Produced 170 MBOEPD with 89 MBOPD,
Repurchased $50 Million of Shares
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.”
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 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 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 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 in
our ability to maintain production rates and replace reserves;
reduced customer demand for our products due to environmental,
regulatory, technological or other reasons; adverse foreign
exchange movements; political and regulatory instability in the
markets where we do business; the impact on our operations or
market of health pandemics such as COVID-19 and related government
responses; other natural hazards impacting our operations or
markets; any other deterioration in our business, markets or
prospects; any failure to obtain necessary regulatory approvals;
any inability to service or refinance our outstanding debt or to
access debt markets at acceptable prices; or adverse developments
in the U.S. or global capital markets, credit markets, banking
system or economies in general, including inflation. For further
discussion of factors that could cause one or more of these future
events or results not to occur as implied by any forward-looking
statement, see “Risk Factors” in our most recent Annual Report on
Form 10-K filed with the U.S. Securities and Exchange Commission
(“SEC”) and any subsequent Quarterly Report on Form 10-Q or Current
Report on Form 8-K that we file, available from the SEC’s website
and from Murphy Oil Corporation’s website at
http://ir.murphyoilcorp.com. Investors and others should note that
we may announce material information using SEC filings, press
releases, public conference calls, webcasts and the investors page
of our website. We may use these channels to distribute material
information about the company; therefore, we encourage investors,
the media, business partners and others interested in the company
to review the information we post on our website. The information
on our website is not part of, and is not incorporated into, this
news release. Murphy Oil Corporation undertakes no duty to publicly
update or revise any forward-looking statements.
NON-GAAP FINANCIAL MEASURES
This news release contains certain non-GAAP financial measures
that management believes are useful tools for internal use and the
investment community in evaluating Murphy Oil Corporation’s overall
financial performance. These non-GAAP financial measures are
broadly used to value and compare companies in the crude oil and
natural gas industry. Not all companies define these measures in
the same way. In addition, these non-GAAP financial measures are
not a substitute for financial measures prepared in accordance with
GAAP and should therefore be considered only as supplemental to
such GAAP financial measures. Please see the attached schedules for
reconciliations of the differences between the non-GAAP financial
measures used in this news release and the most directly comparable
GAAP financial measures.
MURPHY OIL CORPORATION
SUMMARIZED CONSOLIDATED
STATEMENTS OF OPERATIONS (unaudited)
Three Months Ended
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
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
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
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.
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.
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.
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.
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.
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 excludes amortization of
undeveloped leases of $2.8 million (2023: $2.7 million).
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
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.
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.
MURPHY OIL CORPORATION
FIXED PRICE FORWARD SALES AND
COMMODITY HEDGE POSITIONS (unaudited)
AS OF APRIL 30, 2024
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$1.98
11/1/2024
12/31/2024
1 Fixed price forward sale contracts are
accounted for as normal sales and purchases for accounting
purposes.
MURPHY OIL CORPORATION
SECOND QUARTER 2024 GUIDANCE
Oil
NGLs
Gas
Total
BOPD
BOPD
MCFD
BOEPD
Production – net
U.S. – Eagle Ford Shale
18,500
4,000
22,700
26,300
– Gulf of Mexico excluding NCI
61,700
4,600
58,700
76,100
Canada – Tupper Montney
—
—
380,600
63,400
– Kaybob Duvernay and Placid Montney
2,200
500
7,800
4,000
– Offshore
10,000
—
—
10,000
Other
200
—
—
200
Total net production (BOEPD) - excluding
NCI 1
176,000 to 184,000
Exploration expense ($ 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.
View source
version on businesswire.com: https://www.businesswire.com/news/home/20240430291128/en/
Investor Contacts: InvestorRelations@murphyoilcorp.com
Kelly Whitley, 281-675-9107 Megan Larson, 281-675-9470 Beth Heller,
832-506-6831
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