8-K
Murphy Oil Corp (MUR)
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UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
FORM 8-K
CURRENT REPORT
PURSUANT TO SECTION 13 OR 15(d) OF THE
SECURITIES EXCHANGE ACT OF 1934
Date of report (Date of earliest event reported): August 6, 2025
MURPHY OIL CORPORATION
(Exact name of registrant as specified in its charter)
| Delaware | 1-8590 | 71-0361522 | ||||
|---|---|---|---|---|---|---|
| (State or other jurisdiction of incorporation) | (Commission File Number) | (I.R.S. Employer Identification No.) | 9805 Katy Fwy, Suite G-200 | |||
| --- | --- | --- | ||||
| Houston, | Texas | 77024 | ||||
| (Address of principal executive offices, including zip code) | (281) | 675-9000 | ||||
| --- | --- | |||||
| Registrant’s telephone number, including area code | ||||||
| Not applicable | ||||||
| (Former Name or Former Address, if Changed Since Last Report) |
Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):
| ☐ | 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)) |
Securities registered pursuant to Section 12(b) of the Act:
| Title of each class | Trading Symbol | Name of each exchange on which registered |
|---|---|---|
| Common Stock, $1.00 Par Value | MUR | New York Stock Exchange |
Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter). Emerging growth company ☐
If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act. ☐
Item 2.02. Results of Operations and Financial Condition
The following information is furnished pursuant to Item 2.02, “Results of Operations and Financial Condition.”
On August 6, 2025 Murphy Oil Corporation issued a news release announcing its financial and operating results for the quarter ended June 30, 2025. The full text of this news release is attached hereto as Exhibit 99.1. The Company also issued a quarterly stockholder update as a supplement to the earnings release, which is furnished hereto as Exhibit 99.2.
The information contained in this report and the exhibits hereto shall not be deemed to be “filed” for purposes of Section 18 of the Securities Exchange Act of 1934, nor shall it be deemed incorporated by reference in any filing under the Securities Act of 1933, as amended, unless specifically identified as such.
Item 9.01. Financial Statements and Exhibits
| (d) | Exhibits |
|---|---|
| 99.1 | Murphy Oil Corporation AnnouncesSecondQuarter Results |
| 99.2 | Quarterly Stockholder Updateby Murphy Oil Corporation, dated August 6, 2025 |
Signature
Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.
| MURPHY OIL CORPORATION | ||
|---|---|---|
| Date: August 6, 2025 | ||
| By: | /s/ Paul D. Vaughan | |
| Paul D. Vaughan | ||
| Vice President and Controller |
Exhibit Index
| Exhibit<br>No. | |
|---|---|
| 99.1 | Murphy Oil Corporation AnnouncesSecondQuarter Results |
| 99.2 | Quarterly Stockholder Updateby Murphy Oil Corporation, dated August 6, 2025 |
| 104 | Cover Page Interactive Data File (embedded within the Inline XBRL document) |
Document
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<br><br>(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 | NGLs(BOPD) | Total<br>(BOEPD) |
| Eagle Ford Shale | 6,200 | 45,000 |
| Gulf of America, excl. NCI | 3,600 | 57,000 |
| Tupper Montney | — | 75,300 |
| Kaybob Duvernay | 500 | 6,400 |
| Offshore Canada | — | 5,000 |
| Other | — | 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 |
All values are in US Dollars.
The table below details the 2025 CAPEX plan by quarter.
| 2025 CAPEX 1 by Quarter ( MM) | |||
|---|---|---|---|
| 1Q 2025A | 3Q 2025E | 4Q 2025E | FY 2025E |
| 4032 | $2603 | $296 | $1,2102,3 |
All values are in US Dollars.
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 <br>2025A | 2Q<br><br>2025A | 3Q <br>2025E | 4Q <br>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: |
|---|
| InvestorRelations@murphyoilcorp.com |
| Kyle Sahni, 281-675-9369 |
| Beth Heller, 281-675-9363 |
MURPHY OIL CORPORATION
CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)
| Three Months Ended<br>June 30, | Six Months Ended<br>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<br>June 30, | Six Months Ended<br>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,<br>2025 | December 31,<br><br>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<br>June 30, | Six Months Ended<br>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<br>June 30, | Six Months Ended<br>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<br><br>(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<br>June 30, | Six Months Ended<br>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<br>June 30, 2025 | Three Months Ended<br>June 30, 2024 | |||||||
|---|---|---|---|---|---|---|---|---|
| (Millions of dollars) | Revenues | Income<br>(Loss) | Revenues | Income<br>(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<br>June 30, 2025 | Six Months Ended<br>June 30, 2024 | |||||||
| --- | --- | --- | --- | --- | --- | --- | --- | --- |
| (Millions of dollars) | Revenues | Income<br>(Loss) | Revenues | Income<br>(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<br>June 30, | Six Months Ended<br>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<br>June 30, | Six Months Ended<br>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<br>June 30, | Six Months Ended<br>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<br>June 30, | Six Months Ended<br>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<br>June 30, | Six Months Ended<br>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<br>(MMCF/d) | Price/MCF | Remaining Period | |||||
|---|---|---|---|---|---|---|---|
| Area | Commodity | Type 1 | End Date | ||||
| Canada | Natural Gas | Fixed price forward sales | 40 | C2.75 | 7/1/2025 | 12/31/2025 | |
| Canada | Natural Gas | Fixed price forward sales | 50 | C3.03 | 1/1/2026 | 12/31/2026 |
All values are in US Dollars.
1 Fixed price forward sale contracts listed above are accounted for as normal sales and purchases for accounting purposes.
| Volumes<br><br>(MMCF/d) | Price/MCF | Remaining Period | |||||
|---|---|---|---|---|---|---|---|
| Area | Commodity | Type | End Date | ||||
| United States | Natural Gas | Fixed price derivative swap | 60 | US3.65 | 7/1/2025 | 9/30/2025 | |
| United States | Natural Gas | Fixed price derivative swap | 60 | US3.74 | 10/1/2025 | 12/31/2025 |
All values are in US Dollars.
20
Document
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
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: |
|---|
| InvestorRelations@murphyoilcorp.com |
| Kyle Sahni, 281-675-9369 |
| Beth Heller, 281-675-9363 |
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