in the fourth

quarter. The discovery well was drilled near the crest of the structure, encountered 370 feet of net oil pay, and was flow tested at 10,000 BOPD. With our current understanding of the range of recoverable resources, we are confident that the discovery is significant and provides a highly profitable investment opportunity. However, since the discovery well did not encounter water, there is untested upside remaining. The appraisal well will be drilled off the crest of the structure to assess reservoir continuity and determine how much of the structure, below the current total depth, is filled with hydrocarbons. These findings will tighten the range of recoverable resources and potentially move the range higher. More than one appraisal well may be required to fully characterize the field.

Our three-well Côte d’Ivoire exploration program remains on schedule to commence in the fourth quarter. This exploration program allows Murphy to evaluate three separate prospects representing various play types and large mean un-risked resources, with relatively low well costs and strong fiscal terms.

COMMODITY PRICING

In addition to the oil and natural gas price comments made above, I will point out a few other highlights. Our gassy onshore Canada business saw realized natural gas prices average $1.65 per MCF, which was $0.44 per MCF higher than the AECO benchmark due to our diversification and fixed forward selling strategies. In addition, and very importantly, Shell Canada Energy announced in late June that the first cargo of liquefied natural gas (LNG) had left the LNG Canada facility in Kitimat, British Columbia. Thus, after many decades of discussion, planning and finally construction, an LNG exporting facility is finally operating on the West Coast of Canada. This provides two billion cubic feet per day of additional demand for Canadian gas and is expected to result in higher AECO prices as LNG Canada production ramps up.

FINANCIAL PERFORMANCE AND RETURN OF CAPITAL

As previously communicated, our Capital Allocation Plan allocates a minimum of 50 percent of adjusted Free Cash Flow to share buybacks and potential dividend increases, with the remainder allocated to the balance sheet. In the first half of 2025 we distributed $93.4 million of dividends to shareholders. We also repurchased $100 million of stock or 3.6 million shares in the first quarter, reducing our shares outstanding to 142.7 million with $550 million remaining in our board authorized share repurchase program.

BALANCE SHEET

Total debt and net debt at the end of the second quarter were $1.476 billion and $1.096 billion, respectively. We had $200 million drawn on our unsecured revolving credit facility at the end of the quarter.

We are favorably positioned with a strong balance sheet, and we remain committed to our $1.0 billion long-term debt target, which represents a 1.0x debt to EBITDA ratio at approximately $45 per barrel WTI. With that said, given current market conditions and our high potential exploration and appraisal program ahead of us, we currently expect to use available adjusted Free Cash Flow for share repurchases rather than bond repayments.

OTHER BUSINESS

In July 2025, we completed a small Eagle Ford Shale acquisition for a contract price of $23 million, subject to certain post-closing adjustments. The sale closed July 1, 2025, and has an effective date of June 15, 2025. For several years we have been telling investors that we screen many Eagle Ford Shale acquisition opportunities but typically do not find assets that are as good as or better than our existing business. With this highly accretive acquisition, we were able to increase our working interest in the Karnes County business that we already own and operate.

CLOSING

I am pleased with our solid operational results in the second quarter and our continued onshore well performance improvements. It’s an exciting time at Murphy with our significant exploration and appraisal catalysts in the coming months. I’m confident that our talented and dedicated employees are capable of delivering shareholder value through our differentiated business model.

Thank you for being a Murphy Oil Corporation Stockholder.

Eric M. Hambly

President and Chief Executive Officer

CONFERENCE CALL AND WEBCAST SCHEDULED FOR AUGUST 7, 2025

Murphy will host a conference call to discuss second quarter 2025 financial and operating results on Thursday, August 7, 2025, at 9:00 a.m. ET. 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 1-800-717-1738, reservation number 30769. For additional information, please refer to the Second Quarter 2025 Earnings Presentation available under the News and Events section of the Investor Relations website.

FORWARD-LOOKING STATEMENTS

This letter 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 natural 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 US or global capital markets, credit markets, banking system or economies in general, including inflation, trade policies, tariffs and other trade restrictions. 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 US 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 letter. Murphy Oil Corporation undertakes no duty to publicly update or revise any forward-looking statements.

NON-GAAP FINANCIAL MEASURES

This letter 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 US generally accepted accounting principles (GAAP) and should therefore be considered only as supplemental to such GAAP financial measures. Please see Exhibit 99.1 on Form 8-K filed on August 6, 2025, for reconciliations of the differences between the non-GAAP financial measures used in this letter and the most directly comparable GAAP financial measures.

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 letter exclude the NCI, thereby representing only the amounts attributable to Murphy.


Investor Contacts:
[email protected]
Kyle Sahni, 281-675-9369
Beth Heller, 281-675-9363


			(281)			675-9000
			Registrant’s telephone number, including area code
			Not applicable
			(Former Name or Former Address, if Changed Since Last Report)


☐			Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)

☐			Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)

☐			Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))

☐			Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))


Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, $1.00 Par Value	MUR	New York Stock Exchange


(d)			Exhibits

99.1			Murphy Oil Corporation Announces Second Quarter Results
99.2			Quarterly Stockholder Update by Murphy Oil Corporation, dated August 6, 2025


	MURPHY OIL CORPORATION
Date: August 6, 2025
	By:	/s/ Paul D. Vaughan
		Paul D. Vaughan
		Vice President and Controller


Exhibit No.
99.1			Murphy Oil Corporation Announces Second Quarter Results
9 9.2			Quarterly Stockholder Update by Murphy Oil Corporation, dated August 6, 2025

104			Cover Page Interactive Data File (embedded within the Inline XBRL document)