Murphy Oil Corporation Announces Second Quarter 2023 Financial and Operating Results, Strategic Portfolio Repositioning

Rhea-AI Summary

Murphy Oil Corporation (NYSE: MUR) announced Q2 2023 financial results, exceeding production guidance at 184 MBOEPD, signing production sharing contracts for Côte d’Ivoire, and divesting non-core Canadian assets for C$150 million. Net income was $98 million, adjusted net income was $124 million. EBITDA was $373 million, and EBITDAX was $463 million.

Positive

• Exceeded upper end of production guidance range with 184 MBOEPD
• Signed production sharing contracts for Côte d’Ivoire new country entry
• Net income of $98 million, adjusted net income of $124 million
• EBITDA of $373 million, EBITDAX of $463 million
• Divested non-core Canadian assets for C$150 million

Negative

• None.

Exceeded Upper End of Guidance Range With Production of 184 MBOEPD,

Signed Production Sharing Contracts for Côte d’Ivoire New Country Entry,

Executed Agreement to Divest Non-Core Canadian Assets

HOUSTON--(BUSINESS WIRE)-- Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the second quarter ended June 30, 2023, including net income attributable to Murphy of $98 million, or $0.62 net income per diluted share. Excluding discontinued operations and other items affecting comparability between periods, adjusted net income attributable to Murphy was $124 million, or $0.79 adjusted net income per diluted share.

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

Highlights for the second quarter include:

• Exceeded upper end of guidance range with production of 184 thousand barrels of oil equivalent per day (MBOEPD), including 99 thousand barrels of oil per day (MBOPD)
• Received government approval on Block 15-1/05 Lac Da Vang field development plan in Vietnam
• Signed production sharing contracts (PSCs) for five blocks offshore Côte d’Ivoire

Subsequent to the second quarter:

• Signed a Purchase and Sale Agreement to divest a portion of Kaybob Duvernay and Placid Montney assets for C$150 million net purchase price
• Published the fifth annual Sustainability Report with enhanced disclosures on improved environmental activities, increased community support and continuing strong governance oversight

“Murphy’s operational excellence continues to shine as our portfolio again outperformed expectations this quarter. From offshore maintenance being completed faster than scheduled to onshore wells achieving production rates above type curves, our team has done a great job executing our 2023 plan. We also have exciting opportunities ahead, including advancing the Vietnam Lac Da Vang field development plan towards project sanction as well as evaluating our new Côte d’Ivoire acreage. I look forward to progressing our capital allocation framework this year with increasing returns to shareholders and additional debt reduction, which will be supported by monetizing a non-core portion of our Canadian assets,” said Roger W. Jenkins, President and Chief Executive Officer. “Additionally, Murphy continues to operate sustainably, and we were recently recognized by Rystad Energy as the highest-scoring company in ESG performance for the 2021 reporting year across 41 operators in the United States and Canada.”

SECOND QUARTER 2023 RESULTS

The company recorded net income attributable to Murphy of $98 million, or $0.62 net income per diluted share, for the second quarter 2023. Adjusted net income, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, was $124 million, or $0.79 adjusted net income per diluted share for the same period. Adjustments to net income total $28 million before tax. Details for second quarter results and an adjusted net income reconciliation can be found in the attached schedules.

Including NCI, second quarter 2023 exploration expense of $116 million contains three primary items: $80 million of dry hole expense for the Chinook #7 exploration well in the Gulf of Mexico, inclusive of $26 million attributable to NCI; a $17 million write-off of the previously suspended Cholula-1EXP exploration well in offshore Mexico; and $10 million in seismic costs for the Côte d’Ivoire new country entry.

Earnings before interest, taxes, depreciation and amortization (EBITDA) attributable to Murphy were $373 million. Earnings before interest, tax, depreciation, amortization and exploration expenses (EBITDAX) attributable to Murphy were $463 million. Adjusted EBITDA attributable to Murphy was $412 million. Adjusted EBITDAX attributable to Murphy was $485 million. Reconciliations for second quarter EBITDA, EBITDAX, adjusted EBITDA and adjusted EBITDAX can be found in the attached schedules.

In the second quarter, Murphy paid the final contingent consideration payments of $28 million related to the Gulf of Mexico acquisition that closed in 2019. This amount was primarily attributable to the one-year anniversary of achieving first oil at King’s Quay. Murphy has no remaining contingent consideration payment obligations.

Second quarter production averaged 184 MBOEPD and consisted of 54 percent oil volumes, or 99 MBOPD. Production for the quarter exceeded the upper end of the guidance range, primarily driven by 2.5 MBOEPD of strong well performance in the Gulf of Mexico, 2.1 MBOEPD in the Tupper Montney and 1.5 MBOEPD in the Eagle Ford Shale, as well as 1.4 MBOEPD attributed to lower realized royalty rates in the Tupper Montney natural gas asset. Details for second quarter production can be found in the attached schedules.

FINANCIAL POSITION

Murphy had approximately $1.1 billion of liquidity on June 30, 2023, with no borrowings on the $800 million credit facility and $369 million of cash and cash equivalents, inclusive of NCI.

On June 30, 2023, the company’s total debt was unchanged from year-end 2022 at $1.82 billion, and consisted of long-term, fixed-rate notes with a weighted average maturity of 7.2 years and a weighted average coupon of 6.1 percent.

CANADA TRANSACTION SUMMARY

Subsequent to quarter end, a subsidiary of Murphy signed a Purchase and Sale Agreement to divest a non-core portion of its operated Kaybob Duvernay assets and all of its non-operated Placid Montney assets to a private company. Under the terms of the agreement, the buyer will pay Murphy C$150 million at closing in an all-cash transaction, subject to customary closing adjustments and conditions. The transaction has a March 1, 2023 effective date, with closing anticipated to occur in the third quarter of 2023.

The assets to be divested include the Saxon and Simonette areas of the Kaybob Duvernay, where Murphy holds a 70 percent working interest as operator, as well as Murphy’s 30 percent working interest in the Placid Montney assets operated by Athabasca Oil Corporation. Also included are batteries, pipelines and the assumption of related processing and marketing contracts.

The combined assets currently produce approximately 1,700 barrels of oil equivalent per day (BOEPD) net and are comprised of 39 percent oil. Net proved reserves are 5.3 million barrels of oil equivalent (MMBOE) as of December 31, 2022. Also included are 250 gross drilling locations, or 138 net, across 42,000 net acres in Kaybob Duvernay and 26,000 net acres in Placid Montney. After the transaction closes, Murphy will have approximately 488 gross drilling locations with an average 75 percent oil weighting remaining in the Kaybob Duvernay, all of which are operated with a 70 percent working interest. Murphy will have no remaining position in the Placid Montney.

“This transaction brings forward the value of a small, non-core portion of our onshore Canadian portfolio, as we were not planning to develop these locations for many years. I look forward to progressing our capital allocation framework goals in Murphy 2.0 with the proceeds from this divestiture, and continuing to reward our supportive, long-term shareholders in the upcoming quarters,” said Jenkins.

OPERATIONS SUMMARY

Onshore

In the second quarter of 2023, the onshore business produced approximately 98 MBOEPD, which included 36 percent liquids volumes.

Eagle Ford Shale – Production averaged 35 MBOEPD with 76 percent oil volumes and 89 percent liquids volumes. As planned, during the second quarter Murphy brought nine Catarina and eight Tilden operated wells online. Murphy continues to see stronger performance from completion design improvements across its well locations, including promising results in its new Tilden wells with an average gross 30-day (IP30) rate of approximately 1,200 BOEPD with 85 percent oil.

Tupper Montney – Natural gas production averaged 341 million cubic feet per day (MMCFD) in the second quarter, with 10 operated wells brought online. Of those wells, seven were brought on early that were originally planned for the third quarter. Production for the quarter exceeded guidance by 21 MMCFD, which included 13 MMCFD of improved well performance as Murphy realized its highest initial production rates in Tupper Montney history, as well as an 8 MMCFD benefit from a lower realized royalty rate of 2.4 percent.

“Our new onshore well completion design, developed within the last three years, is paying off with higher initial production rates,” said Jenkins. “With this new design, we have achieved continued exceptional results from new wells in both our Eagle Ford Shale and Tupper Montney assets.”

Kaybob Duvernay – During the second quarter, production averaged 4 MBOEPD with 60 percent liquids volumes. Production was minimally impacted from wildfires during the quarter, and no damage was sustained to facilities.

Offshore

Excluding NCI, the offshore business produced approximately 87 MBOEPD for the second quarter, which included 80 percent oil.

Gulf of Mexico – Production averaged approximately 84 MBOEPD, consisting of 79 percent oil during the second quarter. Facility maintenance was completed as planned during the quarter, with work at King’s Quay concluded ahead of schedule.

Canada – In the second quarter, production averaged 3 MBOEPD, consisting of 100 percent oil. The asset life extension project is progressing for the non-operated Terra Nova floating, production, storage and offloading vessel, which Murphy anticipates will return to production by year-end 2023.

Vietnam – As previously disclosed, during the second quarter Murphy received government approval of the Block 15-1/05 Lac Da Vang field development plan in the Cuu Long Basin. Murphy holds a 40 percent working interest as operator of the block. PetroVietnam Exploration Production Corporation Limited and SK Earthon Co., Ltd. hold the remaining 35 percent and 25 percent working interest, respectively. Murphy is working to advance the development project in preparation for final review and sanction in late 2023.

EXPLORATION

Côte d’Ivoire – During the second quarter, Murphy signed production sharing contracts to secure working interests as operator in five deepwater blocks in the Tano Basin offshore Côte d’Ivoire. Murphy will initially hold a 90 percent working interest in four blocks, with an 85 percent working interest in the fifth block. Société Nationale d’Opérations Pétrolières de la Côte d’Ivoire (PETROCI) holds the remaining working interest for each block.

Included in Block CI-103 is the Paon discovery, which was appraised with multiple wells by a previous operator. The PSC for the block includes a commitment to formulate and submit a viable field development plan for this discovery by the end of 2025.

“We are excited for our new country entry as an operator in Côte d’Ivoire, and are pleased with the competitive terms and low entry cost,” said Jenkins. “These blocks offer tremendous opportunities for exploration, and we look forward to maturing geophysical studies in this area and working with PETROCI on the possible development of the Paon discovery.”

Gulf of Mexico – Following the quarter, Murphy, as operator of its subsidiary MP Gulf of Mexico, LLC, concluded drilling the Chinook #7 exploration well in Walker Ridge 425. The well encountered non-commercial hydrocarbons. Murphy plugged and abandoned the well, and approximately $80 million of the well cost before tax, inclusive of $26 million attributable to NCI, was expensed in the second quarter. Murphy holds a 66.66 percent working interest in the well.

As previously announced, during the second quarter Murphy, as operator, drilled a discovery at the Longclaw #1 exploration well. The company holds a 14.5 percent working interest in the well. The well reached a total measured depth of 25,106 feet at a net cost of approximately $6 million. The well encountered approximately 62 feet of net oil pay and is undergoing further evaluation.

Also during the quarter, Murphy was awarded five exploration blocks from the Gulf of Mexico Federal Lease Sale 259 with an average working interest of 90 percent.

Mexico – In conjunction with the July 2023 expiration of the Cholula appraisal period, Murphy wrote off previously suspended exploration well costs of $17 million.

2023 CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE

Second quarter accrued capital expenditures (CAPEX) of $300 million, excluding lease acquisition costs, was lower than guidance due to timing of non-operated activity. Murphy accrued a total of $32 million in acquisition-related costs during the quarter, which will be paid in third quarter 2023.

Murphy is tightening its 2023 accrued CAPEX range to $950 million to $1.025 billion, which excludes $45 million in acquisition-related CAPEX for Côte d’Ivoire and Vietnam.

The company is raising its full year 2023 production range of 180 to 186 MBOEPD, consisting of approximately 53 percent oil and 59 percent liquids volumes.

Production for third quarter 2023 is estimated to be in the range of 188 to 196 MBOEPD with 99 MBOPD, or 52 percent, oil volumes. This range includes assumed Gulf of Mexico storm downtime of 4.6 MBOEPD, as well as operated planned downtime of 2.3 MBOEPD onshore and 600 BOEPD offshore. Murphy forecasts third quarter accrued CAPEX of $215 million, excluding acquisition-related costs.

Both production and CAPEX guidance ranges exclude NCI. Production guidance will be adjusted following closing of the Canadian divestiture announced today.

Detailed guidance for the third quarter and full year 2023 is contained in the attached schedules.

FIXED PRICE FORWARD SALES CONTRACTS

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

CONFERENCE CALL AND WEBCAST SCHEDULED FOR AUGUST 3, 2023

Murphy will host a conference call to discuss second quarter 2023 financial and operating results on Thursday, August 3, 2023, at 9:00 a.m. EDT. The call can be accessed either via the Internet through the Investor Relations section of Murphy Oil’s website at http://ir.murphyoilcorp.com or via the telephone by dialing toll free 1-888-886-7786, reservation number 24655854.

FINANCIAL DATA

Summary financial data and operating statistics for second quarter 2023, with comparisons to the same period from the previous year, are contained in the following schedules. Additionally, a schedule indicating the impacts of items affecting comparability of results between periods, a reconciliation of EBITDA, EBITDAX, adjusted EBITDA and adjusted EBITDAX between periods, as well as guidance for the third quarter and full year 2023, 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 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; increased volatility or deterioration in the success rate of our exploration programs or in our ability to maintain production rates and replace reserves; reduced customer demand for our products due to environmental, regulatory, technological or other reasons; adverse foreign exchange movements; political and regulatory instability in the markets where we do business; the impact on our operations or market of health pandemics such as COVID-19 and related government responses; other natural hazards impacting our operations or markets; any other deterioration in our business, markets or prospects; any failure to obtain necessary regulatory approvals; any inability to service or refinance our outstanding debt or to access debt markets at acceptable prices; or adverse developments in the U.S. or global capital markets, credit markets, banking system or economies in general. 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 report. Murphy Oil Corporation undertakes no duty to publicly update or revise any forward-looking statements.

NON-GAAP FINANCIAL MEASURES

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

MURPHY OIL CORPORATION SUMMARIZED CONSOLIDATED STATEMENTS OF OPERATIONS (unaudited)
	Three Months Ended June 30,							Six Months Ended June 30,
(Thousands of dollars, except per share amounts)	2023				2022			2023				2022
Revenues and other income
Revenue from production	$	799,836			1,146,299			$	1,596,067			1,980,827
Sales of purchased natural gas		13,014			49,939				56,751			86,785
Total revenue from sales to customers		812,850			1,196,238				1,652,818			2,067,612
Loss on derivative instruments		—			(103,068	)			—			(423,845	)
Gain on sale of assets and other income		1,738			7,887				3,486			10,251
Total revenues and other income		814,588			1,101,057				1,656,304			1,654,018
Costs and expenses
Lease operating expenses		194,292			147,352				394,276			284,177
Severance and ad valorem taxes		12,765			17,565				24,205			32,200
Transportation, gathering and processing		59,868			49,948				113,790			96,871
Costs of purchased natural gas		9,657			47,971				41,926			81,636
Exploration expenses, including undeveloped lease amortization		115,793			15,151				125,975			62,717
Selling and general expenses		25,345			27,130				43,653			60,659
Depreciation, depletion and amortization		215,667			195,856				411,337			359,980
Accretion of asset retirement obligations		11,364			11,563				22,521			23,439
Other operating expense		4,960			36,913				16,948			142,855
Total costs and expenses		649,711			549,449				1,194,631			1,144,534
Operating income from continuing operations		164,877			551,608				461,673			509,484
Other income (loss)
Other (expenses) income		(7,694	)		5,308				(7,767	)		2,813
Interest expense, net		(29,856	)		(41,385	)			(58,711	)		(78,662	)
Total other loss		(37,550	)		(36,077	)			(66,478	)		(75,849	)
Income from continuing operations before income taxes		127,327			515,531				395,195			433,635
Income tax expense		34,870			105,084				88,703			88,123
Income from continuing operations		92,457			410,447				306,492			345,512
Loss from discontinued operations, net of income taxes		(602	)		(943	)			(323	)		(1,494	)
Net income including noncontrolling interest		91,855			409,504				306,169			344,018
Less: Net (loss) income attributable to noncontrolling interest		(6,431	)		58,947				16,239			106,797
NET INCOME ATTRIBUTABLE TO MURPHY	$	98,286			350,557			$	289,930			237,221
INCOME (LOSS) PER COMMON SHARE – BASIC
Continuing operations	$	0.63			2.27			$	1.86			1.54
Discontinued operations		—			(0.01	)			—			(0.01	)
Net income	$	0.63			2.26			$	1.86			1.53
INCOME (LOSS) PER COMMON SHARE – DILUTED
Continuing operations	$	0.62			2.24			$	1.84			1.51
Discontinued operations		—			(0.01	)			—			(0.01	)
Net income	$	0.62			2.23			$	1.84			1.50
Cash dividends per common share	$	0.275			0.175			$	0.550			0.325
Average common shares outstanding (thousands)
Basic		156,127			155,389				155,976			155,121
Diluted		157,299			157,455				157,308			157,852

MURPHY OIL CORPORATION CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)
	Three Months Ended June 30,							Six Months Ended June 30,
(Thousands of dollars)	2023				2022			2023				2022
Operating Activities
Net income including noncontrolling interest	$	91,855			409,504			$	306,169			344,018
Adjustments to reconcile net income to net cash provided by continuing operations activities
Loss from discontinued operations		602			943				323			1,494
Depreciation, depletion and amortization		215,667			195,856				411,337			359,980
Unsuccessful exploration well costs and previously suspended exploration costs		95,682			1,271				96,533			34,102
Amortization of undeveloped leases		2,716			3,782				5,369			7,980
Accretion of asset retirement obligations		11,364			11,563				22,521			23,439
Deferred income tax expense		43,515			86,944				92,557			66,691
Contingent consideration payment		(15,609	)		—				(139,574	)		—
Mark-to-market loss on contingent consideration		3,175			31,692				7,113			129,818
Mark-to-market (gain) loss on derivative instruments		—			(88,166	)			—			100,343
Long-term non-cash compensation		13,540			23,179				22,076			40,467
(Gain) from sale of assets		—			(35	)			—			(35	)
Net decrease (increase) in non-cash working capital		59,691			(40,676	)			(15,340	)		(121,598	)
Other operating activities, net		(52,307	)		(14,946	)			(59,417	)		(27,458	)
Net cash provided by continuing operations activities		469,891			620,911				749,667			959,241
Investing Activities
Property additions and dry hole costs		(349,434	)		(307,917	)			(694,753	)		(552,825	)
Acquisition of oil and natural gas properties		—			(46,491	)			—			(46,491	)
Proceeds from sales of property, plant and equipment		—			47				—			47
Net cash required by investing activities		(349,434	)		(354,361	)			(694,753	)		(599,269	)
Financing Activities
Borrowings on revolving credit facility		100,000			100,000				200,000			100,000
Repayment of revolving credit facility		(100,000	)		(100,000	)			(200,000	)		(100,000	)
Retirement of debt		—			(200,000	)			—			(200,000	)
Early redemption of debt cost		—			(3,438	)			—			(3,438	)
Distributions to noncontrolling interest		(6,304	)		(54,970	)			(15,983	)		(94,854	)
Contingent consideration payment		(12,565	)		(26,573	)			(60,243	)		(81,742	)
Issue costs of debt facility		(3	)		—				(20	)		—
Cash dividends paid		(42,942	)		(27,191	)			(85,867	)		(50,491	)
Withholding tax on stock-based incentive awards		(3	)		(1,276	)			(14,220	)		(16,697	)
Capital lease obligation payments		(157	)		(162	)			(296	)		(320	)
Net cash required by financing activities		(61,974	)		(313,610	)			(176,629	)		(447,542	)
Effect of exchange rate changes on cash and cash equivalents		(1,511	)		(1,508	)			(893	)		(1,595	)
Net increase (decrease) in cash and cash equivalents		56,972			(48,568	)			(122,608	)		(89,165	)
Cash and cash equivalents at beginning of period		312,383			480,587				491,963			521,184
Cash and cash equivalents at end of period	$	369,355			432,019			$	369,355			432,019

MURPHY OIL CORPORATION SCHEDULE OF ADJUSTED NET INCOME (LOSS) (unaudited)
	Three Months Ended June 30,						Six Months Ended June 30,
(Millions of dollars, except per share amounts)	2023			2022			2023			2022
Net income attributable to Murphy (GAAP)	$	98.3		350.6			$	289.9		237.2
Discontinued operations loss		0.6		0.9				0.3		1.5
Net income (loss) from continuing operations attributable to Murphy		98.9		351.5				290.2		238.7
Adjustments1:
Write-off of previously suspended exploration well		17.1		—				17.1		—
Foreign exchange (gain) loss		7.9		(8.0	)			8.3		(8.0	)
Mark-to-market loss on contingent consideration		3.2		31.7				7.1		129.8
Mark-to-market (gain) loss on derivative instruments		—		(88.2	)			—		100.3
Early redemption of debt cost		—		4.4				—		4.4
Total adjustments, before taxes		28.2		(60.1	)			32.5		234.5
Income tax expense (benefit) related to adjustments		2.7		(13.2	)			3.6		47.4
Total adjustments after taxes		25.5		(46.9	)			28.9		179.1
Adjusted net income from continuing operations attributable to Murphy (Non-GAAP)	$	124.4		304.6			$	319.1		417.8
Adjusted net income from continuing operations per average diluted share (Non-GAAP)	$	0.79		1.93			$	2.03		2.65
1 Certain prior-period amounts have been updated to conform to the current period presentation.

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 June 30, 2023							Six Months Ended June 30, 2023
(Millions of dollars)	Pretax			Tax		Net		Pretax			Tax		Net
Exploration & Production:
United States	$	3.2		0.7		2.5		$	7.1		1.5		5.6
Other		17.1		—		17.1			17.1		—		17.1
Corporate		7.9		2.0		5.9			8.3		2.1		6.2
Total adjustments	$	28.2		2.7		25.5		$	32.5		3.6		28.9

MURPHY OIL CORPORATION SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION AND AMORTIZATION (EBITDA) (unaudited)
	Three Months Ended June 30,						Six Months Ended June 30,
(Millions of dollars)	2023			2022			2023			2022
Net income attributable to Murphy (GAAP)	$	98.3		350.6			$	289.9		237.2
Income tax expense		34.9		105.1				88.7		88.1
Interest expense, net		29.9		41.4				58.7		78.7
Depreciation, depletion and amortization expense ¹		210.1		188.2				399.3		344.8
EBITDA attributable to Murphy (Non-GAAP)	$	373.2		685.3			$	836.6		748.8
Write-off of previously suspended exploration well		17.1		—				17.1		—
Accretion of asset retirement obligations ¹		10.1		10.2				20.0		20.7
Foreign exchange loss (gain)		7.9		(8.0	)			8.3		(8.0	)
Mark-to-market loss on contingent consideration		3.2		31.7				7.1		129.8
Discontinued operations loss		0.6		0.9				0.3		1.5
Mark-to-market (gain) loss on derivative instruments		—		(88.1	)			—		100.4
Adjusted EBITDA attributable to Murphy (Non-GAAP)	$	412.1		632.0			$	889.4		993.2
1 Depreciation, depletion, and amortization expense, and accretion of asset retirement obligations used in the computation of Adjusted EBITDA exclude the portion attributable to the non-controlling interest (NCI).

Non-GAAP Financial Measures

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

MURPHY OIL CORPORATION SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION AND AMORTIZATION AND EXPLORATION (EBITDAX) (unaudited)
	Three Months Ended June 30,							Six Months Ended June 30,
(Millions of dollars)	2023			2022				2023			2022
Net income attributable to Murphy (GAAP)	$	98.3			350.6			$	289.9			237.2
Income tax expense		34.9			105.1				88.7			88.1
Interest expense, net		29.9			41.4				58.7			78.7
Depreciation, depletion and amortization expense ¹		210.1			188.2				399.3			344.8
EBITDA attributable to Murphy (Non-GAAP)		373.2			685.3				836.6			748.8
Exploration expenses 1		89.5			15.2				99.7			62.7
EBITDAX attributable to Murphy (Non-GAAP)		462.7			700.5				936.3			811.5
Accretion of asset retirement obligations ¹		10.1			10.2				20.0			20.7
Foreign exchange loss (gain)		7.9			(8.0	)			8.3			(8.0	)
Mark-to-market loss on contingent consideration		3.2			31.7				7.1			129.8
Discontinued operations loss		0.6			0.9				0.3			1.5
Mark-to-market (gain) loss on derivative instruments		—			(88.1	)			—			100.4
Adjusted EBITDAX attributable to Murphy (Non-GAAP)	$	484.5		$	647.2			$	972.0		$	1,055.9
1 Depreciation, depletion, and amortization expense, accretion of asset retirement obligations and exploration expenses used in the computation of adjusted EBITDAX exclude the portion attributable to the non-controlling interest (NCI).

Non-GAAP Financial Measures

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

MURPHY OIL CORPORATION FUNCTIONAL RESULTS OF OPERATIONS (unaudited)
	Three Months Ended June 30, 2023				Three Months Ended June 30, 2022
(Millions of dollars)	Revenues		Income (Loss)		Revenues			Income (Loss)
Exploration and production
United States 1	$	696.2	168.9		$	978.0		491.5
Canada		118.3	2.5			206.6		47.2
Other		—	(32.3	)		13.7		(3.5	)
Total exploration and production		814.5	139.1			1,198.3		535.2
Corporate		0.1	(46.6	)		(97.2	)	(124.8	)
Continuing operations		814.6	92.5			1,101.1		410.4
Discontinued operations, net of tax		—	(0.6	)		—		(0.9	)
Total including noncontrolling interest	$	814.6	91.9		$	1,101.1		409.5
Net income attributable to Murphy			98.3					350.6

	Six Months Ended June 30, 2023				Six Months Ended June 30, 2022
(Millions of dollars)	Revenues		Income (Loss)		Revenues			Income (Loss)
Exploration and production
United States 1	$	1,378.5	394.9		$	1,685.4		744.4
Canada		274.1	24.4			372.7		69.9
Other		3.6	(37.6	)		13.7		(47.7	)
Total exploration and production		1,656.2	381.7			2,071.8		766.6
Corporate		0.1	(75.2	)		(417.8	)	(421.1	)
Continuing operations		1,656.3	306.5			1,654.0		345.5
Discontinued operations, net of tax		—	(0.3	)		—		(1.5	)
Total including noncontrolling interest	$	1,656.3	306.2		$	1,654.0		344.0
Net income attributable to Murphy			289.9					237.2
1 Includes results attributable to a noncontrolling interest in MP Gulf of Mexico, LLC (MP GOM).

MURPHY OIL CORPORATION OIL AND GAS OPERATING RESULTS (unaudited) THREE MONTHS ENDED JUNE 30, 2023, AND 2022
(Millions of dollars)	United States 1			Canada		Other		Total
Three Months Ended June 30, 2023
Oil and gas sales and other operating revenues	$	696.2		105.3		—		801.5
Sales of purchased natural gas		—		13.0		—		13.0
Lease operating expenses		156.5		37.5		0.1		194.1
Severance and ad valorem taxes		12.4		0.4		—		12.8
Transportation, gathering and processing		39.9		20.1		—		60.0
Costs of purchased natural gas		—		9.7		—		9.7
Depreciation, depletion and amortization		178.0		35.0		—		213.0
Accretion of asset retirement obligations		9.3		1.9		0.1		11.3
Exploration expenses
Dry holes and previously suspended exploration costs		79.8		—		15.8		95.6
Geological and geophysical		0.4		0.1		10.0		10.5
Other exploration		1.7		—		5.3		7.0
		81.9		0.1		31.1		113.1
Undeveloped lease amortization		2.1		—		0.6		2.7
Total exploration expenses		84.0		0.1		31.7		115.8
Selling and general expenses		(1.9	)	4.7		2.6		5.4
Other		0.5		5.4		1.4		7.3
Results of operations before taxes		217.5		3.5		(35.9	)	185.1
Income tax provisions (benefits)		48.6		1.0		(3.6	)	46.0
Results of operations (excluding Corporate segment)	$	168.9		2.5		(32.3	)	139.1
Three Months Ended June 30, 2022
Oil and gas sales and other operating revenues	$	977.8		156.8		13.7		1,148.3
Sales of purchased natural gas		0.2		49.8		—		50.0
Lease operating expenses		109.5		36.9		0.9		147.3
Severance and ad valorem taxes		17.3		0.3		—		17.6
Transportation, gathering and processing		32.3		17.6		—		49.9
Costs of purchased natural gas		0.2		47.7		—		47.9
Depreciation, depletion and amortization		153.7		35.6		3.4		192.7
Accretion of asset retirement obligations		9.1		2.4		0.1		11.6
Exploration expenses
Dry holes and previously suspended exploration costs		(0.7	)	—		2.0		1.3
Geological and geophysical		—		0.1		0.8		0.9
Other exploration		2.9		0.3		6.0		9.2
		2.2		0.4		8.8		11.4
Undeveloped lease amortization		2.3		—		1.4		3.7
Total exploration expenses		4.5		0.4		10.2		15.1
Selling and general expenses		3.2		3.8		2.1		9.1
Other		35.3		(2.3	)	—		33.0
Results of operations before taxes		612.9		64.2		(3.0	)	674.1
Income tax provisions		121.4		17.0		0.5		138.9
Results of operations (excluding Corporate segment)	$	491.5		47.2		(3.5	)	535.2
1 Includes results attributable to a noncontrolling interest in MP GOM.

MURPHY OIL CORPORATION OIL AND GAS OPERATING RESULTS (unaudited) SIX MONTHS ENDED JUNE 30, 2023, AND 2022
(Millions of dollars)	United States 1			Canada	Other		Total
Six Months Ended June 30, 2023
Oil and gas sales and other operating revenues	$	1,378.5		217.2	3.6		1,599.3
Sales of purchased natural gas		—		56.8	—		56.8
Lease operating expenses		319.2		74.3	0.7		394.2
Severance and ad valorem taxes		23.5		0.7	—		24.2
Transportation, gathering and processing		77.3		36.5	—		113.8
Costs of purchased natural gas		—		41.9	—		41.9
Depreciation, depletion and amortization		338.2		66.7	0.9		405.8
Accretion of asset retirement obligations		18.4		3.9	0.2		22.5
Exploration expenses
Dry holes and previously suspended exploration costs		79.6		—	16.9		96.5
Geological and geophysical		0.7		0.1	10.5		11.3
Other exploration		3.3		0.1	9.4		12.8
		83.6		0.2	36.8		120.6
Undeveloped lease amortization		4.1		0.1	1.2		5.4
Total exploration expenses		87.7		0.3	38.0		126.0
Selling and general expenses		4.5		7.1	2.8		14.4
Other		9.9		9.7	1.4		21.0
Results of operations before taxes		499.8		32.9	(40.4	)	492.3
Income tax provisions (benefits)		104.9		8.5	(2.8	)	110.6
Results of operations (excluding Corporate segment)	$	394.9		24.4	(37.6	)	381.7
Six Months Ended June 30, 2022
Oil and gas sales and other operating revenues	$	1,685.2		286.1	13.7		1,985.0
Sales of purchased natural gas		0.2		86.6	—		86.8
Lease operating expenses		209.4		73.8	0.9		284.1
Severance and ad valorem taxes		31.5		0.7	—		32.2
Transportation, gathering and processing		61.5		35.3	—		96.8
Costs of purchased natural gas		0.2		81.6	—		81.8
Depreciation, depletion and amortization		280.2		69.8	3.5		353.5
Accretion of asset retirement obligations		18.5		4.9	0.1		23.5
Exploration expenses
Dry holes and previously suspended exploration costs		(0.7	)	—	34.8		34.1
Geological and geophysical		2.6		0.1	1.0		3.7
Other exploration		4.4		0.4	12.1		16.9
		6.3		0.5	47.9		54.7
Undeveloped lease amortization		4.7		0.1	3.2		8.0
Total exploration expenses		11.0		0.6	51.1		62.7
Selling and general expenses		11.5		8.9	4.5		24.9
Other		138.1		2.8	0.4		141.3
Results of operations before taxes		923.5		94.5	(46.8	)	971.2
Income tax provisions (benefits)		179.1		24.6	0.9		204.6
Results of operations (excluding Corporate segment)	$	744.4		69.9	(47.7	)	766.6
1 Includes results attributable to a noncontrolling interest in MP GOM.

MURPHY OIL CORPORATION PRODUCTION-RELATED EXPENSES (unaudited)
	Three Months Ended June 30,					Six Months Ended June 30,
(Dollars per barrel of oil equivalents sold)	2023			2022		2023			2022
United States – Eagle Ford Shale
Lease operating expense	$	11.48		11.41		$	13.06		11.81
Severance and ad valorem taxes		3.68		5.07			3.93		5.10
Depreciation, depletion and amortization (DD&A) expense		26.48		25.57			26.35		25.67
United States – Gulf of Mexico1
Lease operating expense	$	14.72		10.25		$	14.71		10.63
Severance and ad valorem taxes		0.07		0.07			0.08		0.08
DD&A expense		11.44		9.86			11.33		9.71
Canada – Onshore
Lease operating expense	$	6.01		6.82		$	6.38		7.14
Severance and ad valorem taxes		0.07		0.06			0.07		0.07
DD&A expense		5.65		6.55			5.82		6.81
Canada – Offshore
Lease operating expense	$	10.96		11.60		$	12.60		13.63
DD&A expense		9.48		11.51			9.40		11.96
Total E&P continuing operations
Lease operating expense	$	11.21		9.41		$	11.76		9.80
Severance and ad valorem taxes		0.74		1.12			0.72		1.11
DD&A expense		12.44		12.51			12.27		12.41
Total oil and gas continuing operations – excluding noncontrolling interest
Lease operating expense	$	11.02		9.36		$	11.58		9.70
Severance and ad valorem taxes		0.76		1.18			0.75		1.17
DD&A expense		12.53		12.64			12.36		12.56
1 Includes results attributable to a noncontrolling interest in MP GOM.

MURPHY OIL CORPORATION CAPITAL EXPENDITURES (unaudited)
	Three Months Ended June 30,					Six Months Ended June 30,
(Millions of dollars)	2023			2022		2023			2022
Exploration and production
United States1	$	245.5		225.4		$	500.2		418.2
Canada		75.4		74.0			143.5		150.9
Other		37.8		12.5			44.7		42.3
Total		358.7		311.9			688.4		611.4
Corporate		3.6		5.2			9.9		10.5
Total capital expenditures - continuing operations2		362.3		317.1			698.3		621.9
Charged to exploration expenses3
United States1		81.9		2.2			83.6		6.3
Canada		0.1		0.4			0.2		0.5
Other		31.2		8.8			36.8		47.9
Total charged to exploration expenses - continuing operations		113.2		11.4			120.6		54.7
Total capitalized	$	249.1		305.7		$	577.7		567.2
1 Includes results attributable to a noncontrolling interest in MP GOM.
2 For the three months ended June 30, 2023, total capital expenditures excluding acquisition-related costs (Côte d’Ivoire and Vietnam) of $32.3 million (2022: $46.5 million) and noncontrolling interest (NCI) of $29.9 million (2022: $5.0 million) is $300.1 million (2022: $265.6 million). For the six months ended June 30, 2023, total capital expenditures excluding acquisition-related costs of $32.3 million (2022:$46.5 million) and noncontrolling interest (NCI) of $38.8 million (2022: $8.6 million) is $627.2 million (2022: $566.8 million).
3 For the three-month and six-month-ended June 30, 2023, charges to exploration expense excludes amortization of undeveloped leases of $2.7 million (2022: $3.7 million) and $5.4 million (2022 $8.0 million), respectively. For the three-month and six-months ended June 30, 2023, charges to exploration expense excluding previously suspended exploration costs of $17.1 million (2022: $0) and NCI of $26.3 million (2022: $0) is $69.8 million (2022: $11.4 million) and $77.2 million (2022: $54.7 million), respectively.

MURPHY OIL CORPORATION CONSOLIDATED BALANCE SHEETS (unaudited)
(Thousands of dollars)	June 30, 2023				December 31, 2022
ASSETS
Current assets
Cash and cash equivalents	$	369,355			491,963
Accounts receivable		409,989			391,152
Inventories		62,450			54,513
Prepaid expenses		27,354			34,697
Total current assets		869,148			972,325
Property, plant and equipment, at cost		8,426,045			8,228,016
Operating lease assets		867,353			946,406
Deferred income taxes		40,678			117,889
Deferred charges and other assets		46,306			44,316
Total assets	$	10,249,530			10,308,952
LIABILITIES AND EQUITY
Current liabilities
Current maturities of long-term debt, finance lease	$	705			687
Accounts payable		584,107			543,786
Income taxes payable		23,539			26,544
Other taxes payable		32,091			22,819
Operating lease liabilities		258,278			220,413
Other accrued liabilities		135,788			443,585
Total current liabilities		1,034,508			1,257,834
Long-term debt, including finance lease obligation		1,823,521			1,822,452
Asset retirement obligations		843,328			817,268
Deferred credits and other liabilities		299,089			304,948
Non-current operating lease liabilities		624,736			742,654
Deferred income taxes		235,665			214,903
Total liabilities		4,860,847			5,160,059
Equity
Common Stock, par $1.00		195,101			195,101
Capital in excess of par value		861,951			893,578
Retained earnings		6,259,561			6,055,498
Accumulated other comprehensive loss		(495,783	)		(534,686	)
Treasury stock		(1,586,522	)		(1,614,717	)
Murphy Shareholders' Equity		5,234,308			4,994,774
Noncontrolling interest		154,375			154,119
Total equity		5,388,683			5,148,893
Total liabilities and equity	$	10,249,530			10,308,952

MURPHY OIL CORPORATION PRODUCTION SUMMARY (unaudited)
		Three Months Ended June 30,						Six Months Ended June 30,
(Barrels per day unless otherwise noted)		2023			2022			2023			2022
Net crude oil and condensate
United States	Onshore	26,880			26,304			23,100			23,334
	Gulf of Mexico 1	72,022			63,427			73,850			59,363
Canada	Onshore	3,097			4,419			3,190			4,400
	Offshore	2,913			3,128			2,687			3,224
Other		212			1,383			240			833
Total net crude oil and condensate - continuing operations		105,124			98,661			103,067			91,154
Net natural gas liquids
United States	Onshore	4,328			5,178			4,243			5,006
	Gulf of Mexico 1	6,291			4,913			6,316			4,223
Canada	Onshore	558			859			691			921
Total net natural gas liquids - continuing operations		11,177			10,950			11,250			10,150
Net natural gas – thousands of cubic feet per day
United States	Onshore	24,195			29,651			24,178			28,512
	Gulf of Mexico 1	69,904			63,703			72,539			59,902
Canada	Onshore	352,265			288,019			328,878			273,237
Total net natural gas - continuing operations		446,364			381,373			425,595			361,651
Total net hydrocarbons - continuing operations including NCI 2,3		190,695			173,173			185,250			161,579
Noncontrolling interest
Net crude oil and condensate – barrels per day		(5,949	)		(7,962	)		(6,279	)		(8,044	)
Net natural gas liquids – barrels per day		(204	)		(319	)		(218	)		(303	)
Net natural gas – thousands of cubic feet per day 2		(1,751	)		(3,097	)		(2,051	)		(2,845	)
Total noncontrolling interest		(6,445	)		(8,797	)		(6,839	)		(8,821	)
Total net hydrocarbons - continuing operations excluding NCI 2,3		184,250			164,376			178,411			152,758
1 Includes net volumes attributable to a noncontrolling interest in MP GOM.
2 Natural gas converted on an energy equivalent basis of 6:1.
3 NCI – noncontrolling interest in MP GOM.

MURPHY OIL CORPORATION WEIGHTED AVERAGE PRICE SUMMARY (unaudited)
		Three Months Ended June 30,					Six Months Ended June 30,
		2023			2022		2023			2022
Crude oil and condensate – dollars per barrel
United States	Onshore	$	72.39		110.66		$	73.47		$	103.39
	Gulf of Mexico 1		73.82		109.55			73.54			102.76
Canada 2	Onshore		68.50		100.51			71.46			96.84
	Offshore		80.14		115.65			79.26			113.46
Other			—		86.51			89.05			86.51
Natural gas liquids – dollars per barrel
United States	Onshore		16.60		38.29			19.28			38.30
	Gulf of Mexico 1		20.16		40.46			22.89			41.95
Canada 2	Onshore		29.90		63.99			39.82			59.23
Natural gas – dollars per thousand cubic feet
United States	Onshore		1.88		7.06			2.19			5.89
	Gulf of Mexico 1		2.33		7.52			2.81			6.43
Canada 2	Onshore		1.85		2.78			2.17			2.66
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 (unaudited) AS OF AUGUST 1, 2023

Volumes (MMcf/d)

Price/MCF

Remaining Period

Area

Commodity

Type 1

Start Date

End Date

Canada

Natural Gas

Fixed price forward sales

250

C$2.35

7/1/2023

12/31/2023

Canada

Natural Gas

Fixed price forward sales

162

C$2.39

1/1/2024

12/31/2024

Canada

Natural Gas

Fixed price forward sales

25

US$1.98

7/1/2023

10/31/2024

Canada

Natural Gas

Fixed price forward sales

15

US$1.98

11/1/2024

12/31/2024

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

MURPHY OIL CORPORATION THIRD QUARTER 2023 GUIDANCE
	Oil BOPD		NGLs BOPD		Gas MCFD		Total BOEPD
Production – net
U.S. – Eagle Ford Shale	27,000		4,900		27,900			36,600
– Gulf of Mexico excluding NCI	65,900		6,200		66,200			83,100
Canada – Tupper Montney	—		—		380,400			63,400
– Kaybob Duvernay and Placid Montney	2,900		700		12,700			5,700
– Offshore	2,900		—		—			2,900
Other	300		—		—			300
Total net production (BOEPD) - excluding NCI 1	188,000 to 196,000
Exploration expense ($ millions)	$32
FULL YEAR 2023 GUIDANCE
Total net production (BOEPD) - excluding NCI 2	180,000 to 186,000
Capital expenditures – excluding NCI ($ millions) 3	$950 to $1,025
¹ Excludes noncontrolling interest of MP GOM of 5,700 BOPD of oil, 200 BOPD of NGLs, and 2,100 MCFD gas.
² Excludes noncontrolling interest of MP GOM of 6,100 BOPD of oil, 200 BOPD of NGLs, and 2,100 MCFD gas.
³ Excludes noncontrolling interest of MP GOM of $72 million and acquisition-related costs of $45 million.

 

View source version on businesswire.com: https://www.businesswire.com/news/home/20230801023508/en/

Investor Contacts:

InvestorRelations@murphyoilcorp.com

Kelly Whitley, 281-675-9107

Megan Larson, 281-675-9470

Nathan Shanor, 713-941-9576

Source: Murphy Oil Corporation

FAQ

What were Murphy Oil Corporation's Q2 2023 financial results?

Murphy Oil Corporation's Q2 2023 financial results included net income of $98 million and adjusted net income of $124 million.

What was Murphy Oil Corporation's Q2 2023 production?

Murphy Oil Corporation exceeded the upper end of its guidance range with production of 184 MBOEPD.

What divestiture did Murphy Oil Corporation announce?

Murphy Oil Corporation announced the divestiture of non-core Canadian assets for C$150 million.

What were Murphy Oil Corporation's EBITDA and EBITDAX for Q2 2023?

Murphy Oil Corporation's EBITDA was $373 million, and EBITDAX was $463 million for Q2 2023.