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): May 2, 2024
(Exact name of registrant as specified in its charter)
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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) | |||||
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Securities registered pursuant to Section 12(b) of the Act:
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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 May 2, 2024 Murphy Oil Corporation issued a news release announcing its financial and operating results for the quarter ended March 31, 2024. The full text of this news release is attached hereto as Exhibit 99.1.
Item 9.01. Financial Statements and Exhibits
| (d) | Exhibits | ||||
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: May 2, 2024 | ||||||||
By: | /s/ Paul D. Vaughan | |||||||
| Paul D. Vaughan | ||||||||
Vice President and Controller | ||||||||
Exhibit Index
| Exhibit No. | |||||
| 104 | Cover Page Interactive Data File (embedded within the Inline XBRL document) | ||||
EXHIBIT 99.1
MURPHY OIL CORPORATION ANNOUNCES FIRST QUARTER 2024
FINANCIAL AND OPERATIONAL RESULTS, REAFFIRMS 2024 PRODUCTION
AND CAPITAL EXPENDITURE GUIDANCE RANGES
Produced 170 MBOEPD with 89 MBOPD, Repurchased $50 Million of Shares
HOUSTON, Texas, May 2, 2024 – Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the first quarter ended March 31, 2024, including net income attributable to Murphy of $90 million, or $0.59 net income per diluted share. Excluding discontinued operations and other items affecting comparability between periods, adjusted net income attributable to Murphy was $131 million, or $0.85 adjusted net income per diluted share.
Unless otherwise noted, the financial and operating highlights and metrics discussed in this commentary exclude noncontrolling interest (NCI). 1
Highlights for the first quarter include:
•Produced 170 thousand barrels of oil equivalent per day (MBOEPD), at the high end of guidance, with 89 thousand barrels of oil per day (MBOPD) or 52 percent oil volumes
•Repurchased $50 million of stock, or 1.3 million shares, at an average price of $39.25 per share
•Awarded six deepwater blocks from Gulf of Mexico Federal Lease Sale 261
Subsequent to the first quarter:
•Maintained the quarterly dividend of $0.30 per share or $1.20 per share annualized
•Received positive outlooks from Moody’s and Fitch credit rating agencies, revised from stable outlooks
“Murphy had another solid quarter. We progressed our offshore plans and produced above expectations from our onshore assets. We advanced our 2024 onshore well delivery program, with new wells in the Eagle Ford Shale, Tupper Montney and Kaybob Duvernay either currently flowing or expected to come online in the near term. Further, our upcoming Gulf of Mexico and Vietnam exploration wells have the potential to expand our resource base,” said Roger W. Jenkins, Chief Executive Officer. “I am pleased we repurchased $50 million of stock at an average price below $40 per share, advancing our share repurchase program. I look forward to production growth as we execute our 2024 plans, leading to increased free cash flow that will continue to enhance shareholder returns.”
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FIRST QUARTER 2024 RESULTS
The company recorded net income attributable to Murphy of $90 million, or $0.59 net income per diluted share, for the first quarter 2024. Adjusted net income, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, was $131 million, or $0.85 adjusted net income per diluted share for the same period. Adjustments to net income totaled $50 million before tax and were comprised of a $35 million impairment of assets and a $26 million write-off of a previously suspended exploration well, offset by a $11 million foreign exchange gain. Details for first quarter results and an adjusted net income reconciliation can be found in the attached schedules.
Earnings before interest, taxes, depreciation and amortization (EBITDA) attributable to Murphy were $343 million. Earnings before interest, tax, depreciation, amortization and exploration expenses (EBITDAX) attributable to Murphy were $387 million. Adjusted EBITDA attributable to Murphy was $405 million. Adjusted EBITDAX attributable to Murphy was $424 million. Reconciliations for first quarter EBITDA, EBITDAX, adjusted EBITDA and adjusted EBITDAX can be found in the attached schedules.
First quarter production averaged 170 MBOEPD and included 52 percent oil volumes, or 89 MBOPD. Volumes were at the high end of the guidance range as a result of strong well performance across onshore assets.
Accrued capital expenditures (CAPEX) for first quarter 2024 totaled $264 million, excluding NCI. Details for first quarter production and CAPEX can be found in the attached schedules.
During the quarter, Murphy received a positive outlook from Moody’s with the Ba2 rating affirmed. Additionally, Murphy received a positive outlook from Fitch, with the BB+ rating affirmed. Both outlooks were revised from stable.
CAPITAL ALLOCATION FRAMEWORK
Murphy had approximately $1.1 billion of liquidity on March 31, 2024, with no borrowings on the $800 million senior unsecured credit facility and $323 million of cash and cash equivalents, inclusive of NCI.
At the end of the first quarter, Murphy’s total debt was $1.3 billion, and consisted of long-term, fixed-rate notes with a weighted average maturity of 7.9 years and a weighted average coupon of 6.2 percent.
During the first quarter, Murphy repurchased $50 million of stock, or 1.3 million shares, at an average price of $39.25 per share. As of March 31, 2024, Murphy had $400 million remaining under the share repurchase authorization and 152.6 million shares outstanding.
“Since disclosing our capital allocation framework in August 2022, we have consistently executed a combination of debt reductions, share repurchases and dividend increases,” said Jenkins. “Murphy has repurchased a total of $200 million of stock, or 4.7 million shares, at an average price of $42.68 per share, while also lowering debt by $500 million since third quarter 2023. We remain committed to following our capital allocation framework, which will allow us
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to reach Murphy 3.0 later this year when we accomplish our 2024 debt reduction goal of $300 million.”
OPERATIONS SUMMARY
Onshore
In the first quarter of 2024, the onshore business produced approximately 91 MBOEPD, which included 30 percent liquids volumes.
Eagle Ford Shale – Production averaged 29 MBOEPD with 71 percent oil volumes and 86 percent liquids volumes in the first quarter. Murphy progressed its 20-well operated 2024 program during the quarter, and four non-operated Tilden wells were brought online. The company plans to bring online seven operated Catarina wells in second quarter 2024.
Tupper Montney – During the first quarter, natural gas production averaged 348 million cubic feet per day (MMCFD). Production was 21 MMCFD above guidance as a result of wells brought online in 2023 continuing to exceed expectations. As planned, Murphy completed drilling its 13-well program during the quarter, with all wells coming online in second quarter 2024.
Kaybob Duvernay – Production averaged 4 MBOEPD with 68 percent liquids volumes in the first quarter. Murphy drilled three operated wells in the first quarter as planned, with completions ongoing. All three wells are scheduled to come online in second quarter 2024.
Offshore
Excluding NCI, in the first quarter of 2024, the offshore business produced approximately 79 MBOEPD, which included 84 percent oil.
Gulf of Mexico – Production averaged approximately 73 MBOEPD, consisting of 82 percent oil during the first quarter. As planned, Murphy drilled a successful well at Khaleesi #4 (Green Canyon 389) and completed the Mormont #2 (Mississippi Canyon 478) subsea equipment repair and returned the well to production. Also during the quarter, Murphy’s operating partner drilled and completed the non-operated Lucius #11 (Keathley Canyon 919) well.
Canada – In the first quarter, production averaged 6 MBOEPD, consisting of 100 percent oil. Production continued to ramp up from the non-operated Terra Nova field during the quarter following completion of the asset life extension project.
EXPLORATION
Gulf of Mexico – During the first quarter, Murphy was awarded six exploration blocks from the Gulf of Mexico Federal Lease Sale 261 with an average working interest of 68 percent. Also during the quarter, Murphy wrote off $26 million of previously suspended exploration well costs related to the 2016 Hoffe Park exploration well.
2024 CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE
Murphy maintains its 2024 accrued CAPEX range of $920 million to $1.02 billion. The company also maintains its full year 2024 production range of 180 to 188 MBOEPD, consisting of
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approximately 95 MBOPD oil and 105 MBOEPD liquids volumes, equating to 52 percent oil and 57 percent liquids volumes, respectively.
Production for second quarter 2024 is estimated to be in the range of 176 to 184 MBOEPD with 93 MBOPD, or 51 percent, oil volumes. This range is impacted by 2,000 BOEPD of offshore non-operated unplanned maintenance, 1,250 BOEPD of Eagle Ford Shale planned downtime and 11,700 BOEPD of Tupper Montney planned plant maintenance. Both production and CAPEX guidance ranges exclude Gulf of Mexico NCI.
Detailed guidance for the second quarter and full year 2024 is contained in the attached schedules.
FIXED PRICE FORWARD SALES CONTRACTS
Murphy maintains fixed price forward sales contracts in Canada to lessen its dependence on variable AECO prices. These contracts are for physical delivery of natural gas volumes at a fixed price, with no mark-to-market income adjustments. Details for the current fixed price contracts can be found in the attached schedules.
CONFERENCE CALL AND WEBCAST SCHEDULED FOR MAY 2, 2024
Murphy will host a conference call to discuss first quarter 2024 financial and operating results on Thursday, May 2, 2024, at 9:00 a.m. EDT. The call can be accessed either via the Internet through the events calendar on the Murphy Oil Corporation Investor Relations website at http://ir.murphyoilcorp.com or via telephone by dialing toll free 800-717-1738, reservation number 78570. For additional information, please refer to the First Quarter 2024 Earnings Presentation available under the News and Events section of the Investor Relations website.
FINANCIAL DATA
Summary financial data and operating statistics for first quarter 2024, with comparisons to the same period from the previous year, are contained in the attached schedules. Additionally, a schedule indicating the impacts of items affecting comparability of results between periods, a reconciliation of EBITDA, EBITDAX, adjusted EBITDA and adjusted EBITDAX between periods, as well as guidance for the second quarter and full year 2024, are also included.
1In accordance with GAAP, Murphy reports the 100 percent interest, including a 20 percent noncontrolling interest (NCI), in its subsidiary, MP Gulf of Mexico, LLC (MP GOM). The GAAP financials include the NCI portion of revenue, costs, assets and liabilities and cash flows. Unless otherwise noted, the financial and operating highlights and metrics discussed in this news release, but not the accompanying schedules, exclude the NCI, thereby representing only the amounts attributable to Murphy.
CAPITAL ALLOCATION FRAMEWORK
This news release contains references to the company’s capital allocation framework and adjusted free cash flow. As previously disclosed, the capital allocation framework defines Murphy 1.0 as when long-term debt exceeds $1.8 billion. At such time, adjusted free cash flow is allocated to long-term debt reduction while the company continues to support the quarterly
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dividend. The company reaches Murphy 2.0 when long-term debt is between $1.0 billion and $1.8 billion. At such time, approximately 75 percent of adjusted free cash flow is allocated to debt reduction, with the remaining 25 percent distributed to shareholders through share buybacks and potential dividend increases. When long-term debt is at or below $1.0 billion, the company is in Murphy 3.0 and begins allocating 50 percent of adjusted free cash flow to the balance sheet, with a minimum of 50 percent of adjusted free cash flow allocated to share buybacks and potential dividend increases.
Adjusted free cash flow is defined as cash flow from operations before working capital change, less capital expenditures, distributions to NCI and projected payments, quarterly dividend and accretive acquisitions.
ABOUT MURPHY OIL CORPORATION
As an independent oil and natural gas exploration and production company, Murphy Oil Corporation believes in providing energy that empowers people by doing right always, staying with it and thinking beyond possible. Murphy challenges the norm, taps into its strong legacy and uses its foresight and financial discipline to deliver inspired energy solutions. Murphy sees a future where it is an industry leader who is positively impacting lives for the next 100 years and beyond. Additional information can be found on the company’s website at www.murphyoilcorp.com.
FORWARD-LOOKING STATEMENTS
This news release contains forward-looking statements within the meaning of the Private Securities Litigation Reform Act of 1995. Forward-looking statements are generally identified through the inclusion of words such as “aim”, “anticipate”, “believe”, “drive”, “estimate”, “expect”, “expressed confidence”, “forecast”, “future”, “goal”, “guidance”, “intend”, “may”, “objective”, “outlook”, “plan”, “position”, “potential”, “project”, “seek”, “should”, “strategy”, “target”, “will” or variations of such words and other similar expressions. These statements, which express management’s current views concerning future events, results and plans, are subject to inherent risks, uncertainties and assumptions (many of which are beyond our control) and are not guarantees of performance. In particular, statements, express or implied, concerning the company’s future operating results or activities and returns or the company's ability and decisions to replace or increase reserves, increase production, generate returns and rates of return, replace or increase drilling locations, reduce or otherwise control operating costs and expenditures, generate cash flows, pay down or refinance indebtedness, achieve, reach or otherwise meet initiatives, plans, goals, ambitions or targets with respect to emissions, safety matters or other ESG (environmental/social/governance) matters, make capital expenditures or pay and/or increase dividends or make share repurchases and other capital allocation decisions are forward-looking statements. Factors that could cause one or more of these future events, results or plans not to occur as implied by any forward-looking statement, which consequently could cause actual results or activities to differ materially from the expectations expressed or implied by such forward-looking statements, include, but are not limited to: macro conditions in the oil and gas industry, including supply/demand levels, actions taken by major oil exporters and the resulting impacts on commodity prices; geopolitical concerns; increased volatility or deterioration in the success rate of our exploration programs or
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in our ability to maintain production rates and replace reserves; reduced customer demand for our products due to environmental, regulatory, technological or other reasons; adverse foreign exchange movements; political and regulatory instability in the markets where we do business; the impact on our operations or market of health pandemics such as COVID-19 and related government responses; other natural hazards impacting our operations or markets; any other deterioration in our business, markets or prospects; any failure to obtain necessary regulatory approvals; any inability to service or refinance our outstanding debt or to access debt markets at acceptable prices; or adverse developments in the U.S. or global capital markets, credit markets, banking system or economies in general, including inflation. For further discussion of factors that could cause one or more of these future events or results not to occur as implied by any forward-looking statement, see “Risk Factors” in our most recent Annual Report on Form 10-K filed with the U.S. Securities and Exchange Commission (“SEC”) and any subsequent Quarterly Report on Form 10-Q or Current Report on Form 8-K that we file, available from the SEC’s website and from Murphy Oil Corporation’s website at http://ir.murphyoilcorp.com. Investors and others should note that we may announce material information using SEC filings, press releases, public conference calls, webcasts and the investors page of our website. We may use these channels to distribute material information about the company; therefore, we encourage investors, the media, business partners and others interested in the company to review the information we post on our website. The information on our website is not part of, and is not incorporated into, this news release. Murphy Oil Corporation undertakes no duty to publicly update or revise any forward-looking statements.
NON-GAAP FINANCIAL MEASURES
This news release contains certain non-GAAP financial measures that management believes are useful tools for internal use and the investment community in evaluating Murphy Oil Corporation’s overall financial performance. These non-GAAP financial measures are broadly used to value and compare companies in the crude oil and natural gas industry. Not all companies define these measures in the same way. In addition, these non-GAAP financial measures are not a substitute for financial measures prepared in accordance with GAAP and should therefore be considered only as supplemental to such GAAP financial measures. Please see the attached schedules for reconciliations of the differences between the non-GAAP financial measures used in this news release and the most directly comparable GAAP financial measures.
Investor Contacts:
InvestorRelations@murphyoilcorp.com
Kelly Whitley, 281-675-9107
Megan Larson, 281-675-9470
Beth Heller, 832-506-6831
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MURPHY OIL CORPORATION
SUMMARIZED CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)
| Three Months Ended March 31, | |||||||||||
| (Thousands of dollars, except per share amounts) | 2024 | 2023 | |||||||||
| Revenues and other income | |||||||||||
| Revenue from production | $ | 794,603 | 796,231 | ||||||||
| Sales of purchased natural gas | 245 | 43,737 | |||||||||
| Total revenue from sales to customers | 794,848 | 839,968 | |||||||||
| Gain on sale of assets and other income | 1,564 | 1,748 | |||||||||
| Total revenues and other income | 796,412 | 841,716 | |||||||||
| Costs and expenses | |||||||||||
| Lease operating expenses | 234,264 | 199,984 | |||||||||
| Severance and ad valorem taxes | 10,086 | 11,440 | |||||||||
| Transportation, gathering and processing | 56,553 | 53,922 | |||||||||
| Costs of purchased natural gas | 160 | 32,269 | |||||||||
| Exploration expenses, including undeveloped lease amortization | 44,429 | 10,182 | |||||||||
| Selling and general expenses | 31,161 | 18,308 | |||||||||
| Depreciation, depletion and amortization | 211,134 | 195,670 | |||||||||
| Accretion of asset retirement obligations | 12,774 | 11,157 | |||||||||
| Other operating expense | 7,266 | 11,988 | |||||||||
| Impairment of assets | 34,528 | — | |||||||||
| Total costs and expenses | 642,355 | 544,920 | |||||||||
| Operating income from continuing operations | 154,057 | 296,796 | |||||||||
| Other loss | |||||||||||
| Other income (loss) | 11,551 | (73) | |||||||||
| Interest expense, net | (20,021) | (28,855) | |||||||||
| Total other loss | (8,470) | (28,928) | |||||||||
| Income from continuing operations before income taxes | 145,587 | 267,868 | |||||||||
| Income tax expense | 30,057 | 53,833 | |||||||||
| Income from continuing operations | 115,530 | 214,035 | |||||||||
| (Loss) gain from discontinued operations, net of income taxes | (872) | 279 | |||||||||
| Net income including noncontrolling interest | 114,658 | 214,314 | |||||||||
| Less: Net income attributable to noncontrolling interest | 24,656 | 22,670 | |||||||||
| NET INCOME ATTRIBUTABLE TO MURPHY | $ | 90,002 | 191,644 | ||||||||
| INCOME (LOSS) PER COMMON SHARE – BASIC | |||||||||||
| Continuing operations | $ | 0.60 | 1.23 | ||||||||
| Discontinued operations | (0.01) | — | |||||||||
| Net income | $ | 0.59 | 1.23 | ||||||||
| INCOME (LOSS) PER COMMON SHARE – DILUTED | |||||||||||
| Continuing operations | $ | 0.60 | 1.22 | ||||||||
| Discontinued operations | (0.01) | — | |||||||||
| Net income | $ | 0.59 | 1.22 | ||||||||
| Cash dividends per common share | $ | 0.300 | 0.275 | ||||||||
| Average common shares outstanding (thousands) | |||||||||||
| Basic | 152,664 | 155,857 | |||||||||
| Diluted | 153,817 | 157,389 | |||||||||
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MURPHY OIL CORPORATION
CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)
| Three Months Ended March 31, | |||||||||||
| (Thousands of dollars) | 2024 | 2023 | |||||||||
| Operating Activities | |||||||||||
| Net income including noncontrolling interest | $ | 114,658 | 214,314 | ||||||||
| Adjustments to reconcile net income to net cash provided by continuing operations activities | |||||||||||
| Depreciation, depletion and amortization | 211,134 | 195,670 | |||||||||
| Impairment of assets | 34,528 | — | |||||||||
| Unsuccessful exploration well costs and previously suspended exploration costs | 32,437 | 851 | |||||||||
| Deferred income tax expense | 19,478 | 49,042 | |||||||||
| Accretion of asset retirement obligations | 12,774 | 11,157 | |||||||||
| Long-term non-cash compensation | 9,851 | 8,536 | |||||||||
| Amortization of undeveloped leases | 2,793 | 2,653 | |||||||||
| Loss (gain) from discontinued operations | 872 | (279) | |||||||||
| Contingent consideration payment | — | (123,965) | |||||||||
| Mark-to-market loss on contingent consideration | — | 3,938 | |||||||||
| Other operating activities, net | (15,381) | (7,110) | |||||||||
| Net increase in non-cash working capital | (24,353) | (75,031) | |||||||||
| Net cash provided by continuing operations activities | 398,791 | 279,776 | |||||||||
| Investing Activities | |||||||||||
| Property additions and dry hole costs | (249,085) | (345,319) | |||||||||
| Net cash required by investing activities | (249,085) | (345,319) | |||||||||
| Financing Activities | |||||||||||
| Borrowings on revolving credit facility | 100,000 | 100,000 | |||||||||
| Repayment of revolving credit facility | (100,000) | (100,000) | |||||||||
| Repurchase of common stock | (50,000) | — | |||||||||
| Cash dividends paid | (45,773) | (42,925) | |||||||||
| Withholding tax on stock-based incentive awards | (25,270) | (14,217) | |||||||||
| Distributions to noncontrolling interest | (23,001) | (9,679) | |||||||||
| Finance lease obligation payments | (164) | (139) | |||||||||
| Contingent consideration payment | — | (47,678) | |||||||||
| Issue costs of debt facility | — | (17) | |||||||||
| Net cash required by financing activities | (144,208) | (114,655) | |||||||||
| Effect of exchange rate changes on cash and cash equivalents | 858 | 618 | |||||||||
| Net increase (decrease) in cash and cash equivalents | 6,356 | (179,580) | |||||||||
| Cash and cash equivalents at beginning of period | 317,074 | 491,963 | |||||||||
| Cash and cash equivalents at end of period | $ | 323,430 | 312,383 | ||||||||
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MURPHY OIL CORPORATION
SCHEDULE OF ADJUSTED NET INCOME (LOSS) (unaudited)
| Three Months Ended March 31, | |||||||||||
(Millions of dollars, except per share amounts) | 2024 | 2023 | |||||||||
Net income attributable to Murphy (GAAP) 1 | $ | 90.0 | 191.6 | ||||||||
| Discontinued operations (income) loss | 0.9 | (0.3) | |||||||||
| Net income from continuing operations attributable to Murphy | 90.9 | 191.3 | |||||||||
| Adjustments: | |||||||||||
| Impairment of assets | 34.5 | — | |||||||||
| Write-off of previously suspended exploration well | 26.1 | — | |||||||||
| Foreign exchange (gain) loss | (10.5) | 0.4 | |||||||||
| Mark-to-market loss on contingent consideration | — | 3.9 | |||||||||
| Total adjustments, before taxes | 50.1 | 4.3 | |||||||||
| Income tax benefit related to adjustments | (10.2) | (0.9) | |||||||||
| Total adjustments after taxes | 39.9 | 3.4 | |||||||||
| Adjusted net income from continuing operations attributable to Murphy (Non-GAAP) | $ | 130.8 | 194.7 | ||||||||
| Adjusted net income from continuing operations per average diluted share (Non-GAAP) | $ | 0.85 | 1.24 | ||||||||
1 Excludes results attributable to a noncontrolling interest in MP Gulf of Mexico, LLC (MP GOM).
Non-GAAP Financial Measures
Presented above is a reconciliation of Net income to Adjusted net income from continuing operations attributable to Murphy. Adjusted net income excludes certain items that management believes affect the comparability of results between periods. Management believes this is important information to provide because it is used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. Adjusted net income is a non-GAAP financial measure and should not be considered a substitute for Net income as determined in accordance with accounting principles generally accepted in the United States of America.
The pretax and income tax impacts for adjustments shown above are as follows by area of operations and exclude the share attributable to non-controlling interests.
| Three Months Ended March 31, 2024 | |||||||||||||||||
| (Millions of dollars) | Pretax | Tax | Net | ||||||||||||||
Exploration & Production: | |||||||||||||||||
| United States | $ | 60.6 | (12.9) | 47.7 | |||||||||||||
| Corporate | (10.5) | 2.7 | (7.8) | ||||||||||||||
Total adjustments | $ | 50.1 | (10.2) | 39.9 | |||||||||||||
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MURPHY OIL CORPORATION
SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION
AND AMORTIZATION (EBITDA)
(unaudited)
| Three Months Ended March 31, | |||||||||||
| (Millions of dollars) | 2024 | 2023 | |||||||||
Net income attributable to Murphy (GAAP) 1 | $ | 90.0 | 191.6 | ||||||||
| Income tax expense | 30.1 | 53.8 | |||||||||
| Interest expense, net | 20.0 | 28.9 | |||||||||
Depreciation, depletion and amortization expense 1 | 202.7 | 189.3 | |||||||||
| EBITDA attributable to Murphy (Non-GAAP) | $ | 342.8 | 463.6 | ||||||||
| Impairment of asset | 34.5 | — | |||||||||
| Write-off of previously suspended exploration well | 26.1 | — | |||||||||
Accretion of asset retirement obligations 1 | 11.4 | 9.9 | |||||||||
| Foreign exchange (gain) loss | (10.5) | 0.4 | |||||||||
| Mark-to-market loss on contingent consideration | — | 3.9 | |||||||||
| Discontinued operations loss (income) | 0.9 | (0.3) | |||||||||
| Adjusted EBITDA attributable to Murphy (Non-GAAP) | $ | 405.2 | 477.5 | ||||||||
1 Excludes results attributable to a noncontrolling interest in MP GOM.
Non-GAAP Financial Measures
Presented above is a reconciliation of Net income to Earnings before interest, taxes, depreciation and amortization (EBITDA) and Adjusted EBITDA. Management believes EBITDA and Adjusted EBITDA are important information to provide because they are used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. EBITDA and Adjusted EBITDA are non-GAAP financial measures and should not be considered a substitute for Net income or Cash provided by operating activities as determined in accordance with accounting principles generally accepted in the United States of America.
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MURPHY OIL CORPORATION
SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION
AND AMORTIZATION AND EXPLORATION (EBITDAX)
(unaudited)
| Three Months Ended March 31, | |||||||||||
| (Millions of dollars) | 2024 | 2023 | |||||||||
Net income attributable to Murphy (GAAP) 1 | $ | 90.0 | 191.6 | ||||||||
| Income tax expense | 30.1 | 53.8 | |||||||||
| Interest expense, net | 20.0 | 28.9 | |||||||||
Depreciation, depletion and amortization expense 1 | 202.7 | 189.3 | |||||||||
| EBITDA attributable to Murphy (Non-GAAP) | 342.8 | 463.6 | |||||||||
| Exploration expenses | 44.4 | 10.2 | |||||||||
| EBITDAX attributable to Murphy (Non-GAAP) | 387.2 | 473.8 | |||||||||
Accretion of asset retirement obligations 1 | 11.4 | 9.9 | |||||||||
| Impairment of asset | 34.5 | — | |||||||||
| Foreign exchange (gain) loss | (10.5) | 0.4 | |||||||||
| Mark-to-market loss on contingent consideration | — | 3.9 | |||||||||
| Discontinued operations loss (income) | 0.9 | (0.3) | |||||||||
| Adjusted EBITDAX attributable to Murphy (Non-GAAP) | $ | 423.5 | 487.7 | ||||||||
1 Excludes results attributable to a noncontrolling interest in MP GOM.
Non-GAAP Financial Measures
Presented above is a reconciliation of Net income to Earnings before interest, taxes, depreciation and amortization, and exploration expenses (EBITDAX) and Adjusted EBITDAX. Management believes EBITDAX and Adjusted EBITDAX are important information to provide because they are used by management to evaluate the Company’s operational performance and trends between periods and relative to its industry competitors. Management also believes this information may be useful to investors and analysts to gain a better understanding of the Company’s financial results. EBITDAX and Adjusted EBITDAX are non-GAAP financial measures and should not be considered a substitute for Net income or Cash provided by operating activities as determined in accordance with accounting principles generally accepted in the United States of America.
11
MURPHY OIL CORPORATION
FUNCTIONAL RESULTS OF OPERATIONS (unaudited)
| Three Months Ended March 31, 2024 | Three Months Ended March 31, 2023 | |||||||||||||
(Millions of dollars) | Revenues | Income (Loss) | Revenues | Income (Loss) | ||||||||||
| Exploration and production | ||||||||||||||
| United States ¹ | $ | 659.6 | 134.5 | 682.3 | 226.0 | |||||||||
| Canada | 136.9 | 19.4 | 155.8 | 21.9 | ||||||||||
| Other | (0.1) | (10.8) | 3.6 | (5.2) | ||||||||||
| Total exploration and production | 796.4 | 143.1 | 841.7 | 242.7 | ||||||||||
| Corporate | — | (27.5) | — | (28.7) | ||||||||||
| Continuing operations | 796.4 | 115.6 | 841.7 | 214.0 | ||||||||||
| Discontinued operations, net of tax | — | (0.9) | — | 0.3 | ||||||||||
| Total including noncontrolling interest | $ | 796.4 | 114.7 | 841.7 | 214.3 | |||||||||
| Net income attributable to Murphy | $ | 90.0 | 191.6 | |||||||||||
1 Includes results attributable to a noncontrolling interest in MP GOM.
12
MURPHY OIL CORPORATION
OIL AND GAS OPERATING RESULTS (unaudited)
THREE MONTHS ENDED MARCH 31, 2024, AND 2023
(Millions of dollars) | United States 1 | Canada | Other | Total | ||||||||||
| Three Months Ended March 31, 2024 | ||||||||||||||
| Oil and gas sales and other operating revenues | $ | 659.6 | 136.7 | (0.1) | 796.2 | |||||||||
| Sales of purchased natural gas | — | 0.2 | — | 0.2 | ||||||||||
| Lease operating expenses | 186.6 | 47.5 | 0.2 | 234.3 | ||||||||||
| Severance and ad valorem taxes | 9.8 | 0.3 | — | 10.1 | ||||||||||
| Transportation, gathering and processing | 36.6 | 19.9 | — | 56.5 | ||||||||||
| Costs of purchased natural gas | — | 0.2 | — | 0.2 | ||||||||||
| Depreciation, depletion and amortization | 174.0 | 34.3 | — | 208.3 | ||||||||||
| Accretion of asset retirement obligations | 10.4 | 2.1 | 0.2 | 12.7 | ||||||||||
| Impairment of assets | 34.5 | — | — | 34.5 | ||||||||||
| Exploration expenses | ||||||||||||||
| Dry holes and previously suspended exploration costs | 31.2 | — | 1.2 | 32.4 | ||||||||||
| Geological and geophysical | 0.6 | — | 0.8 | 1.4 | ||||||||||
| Other exploration | 1.4 | 0.1 | 6.3 | 7.8 | ||||||||||
| Undeveloped lease amortization | 2.0 | — | 0.8 | 2.8 | ||||||||||
| Total exploration expenses | 35.2 | 0.1 | 9.1 | 44.4 | ||||||||||
| Selling and general expenses | (0.2) | 5.1 | 1.2 | 6.1 | ||||||||||
| Other | 7.4 | 1.1 | 0.3 | 8.8 | ||||||||||
| Results of operations before taxes | 165.3 | 26.3 | (11.1) | 180.5 | ||||||||||
Income tax provisions (benefits) | 30.8 | 6.9 | (0.3) | 37.4 | ||||||||||
| Results of operations (excluding Corporate segment) | $ | 134.5 | 19.4 | (10.8) | 143.1 | |||||||||
| Three Months Ended March 31, 2023 | ||||||||||||||
| Oil and gas sales and other operating revenues | $ | 682.3 | 112.1 | 3.6 | 798.0 | |||||||||
| Sales of purchased natural gas | — | 43.7 | — | 43.7 | ||||||||||
| Lease operating expenses | 162.6 | 36.8 | 0.6 | 200.0 | ||||||||||
| Severance and ad valorem taxes | 11.1 | 0.3 | — | 11.4 | ||||||||||
| Transportation, gathering and processing | 37.4 | 16.5 | — | 53.9 | ||||||||||
| Costs of purchased natural gas | — | 32.3 | — | 32.3 | ||||||||||
| Depreciation, depletion and amortization | 160.3 | 31.6 | 0.9 | 192.8 | ||||||||||
| Accretion of asset retirement obligations | 9.1 | 1.9 | 0.1 | 11.1 | ||||||||||
| Exploration expenses | ||||||||||||||
| Dry holes and previously suspended exploration costs | (0.2) | — | 1.1 | 0.9 | ||||||||||
| Geological and geophysical | 0.3 | — | 0.5 | 0.8 | ||||||||||
| Other exploration | 1.6 | 0.1 | 4.2 | 5.9 | ||||||||||
| Undeveloped lease amortization | 2.0 | 0.1 | 0.6 | 2.7 | ||||||||||
| Total exploration expenses | 3.7 | 0.2 | 6.4 | 10.3 | ||||||||||
| Selling and general expenses | 6.4 | 2.3 | 0.2 | 8.9 | ||||||||||
| Other | 9.4 | 4.4 | (0.2) | 13.6 | ||||||||||
| Results of operations before taxes | 282.3 | 29.5 | (4.4) | 307.4 | ||||||||||
Income tax provisions | 56.3 | 7.6 | 0.8 | 64.7 | ||||||||||
| Results of operations (excluding Corporate segment) | $ | 226.0 | 21.9 | (5.2) | 242.7 | |||||||||
1 Includes results attributable to a noncontrolling interest in MP GOM.
13
MURPHY OIL CORPORATION
PRODUCTION-RELATED EXPENSES
(unaudited)
| Three Months Ended March 31, | |||||||||||
(Dollars per barrel of oil equivalents sold) | 2024 | 2023 | |||||||||
United States – Onshore | |||||||||||
Lease operating expense | $ | 13.68 | 15.08 | ||||||||
Severance and ad valorem taxes | 3.60 | 4.23 | |||||||||
Depreciation, depletion and amortization (DD&A) expense | 28.46 | 26.13 | |||||||||
United States – Offshore1 | |||||||||||
Lease operating expense | $ | 20.34 | 14.69 | ||||||||
| Severance and ad valorem taxes | 0.06 | 0.08 | |||||||||
DD&A expense | 13.46 | 11.22 | |||||||||
Canada – Onshore | |||||||||||
Lease operating expense | $ | 5.49 | 6.81 | ||||||||
Severance and ad valorem taxes | 0.05 | 0.06 | |||||||||
DD&A expense | 4.99 | 6.01 | |||||||||
Canada – Offshore | |||||||||||
| Lease operating expense | $ | 25.91 | 15.06 | ||||||||
DD&A expense | 9.68 | 9.29 | |||||||||
Total E&P continuing operations1 | |||||||||||
| Lease operating expense | $ | 14.37 | 12.35 | ||||||||
Severance and ad valorem taxes | 0.62 | 0.71 | |||||||||
DD&A expense2 | 12.77 | 11.90 | |||||||||
| Total oil and gas continuing operations – excluding noncontrolling interest | |||||||||||
Lease operating expense 3 | $ | 14.28 | 12.19 | ||||||||
Severance and ad valorem taxes | 0.64 | 0.73 | |||||||||
DD&A expense2 | 12.79 | 11.99 | |||||||||
1 Includes results attributable to a noncontrolling interest in MP GOM.
2 Excludes expenses attributable to the Corporate segment.
3 Lease operating expense per barrel of oil equivalent sold for total oil and gas continuing operations, excluding NCI and workover costs, was $10.75 and $11.35 for the three months ended March 31, 2024, and 2023, respectively.
14
MURPHY OIL CORPORATION
CAPITAL EXPENDITURES
(unaudited)
| Three Months Ended March 31, | |||||||||||
(Millions of dollars) | 2024 | 2023 | |||||||||
| Exploration and production | |||||||||||
United States1 | $ | 188.5 | 254.7 | ||||||||
| Canada | 67.3 | 68.1 | |||||||||
| Other | 11.3 | 6.9 | |||||||||
| Total | 267.1 | 329.7 | |||||||||
| Corporate | 4.2 | 6.3 | |||||||||
Total capital expenditures - continuing operations2 | 271.3 | 336.0 | |||||||||
Charged to exploration expenses3 | |||||||||||
United States1 | 33.2 | 1.7 | |||||||||
| Canada | 0.1 | 0.1 | |||||||||
| Other | 8.3 | 5.8 | |||||||||
| Total charged to exploration expenses - continuing operations | 41.6 | 7.6 | |||||||||
| Total capitalized | $ | 229.7 | 328.4 | ||||||||
1 Includes results attributable to a noncontrolling interest in MP GOM.
2 For the three months ended March 31, 2024, total capital expenditures excluding noncontrolling interest (NCI) of $7.3 million (2023: $8.9 million) are $264.0 million (2023: $327.1 million).
3 For the three months ended March 31, 2024, charges to exploration expense exclude amortization of undeveloped leases of $2.8 million (2023: $2.7 million).
15
MURPHY OIL CORPORATION
CONSOLIDATED BALANCE SHEETS
(unaudited)
| (Thousands of dollars) | March 31, 2024 | December 31, 2023 | |||||||||
| ASSETS | |||||||||||
| Current assets | |||||||||||
| Cash and cash equivalents | $ | 323,430 | 317,074 | ||||||||
Accounts receivable, net | 356,863 | 343,992 | |||||||||
| Inventories | 49,662 | 54,454 | |||||||||
| Prepaid expenses | 30,934 | 36,674 | |||||||||
| Total current assets | 760,889 | 752,194 | |||||||||
Property, plant and equipment, at cost less accumulated depreciation, depletion and amortization | 8,188,903 | 8,225,197 | |||||||||
| Operating lease assets | 681,766 | 745,185 | |||||||||
| Deferred income taxes | 434 | 435 | |||||||||
| Deferred charges and other assets | 36,668 | 43,686 | |||||||||
| Total assets | $ | 9,668,660 | 9,766,697 | ||||||||
| LIABILITIES AND EQUITY | |||||||||||
| Current liabilities | |||||||||||
| Current maturities of long-term debt, finance lease | $ | 730 | 723 | ||||||||
| Accounts payable | 485,892 | 446,891 | |||||||||
| Income taxes payable | 24,710 | 21,007 | |||||||||
| Other taxes payable | 26,096 | 29,339 | |||||||||
| Operating lease liabilities | 179,471 | 207,840 | |||||||||
| Other accrued liabilities | 101,253 | 140,745 | |||||||||
| Total current liabilities | 818,152 | 846,545 | |||||||||
| Long-term debt, including finance lease obligation | 1,328,669 | 1,328,352 | |||||||||
| Asset retirement obligations | 916,815 | 904,051 | |||||||||
| Deferred credits and other liabilities | 303,951 | 309,605 | |||||||||
| Non-current operating lease liabilities | 516,520 | 551,845 | |||||||||
| Deferred income taxes | 292,048 | 276,646 | |||||||||
| Total liabilities | 4,176,155 | 4,217,044 | |||||||||
| Equity | |||||||||||
| Common Stock, par $1.00 | $ | 195,101 | 195,101 | ||||||||
| Capital in excess of par value | 816,815 | 880,297 | |||||||||
| Retained earnings | 6,590,308 | 6,546,079 | |||||||||
| Accumulated other comprehensive loss | (555,735) | (521,117) | |||||||||
| Treasury stock | (1,742,498) | (1,737,566) | |||||||||
| Murphy Shareholders' Equity | 5,303,991 | 5,362,794 | |||||||||
| Noncontrolling interest | 188,514 | 186,859 | |||||||||
| Total equity | 5,492,505 | 5,549,653 | |||||||||
| Total liabilities and equity | $ | 9,668,660 | 9,766,697 | ||||||||
16
MURPHY OIL CORPORATION
PRODUCTION SUMMARY
(unaudited)
| Three Months Ended March 31, | ||||||||||||||
| (Barrels per day unless otherwise noted) | 2024 | 2023 | ||||||||||||
| Net crude oil and condensate | ||||||||||||||
United States - Onshore | 20,382 | 19,277 | ||||||||||||
United States - Offshore 1 | 66,078 | 75,699 | ||||||||||||
Canada - Onshore | 2,255 | 3,283 | ||||||||||||
Canada - Offshore | 6,264 | 2,459 | ||||||||||||
| Other | 245 | 269 | ||||||||||||
Total net crude oil and condensate | 95,224 | 100,987 | ||||||||||||
| Net natural gas liquids | ||||||||||||||
United States - Onshore | 4,166 | 4,157 | ||||||||||||
United States - Offshore 1 | 4,687 | 6,342 | ||||||||||||
Canada - Onshore | 453 | 826 | ||||||||||||
Total net natural gas liquids | 9,306 | 11,325 | ||||||||||||
| Net natural gas – thousands of cubic feet per day | ||||||||||||||
United States - Onshore | 24,231 | 24,160 | ||||||||||||
United States - Offshore 1 | 53,161 | 75,203 | ||||||||||||
Canada - Onshore | 355,455 | 305,232 | ||||||||||||
Total net natural gas | 432,847 | 404,595 | ||||||||||||
Total net hydrocarbons - including NCI 2,3 | 176,671 | 179,745 | ||||||||||||
| Noncontrolling interest | ||||||||||||||
| Net crude oil and condensate – barrels per day | (6,499) | (6,613) | ||||||||||||
| Net natural gas liquids – barrels per day | (211) | (232) | ||||||||||||
Net natural gas – thousands of cubic feet per day | (2,074) | (2,354) | ||||||||||||
Total noncontrolling interest 2,3 | (7,056) | (7,237) | ||||||||||||
Total net hydrocarbons - excluding NCI 2,3 | 169,615 | 172,508 | ||||||||||||
1 Includes net volumes attributable to a noncontrolling interest in MP GOM.
2 Natural gas converted on an energy equivalent basis of 6:1.
3 NCI – noncontrolling interest in MP GOM.
17
MURPHY OIL CORPORATION
WEIGHTED AVERAGE PRICE SUMMARY
(unaudited)
| Three Months Ended March 31, | |||||||||||
| 2024 | 2023 | ||||||||||
| Crude oil and condensate – dollars per barrel | |||||||||||
United States - Onshore | $ | 76.85 | 74.98 | ||||||||
United States - Offshore 1 | 77.58 | 73.27 | |||||||||
Canada - Onshore 2 | 67.59 | 74.29 | |||||||||
Canada - Offshore 2 | 85.99 | 77.93 | |||||||||
Other 2 | — | 89.05 | |||||||||
| Natural gas liquids – dollars per barrel | |||||||||||
| United States - Onshore | 20.67 | 22.11 | |||||||||
United States - Offshore 1 | 24.32 | 25.63 | |||||||||
Canada - Onshore 2 | 34.84 | 46.59 | |||||||||
| Natural gas – dollars per thousand cubic feet | |||||||||||
| United States - Onshore | 1.94 | 2.51 | |||||||||
United States - Offshore 1 | 2.66 | 3.27 | |||||||||
Canada - Onshore 2 | 2.05 | 2.55 | |||||||||
1 Prices include the effect of noncontrolling interest in MP GOM.
2 U.S. dollar equivalent.
18
MURPHY OIL CORPORATION
FIXED PRICE FORWARD SALES AND COMMODITY HEDGE POSITIONS
AS OF APRIL 30, 2024
(unaudited)
| Volumes (MMcf/d) | Price/MCF | Remaining Period | ||||||||||||||||||||||||||||||||||||
| Area | Commodity | Type 1 | Start Date | End Date | ||||||||||||||||||||||||||||||||||
| Canada | Natural Gas | Fixed price forward sales | 162 | C$2.39 | 4/1/2024 | 12/31/2024 | ||||||||||||||||||||||||||||||||
| Canada | Natural Gas | Fixed price forward sales | 25 | US$1.98 | 4/1/2024 | 10/31/2024 | ||||||||||||||||||||||||||||||||
| Canada | Natural Gas | Fixed price forward sales | 15 | US$1.98 | 11/1/2024 | 12/31/2024 | ||||||||||||||||||||||||||||||||
1 Fixed price forward sale contracts are accounted for as normal sales and purchases for accounting purposes.
19
MURPHY OIL CORPORATION
SECOND QUARTER 2024 GUIDANCE
| Oil BOPD | NGLs BOPD | Gas MCFD | Total BOEPD | ||||||||||||||||||||
| Production – net | |||||||||||||||||||||||
U.S. – Eagle Ford Shale | 18,500 | 4,000 | 22,700 | 26,300 | |||||||||||||||||||
| – Gulf of Mexico excluding NCI | 61,700 | 4,600 | 58,700 | 76,100 | |||||||||||||||||||
| Canada – Tupper Montney | — | — | 380,600 | 63,400 | |||||||||||||||||||
| – Kaybob Duvernay and Placid Montney | 2,200 | 500 | 7,800 | 4,000 | |||||||||||||||||||
| – Offshore | 10,000 | — | — | 10,000 | |||||||||||||||||||
| Other | 200 | — | — | 200 | |||||||||||||||||||
Total net production (BOEPD) - excluding NCI 1 | 176,000 to 184,000 | ||||||||||||||||||||||
| Exploration expense ($ millions) | $65 | ||||||||||||||||||||||
| FULL YEAR 2024 GUIDANCE | |||||||||||||||||||||||
Total net production (BOEPD) - excluding NCI 2 | 180,000 to 188,000 | ||||||||||||||||||||||
Capital expenditures – excluding NCI ($ millions) 3 | $920 to $1,020 | ||||||||||||||||||||||
| ¹ Excludes noncontrolling interest of MP GOM of 6,700 BOPD of oil, 300 BOPD of NGLs, and 2,500 MCFD gas. | |||||||||||||||||||||||
| ² Excludes noncontrolling interest of MP GOM of 6,600 BOPD of oil, 300 BOPD of NGLs, and 2,500 MCFD gas. | |||||||||||||||||||||||
| ³ Excludes noncontrolling interest of MP GOM of $22 million. | |||||||||||||||||||||||
20