Market Overview

Murphy Oil Corporation Announces First Quarter Financial and Operating Results

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Executed Agreements to Divest Malaysia Assets for $2.127 Billion,
and Subsequent to Quarter End, Acquire Gulf of Mexico Assets for $1.375
Billion

Drilled Discovery Wells in Mexico and Vietnam

Murphy Oil Corporation (NYSE:MUR) today announced its financial and
operating results for the first quarter ended March 31, 2019, including
net income attributable to Murphy of $40 million, or $0.23 per diluted
share. Adjusted net income, which excludes discontinued operations and
other one-off items, was $27 million, or $0.15 per diluted share.

On March 21, 2019, Murphy announced the divestiture of its Malaysia
assets. Beginning with the first quarter 2019, Malaysian operations will
be reported as "discontinued operations" and classified as "held for
sale" for financial reporting purposes. Unless otherwise noted, the
financial and operating highlights and metrics discussed in this
commentary, will exclude discontinued operations and noncontrolling
interest.1

Highlights for the first quarter include:

  • Signed a purchase and sale agreement to divest Malaysia assets for
    $2.127 billion cash, with an expected book gain of $0.9 billion to
    $1.0 billion
  • Realized adjusted EBITDAX over $24 per barrel of oil equivalent sold
  • Obtained operatorship approval from regulators for Gulf of Mexico
    assets acquired from Petrobras America Inc.

Highlights subsequent to quarter end include:

  • Signed purchase and sale agreement to acquire accretive, oil-weighted
    Gulf of Mexico assets for $1.375 billion
  • Drilled a discovery in Block 15-1/05 in the Cuu Long Basin in Vietnam
    with the LDT-1X exploration well
  • Entered into 20,000 barrels per day of new fixed price oil swaps for
    the remainder of 2019 and full year 2020

FIRST QUARTER 2019 RESULTS

The company recorded net income, attributable to Murphy, of $40 million,
or $0.23 per diluted share, for the first quarter 2019. The company
reported adjusted net income, which excludes both the results of
discontinued operations and certain other items that affect
comparability of results between periods, of $27 million, or $0.15 per
diluted share. The adjusted income from continuing operations excludes
the following after-tax items: a $13 million write-off of previously
suspended exploration well costs, an $11 million mark-to-market non-cash
expense related to the valuation of potential Petrobras America Inc.
("PAI") contingent consideration, and a $10 million charge for
non-recurring PAI transition service fees. Details for first quarter
results can be found in the attached schedules.

Adjusted earnings before interest, taxes, depreciation and amortization
(EBITDA) from continuing operations attributable to Murphy, totaled $311
million, or $23.00 per barrel of oil equivalent (BOE) sold. Adjusted
earnings before interest, taxes, depreciation, amortization and
exploration expenses (EBITDAX) from continuing operations attributable
to Murphy, totaled $330 million, or $24.43 per BOE sold. Details for
first quarter EBITDA and EBITDAX reconciliation can be found in the
attached schedules.

Production from continuing operations in the first quarter averaged 148
thousand barrels of oil equivalent per day (MBOEPD) with production from
discontinued operations averaging 44 MBOEPD. Production from continuing
operations was below plan due to the following reasons; North American
onshore business production was lower than expected by 4,400 BOEPD, with
the majority in the Eagle Ford Shale where 3,500 BOEPD was due to a
significant delay in the execution of a ten well pad along with offset
frac impacts. Production levels were also impacted by higher than
planned downtime at key facilities along with historically higher than
normal failure rates on artificial lift systems that impacted high
volume wells. The onshore Canada business was lower than expected by 900
BOEPD due primarily to third party mid-stream specification constraints
causing production from three new high-rate Kaybob Duvernay wells to be
shut in coupled with cold weather in the region causing unplanned shut
ins. The North American offshore business had a negative variance of
2,100 BOEPD of which 1,500 BOEPD was the result of a royalty adjustment
due to cumulative production levels in a newly acquired Gulf of Mexico
field, and lower than planned production levels at other smaller Gulf of
Mexico fields.

Details for first quarter production can be found in the attached
schedules.

"The first quarter was an extremely busy quarter at Murphy. We
demonstrated again that we are proven deal-makers by successfully
executing agreements to divest our Malaysia assets, which are becoming
gassier, followed shortly thereafter by an agreement to re-deploy the
expected proceeds by acquiring oil-weighted, tax-advantaged Gulf of
Mexico assets further enhancing our ability to generate cash flow. While
our lower than planned production across our North American business was
disappointing, many of the causes were one-off events and are now behind
us with production stabilized as we move into the second quarter. As
always, we remain committed to rewarding shareholders with cash returns
through our long-standing competitive dividend, along with beginning to
execute our recently Board-approved share repurchase, all while keeping
forward investment in our assets in line with cash flows," stated Roger
W. Jenkins, President and Chief Executive Officer.

FINANCIAL POSITION

As of March 31, 2019, the company had $2.8 billion of outstanding
long-term, fixed-rate notes, $325 million of borrowings on the $1.6
billion unsecured senior credit facility, and approximately $286 million
in cash and cash equivalents, net to Murphy at quarter end. The
fixed-rate notes had a weighted average maturity of 7.5 years and a
weighted average coupon of 5.5 percent.

STRATEGIC DIVESTITURE OF MALAYSIA

On March 21, 2019, the company announced it signed a purchase and sale
agreement to divest the fully issued share capital of the subsidiaries
that own Murphy's Malaysia assets, to a subsidiary of PTT Exploration
and Production Public Company Limited ("PTTEP"). PTTEP will pay Murphy
$2.127 billion in an all-cash transaction, payable upon closing and
subject to customary closing adjustments, plus up to a $100 million
bonus payment contingent upon certain future exploratory drilling
results prior to October 2020. The transaction has an effective economic
valuation date of January 1, 2019.

Since announcing the divestiture, significant progress has been made
toward a closing in the second quarter 2019. Closing of the transaction
is subject to customary conditions precedent including, among other
things, necessary regulatory approvals. Under the terms of the
transaction, Murphy will exit the country of Malaysia. The expected gain
on the sale of the assets is estimated to be between $0.9 billion to
$1.0 billion.

At year end 2018, the proved reserves (1P) net to Murphy attributable to
Malaysia, were 129 million barrels of oil equivalent (Mmboe), which
represented 16 percent of the company's total proved reserves at that
time. Of the 129 Mmboe of proved reserves, 70 Mmboe are characterized as
proved undeveloped. The proved reserves are comprised of 78 Mmboe of
natural gas and 51 million barrels (Mmbbl) of liquids. As previously
disclosed, full year 2019 production from Malaysia was estimated to be
46 to 48 MBOEPD.

SUBSEQUENT TO QUARTER END

Subsequent to quarter end, Murphy announced that its wholly owned
subsidiary, Murphy Exploration & Production Company – USA, has entered
into a definitive agreement to acquire deep water Gulf of Mexico assets
from LLOG Exploration Offshore, L.L.C. and LLOG Bluewater Holdings,
L.L.C., ("LLOG"). The accretive, cash flow providing Gulf of Mexico
assets currently produce approximately 38,000 BOEPD and are expected to
add approximately 66 Mmboe of proved reserves and 122 Mmboe of proved
and probable (2P) reserves2. The proved reserves are
comprised of 16 Mmboe of natural gas and 51 Mmbbl of liquids. The
transaction will have an effective date of January 1, 2019 and is
expected to close in the second quarter, subject to normal closing
adjustments. The new assets have an estimated 2019 annualized production
range of 32 to 35 MBOEPD.

Murphy will pay a cash consideration of $1.375 billion. Additional
contingent consideration payments are based on the following: up to $200
million in the event that revenue from certain properties exceeds
certain contractual thresholds between 2019 and 2022; $50 million
following first oil from certain development projects.

"Over the past seven months Murphy has undertaken three major
transactions as part of the strategic transformation to focus our
company primarily in the western hemisphere with oil-weighted growth
that can generate significant after tax cash flow for many years. Viewed
in combination, our sale of Malaysia along with the purchase of two Gulf
of Mexico assets illustrates very compelling metrics across all fronts.
We look forward to closing the transactions during the second quarter
and executing on our new long range plan," stated Jenkins.

REGIONAL OPERATIONS SUMMARY

North American Onshore

The North American onshore business produced approximately 86 MBOEPD in
the first quarter.

Eagle Ford Shale – Production in the quarter averaged
approximately 36 MBOEPD, with 86 percent liquids. The company brought 13
operated wells online during the quarter, of which four were in the
Tilden area and nine were in the Karnes area. The nine Karnes wells were
completed with four in the Upper Eagle Ford Shale and five in the Lower
Eagle Ford Shale, and due to a variety of delays, flowed only two days
in the quarter. The nine new wells had high 30 day (IP30 rate) rates
averaging over 1,700 BOEPD, with the Upper Eagle Ford Shale wells
averaging over 1,400 BOEPD IP30 with the Lower Eagle Ford Shale wells
average exceeding 2,100 BOEPD. The 2019 Eagle Ford Shale drilling and
completion schedule has been amended to include a slightly higher
average well count per pad. As compared to the original plan, the
company now plans to bring two additional wells online, bringing the
total wells online to 92.

"Following a weak production month for March in our Eagle Ford Shale
business we are back on track with production increasing daily as
volumes are currently approaching 44,000 BOEPD. With almost 80 percent
of our planned wells to come online in the second and third quarters, we
expect to see continued strong growth in this asset," commented Jenkins.

Tupper Montney – Natural gas production in the quarter averaged
223 million cubic feet per day (MMCFD). As planned, the company brought
three operated wells online during the quarter. As a result of the
company's sales price diversification and hedging strategy, Murphy
achieved a natural gas price of C$2.98 per million cubic feet per day
AECO for the Tupper Montney.

Kaybob Duvernay – During the quarter production averaged
approximately 10 MBOEPD with 61 percent liquids. As planned, the company
brought four operated wells online: a three well pad in Simonette and
one well in Kaybob North. Due to a third party mid-stream specification
constraint, the three well pad in Simonette was unable to flow to sales
for the entire quarter. For future production forecasts, it is assumed
that the three wells will not produce for the remainder of the year. The
one well in Kaybob North achieved an IP30 rate of over 830 BOEPD with 89
liquids with restricted flow rates.

As a result of reviewing land retention plans and capital allocation,
Murphy has elected to drill and complete fewer wells in the Kaybob
Duvernay based on the current market conditions. The company expects to
bring seven wells online as compared to the previously planned twelve
wells. The lower well count also includes the three well pad that was
unable to flow due to third party mid-stream constraints.

Global Offshore

The offshore business produced 62 MBOEPD for the first quarter, with 96
percent liquids. This excludes production from discontinued operations.

North America Production in the quarter for the Gulf of
Mexico averaged 54 MBOEPD, with 95 percent liquids. Canada offshore
averaged 8 MBOEPD.

Significant planning for 2019 rig operations took place in the first
quarter. The company has solidified its rig and partner plans to drill a
development well at Dalmatian field in the second quarter. That
operation will be followed by the drilling of the Hoffe Park exploration
well in Mississippi Canyon 122. Following that exploration well, the
contracted rig will move onto the Cascade #5 well to repair a subsea
safety valve that is expected to revive production levels, with an
anticipated increase of approximately 7,500 BOEPD gross. In additional
development work, there will be a rig placed on the Medusa facility late
in the second quarter for a one well workover. A different rig will move
to Front Runner to sidetrack and complete a three well program
commencing in the fourth quarter.

Vietnam – Early in 2019, Murphy received the Declaration of
Commerciality for the LDV field and expects to move forward with
sanction of the field development later this year.

EXPLORATION

Mexico Exploration – During the first quarter, the company
drilled a discovery with its first exploration test on Block 5 in the
Salinas Basin, offshore Mexico. The Cholula-1EXP exploration well
reached a total depth (TD) of over 8,800 feet in approximately 2,300
feet of water. The well was spud and drilled to total depth in less than
30 days with a drilling cost of approximately $12 million net to Murphy.
The exploration well discovered hydrocarbons in the upper Miocene target
objectives, encountering approximately 185 feet of net pay. The results
of the well have significantly de-risked the block and the company is
currently evaluating future appraisal plans. Murphy's subsidiary, Murphy
Sur, S. de R.L. de C.V., is the operator of Block 5 holding a 30 percent
working interest (WI). Partners in the block are wholly-owned
subsidiaries of Petrolium Nasional Berhad ("PETRONAS") (23.34 percent
WI), Ophir Energy (23.33 percent WI) and Sierra Oil and Gas (23.33
percent WI).

Vietnam Exploration – Murphy drilled a discovery in the LDT-1X
exploration well in Block 15-1/05 in the Cuu Long Basin in Vietnam. The
well completed drilling operations in April drilling to a TD of 14,090
feet measured depth at a net cost to Murphy of approximately $13
million. The well successfully encountered approximately 320 feet of net
oil pay in the primary objective and an additional 62 feet of net oil
pay in a secondary objective. The LDT-1X discovery will be incorporated
into the development of the adjacent LDV field where Murphy is operator
and progressing toward first oil in 2021. Murphy's subsidiary, Murphy
Cuu Long Bac Oil Co., Ltd, is the operator of the block and holds 40
percent WI in Block 15-1/05. Partners in the block include PetroVietnam
Exploration and Production Company ("PVEP") with 35 percent carried
interest and SK Innovation ("SKI") with a 25 percent interest.

"I am extremely pleased with the early success of our 2019 exploration
program. Our drilling team did an outstanding job executing a
pace-setter well in Mexico that allows us to dramatically improve the
economics for the development of the block. The well confirms our view
of the highly prospective Block 5 and, along with our partners, we are
planning a Cholula appraisal and further exploration program in
2020. While it is too early to quantify ultimate volumes without
additional appraisal, we are excited to have successfully encountered
pay in all of our objectives in an oil-charged system. We especially
look forward to incorporating the well results into multiple look-a-like
prospects that are near the Cholula well," Jenkins stated. "In Vietnam,
the LDT-1X well has met our pre-drill expectations and is a positive
resource addition to our growing business in the country, with the oil
reservoir section having properties exceeding our pre drill
estimates. The data collected from the well also yielded valuable
information that will be utilized in future exploration activity on
Block 15-1/05."

Gulf of Mexico Exploration – During the third quarter, Murphy
plans to spud the Hoffe Park exploration well in Mississippi Canyon 122
targeting a gross mean volume of 75 Mmboe at a 60 percent working
interest.

COMMODITY HEDGE POSITIONS

The company employs derivative commodity instruments to manage certain
risks associated with commodity prices and to underpin capital spending
associated with certain assets. Subsequent to quarter end, Murphy
entered into WTI based fixed price derivative swaps as detailed in the
table below.

Hedge & Fixed Price Sales Open Positions, as of April 30, 2019
                    Remaining Period
Area   Commodity   Type  

Volume
(Bbl/d)

 

Price
(USD/Bbl)

  Start Date   End Date
U.S.   WTI   Fixed Price Derivative Swap   20,000   $63.64   May 1, 2019   Dec. 31, 2019
U.S. WTI Fixed Price Derivative Swap 20,000 $60.10 Jan. 1, 2020 Dec. 31, 2020
 

Currently, Murphy has the following natural gas fixed price forward
sales as detailed in the table below.

Fixed Price Sales Open Positions, as of April 30, 2019
                    Remaining Period
Area   Commodity   Type  

Volume
(MMcf/d)

 

Price
(CAD$/Mcf)

  Start Date   End Date
Montney   Natural Gas  

Fixed Price Forward
Sales at AECO

  59   $2.81   Jan. 1, 2019   Dec. 31, 2020
 

SUSTAINABILITY REPORT

Subsequent to quarter end, Murphy released its 2019 Sustainability
Report. This inaugural online report reinforces the strategic importance
of responsible oil and natural gas development while investing in local
communities. Highlights from the report include; safeguarding people
conducting business in a manner that protects the health, safety and
security of everyone who works for and alongside Murphy, protecting the
environment and practicing conservation by committing to minimize
environmental impact through comprehensive policies, resource
efficiency, and emission reduction programs; and, investing in and
engaging with local communities where Murphy employees live and work
with the commitment to making a lasting difference.

To view an electronic version of Murphy's 2019 Sustainability Report,
visit www.murphyoilcorp.com/Responsibility/.

2019 CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE

Murphy's previously disclosed capital program had a range of $1.25 to
$1.45 billion. The Malaysia business as previously disclosed had a
capital program of $109 million. With Malaysia capital removed, the new
range of estimated capital spend for continuing operations is $1.15 to
$1.35 billion. This range does not include new capital that will be
allocated to the recently announcement agreement to acquire Gulf of
Mexico assets as the company will update upon the closing. Full year
production guidance will be updated following the closing of the
recently announced Gulf of Mexico acquisition.

For the second quarter Murphy estimates that production will be 143 to
147 MBOEPD. This level of production is below that of the first quarter
due to significant planned downtime events at the non-operated St. Malo
field where planned maintenance is scheduled for approximately 22 days
as well as a planned outage at the Tupper Montney non-operated gas
plants for approximately 11 days in the second quarter. The company has
historically experienced major planned downtime events in the second
quarter of each year associated with offshore assets and as such, second
quarter production has been lower than the first quarter for three of
the last four years.

The operated onshore well cadence for the year is updated to include the
following revisions, two additional Eagle Ford Wells and six less wells
it the Kaybob Duvernay.

2019 Operated Onshore Wells Online
      1Q 2019A     2Q 2019E     3Q 2019E     4Q 2019E     2019 TotalE
Eagle Ford Shale     13     23     35     21     92
Kaybob Duvernay 1 6 0 0 7
Tupper Montney 3 0 5 0 8
Placid Montney 0 0 0 7 7
 

"At this time our capital and production ranges are simply a reduction
of our discontinued operations in Malaysia being removed from our
ongoing business. We are especially keen to maintain capital spending
for our continuing business at planned levels and annual production
guidance will be updated following the closing of our latest Gulf of
Mexico transaction later this quarter. As usual, our goal remains to
keep spending levels, including our dividend in line with cash flow,"
commented Jenkins.

Detailed guidance for the second quarter is contained in the following
schedule.

CONFERENCE CALL AND WEBCAST SCHEDULED FOR MAY 2, 2019

Murphy will host a conference call to discuss first quarter 2019
financial and operating results on Thursday, May 2, 2019, at 10:00 a.m.
ET. 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 11507639.

FINANCIAL DATA

Summary financial data and operating statistics for first quarter 2019,
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 and schedules comparing EBITDA and EBITDAX between
periods are included with these schedules as well as guidance for the
second quarter 2019.

1With the close of the previously announced Gulf of Mexico
transaction in the fourth quarter 2018, and in accordance with GAAP,
Murphy reports the 100 percent interest, including a 20 percent
noncontrolling interest (NCI), in its new subsidiary, MP Gulf of Mexico,
LLC (MP GOM). The GAAP financials will 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, will exclude the
NCI, thereby representing only the amounts attributable to Murphy.

2Transaction reserves are based on internal engineering
estimates as of January 1, 2019, using strip prices in effect on April
3, 2019.

ABOUT MURPHY OIL CORPORATION

Murphy Oil Corporation is a global independent oil and natural gas
exploration and production company. The company's diverse resource base
includes production from North America onshore plays in the Eagle Ford
Shale, Kaybob Duvernay, Tupper Montney and Placid Montney, as well as
offshore Gulf of Mexico, Canada and Southeast Asia. Additional
information is available on the company's website 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 or results, are subject to inherent risks and
uncertainties. Factors that could cause one or more of these future
events or results not to occur as implied by any forward-looking
statement include, but are not limited to: our ability to complete the
acquisition of the Gulf of Mexico assets or the Malaysia divestiture due
to the failure to obtain regulatory approvals, the failure of the
respective counterparties to perform their obligations under the
relevant transaction agreements, the failure to satisfy all closing
conditions, or otherwise, 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; natural hazards
impacting our operations; 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; and adverse developments in
the U.S. or global capital markets, credit markets 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.
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 good 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,
although 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)

(Thousands of dollars, except per share amounts)

 
Three Months Ended
  March 31,
  2019

2018 1

 
Revenues
Revenue from sales to customers $ 590,550 396,329

Loss on crude contracts

- (29,502 )
Gain on sale of assets and other income   454   7,963  
Total revenues   591,004   374,790  
 
Costs and expenses
Lease operating expenses 131,696 88,833
Severance and ad valorem taxes 10,097 12,157

Exploration expenses, including undeveloped lease amortization

32,538 28,738
Selling and general expenses 63,360 48,096
Depreciation, depletion and amortization 229,406 182,743
Accretion of asset retirement obligations 9,340 6,372
Other expense (benefit)   30,005   (11,045 )
Total costs and expenses   506,442   355,894  
Operating income from continuing operations   84,562   18,896  
 
Other income (loss)
Interest and other income (loss) (4,748 ) 4,587
Interest expense, net   (46,069 ) (44,541 )
Total other loss   (50,817 ) (39,954 )
 

Income (loss) from continuing operations before income taxes

33,745 (21,058 )

Income tax expense (benefit)

  10,822   (111,639 )
Income from continuing operations 22,923 90,581

Income from discontinued operations, net of income taxes

  49,846   77,672  
Net income including noncontrolling interest 72,769 168,253

Less: Net income attributable to noncontrolling interest

  32,587   -  
NET INCOME ATTRIBUTABLE TO MURPHY $ 40,182   168,253  
 

INCOME (LOSS) PER COMMON SHARE – BASIC

Continuing operations $ (0.06 ) 0.52
Discontinued operations   0.29   0.45  
Net Income $ 0.23   0.97  
 

INCOME (LOSS) PER COMMON SHARE – DILUTED

Continuing operations $ (0.06 ) 0.52
Discontinued operations   0.29   0.44  
Net Income $ 0.23   0.96  
 
Cash dividends per Common share 0.25 0.25
 
Average Common shares outstanding (thousands)
Basic 173,341 172,805
Diluted

174,491

174,620
 

1 Reclassified to conform to current presentation.

 
   

MURPHY OIL CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)

(Thousands of dollars)

 
Three Months Ended
  March 31,
  2019

2018 1

Operating Activities
Net income including noncontrolling interest $ 72,769 168,253

Adjustments to reconcile net income to net cash provided by
continuing operations activities:

(Income) loss from discontinued operations (49,846 ) (77,672 )
Depreciation, depletion and amortization 229,406 182,743
Previously suspended exploration costs (credits) 13,251 (5 )
Amortization of undeveloped leases 8,045 13,168
Accretion of asset retirement obligations 9,340 6,372
Deferred income tax charge (benefit) 15,589 (147,716 )
Pretax (gain) loss from sale of assets (12 ) 339
Mark to market and revaluation of contingent consideration 13,530
Mark to market of crude contracts 14,350
Long-term non-cash compensation 22,388 14,057
Net (increase) decrease in noncash operating working capital (98,505 ) (3,553 )
Other operating activities, net  

(18,758

)

(59,449

)

Net cash provided by continuing operations activities  

217,197

 

110,887

 
 
Investing Activities
Property additions and dry hole costs (270,338 ) (247,054 )
Proceeds from sales of property, plant and equipment     260  
Net cash required by investing activities   (270,338 ) (246,794 )
 
Financing Activities
Capital lease obligation payments (160 )
Withholding tax on stock-based incentive awards (6,991 ) (6,642 )
Distribution to noncontrolling interest (18,437 )
Cash dividends paid   (43,398 ) (43,258 )
Net cash required by financing activities   (68,986 ) (49,900 )
 
Cash Flows from Discontinued Operations
Operating activities

123,469

167,386

 

Investing activities (26,438 ) (26,848 )
Financing activities   (2,547 ) (2,405 )

Net cash provided by discontinued operations

 

94,484

 

138,133

 

Cash transferred from discontinued operations to continuing
operations

 

46,080

 

371,656

 
Effect of exchange rate changes on cash and cash equivalents   2,405   21,051  
Net increase (decrease) in cash and cash equivalents (73,642 ) 206,900
Cash and cash equivalents at beginning of period   359,923   630,433  
Cash and cash equivalents at end of period $ 286,281   837,333  
 

1 Reclassified to conform to current presentation.

 
   

MURPHY OIL CORPORATION

SCHEDULE OF ADJUSTED INCOME (LOSS)

(unaudited)

(Millions of dollars, except per share amounts)

 
Three Months Ended
  March 31,
  2019 2018
Net income attributable to Murphy (GAAP) $ 40.2 168.3
Discontinued operations loss (income)   (49.8 ) (77.7 )

(Loss) income from continuing operations

(9.6 ) 90.6
Adjustments:
Write-off of previously suspended exploration wells 13.2
Mark-to-market (gain) loss on PAI contingent consideration 10.7
PAI transition service fee 9.8
Foreign exchange losses (gains) 2.4 (11.9 )
Impact of tax reform (120.0 )
Mark-to-market (gain) loss on crude oil derivative contracts 11.3
Seal insurance proceeds   (8.2 )
Total adjustments after taxes   36.1   (128.8 )
Adjusted income (loss) from continuing operations attributable to
Murphy
$ 26.5   (38.2 )
 
Adjusted income (loss) from continuing operations per diluted share $ 0.15   (0.22 )
 

Non-GAAP Financial Measures

Presented above is a reconciliation of Net income to Adjusted income
(loss) from continuing operations attributable to Murphy. Adjusted
income (loss) 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
income (loss) is a non-GAAP financial measure and should not be
considered a substitute for Net income (loss) as determined in
accordance with accounting principles generally accepted in the United
States of America.

Amounts shown above as reconciling items between Net income and Adjusted
income (loss) are presented net of applicable income taxes based on the
estimated statutory rate in the applicable tax jurisdiction. The pretax
and income tax impacts for adjustments shown above are as follows by
area of operations.

  Three Months Ended
  March 31, 2019
  Pretax   Tax   Net
Exploration & Production:
United States $ 26.0 (5.5 ) 20.5
Other International   13.2   13.2
Total E&P 39.2 (5.5 ) 33.7
Corporate:   2.6 (0.2 ) 2.4
Total adjustments $ 41.8 (5.7 ) 36.1
 
   

MURPHY OIL CORPORATION

SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION

AND AMORTIZATION (EBITDA)

(unaudited)

(Millions of dollars, except per barrel of oil equivalents sold)

 
Three Months Ended
  March 31,
  2019 2018
Net income attributable to Murphy (GAAP) $ 40.2 168.3
Discontinued operations loss (income) (49.8 ) (77.7 )
Income tax expense (benefit) 10.8 (111.6 )
Interest expense, net 46.1 44.5
Depreciation, depletion and amortization expense   212.1   182.7  
EBITDA attributable to Murphy (Non-GAAP) $ 259.4   206.2  
Mark-to-market (gain) loss on PAI contingent consideration 13.5
Write-off of previously suspended exploration wells 13.2
PAI transition service fee 12.5
Accretion of asset retirement obligations 9.3 6.4
Foreign exchange losses (gains) 2.6 (16.6 )
Mark-to-market (gain) loss on crude oil derivative contracts 14.4
Seal insurance proceeds     (11.3 )
Adjusted EBITDA attributable to Murphy (Non-GAAP) $ 310.5   199.1  
 
Total barrels of oil equivalents sold from continuing operations
attributable to Murphy (thousands of barrels)
13,497.2 10,531.7
 
EBITDA per barrel of oil equivalents sold $ 19.22 19.58
Adjusted EBITDA per barrel of oil equivalents sold $ 23.00 18.90
 

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 (loss) or Cash provided by operating
activities as determined in accordance with accounting principles
generally accepted in the United States of America.

Presented above is EBITDA per barrel of oil equivalent sold and adjusted
EBITDA per barrel of oil equivalent sold. Management believes EBITDA per
barrel of oil equivalent sold and adjusted EBITDA per barrel of oil
equivalent sold are important information because they are used by
management to evaluate the Company's profitability of one barrel of oil
equivalent sold in that period. EBITDA per barrel of oil equivalent sold
and adjusted EBITDA per barrel of oil equivalent sold are non-GAAP
financial metrics.

   

MURPHY OIL CORPORATION

SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION

AND AMORTIZATION AND EXPLORATION (EBITDAX)

(unaudited)

(Millions of dollars, except per barrel of oil equivalents sold)

 
Three Months Ended
  March 31,
  2019 2018
Net income attributable to Murphy (GAAP) $ 40.2 168.3
Discontinued operations loss (income) (49.8 ) (77.7 )
Income tax expense (benefit) 10.8 (111.6 )
Interest expense, net 46.1 44.5
Depreciation, depletion and amortization expense   212.1   182.7  
EBITDA attributable to Murphy (Non-GAAP)   259.4   206.2  
Exploration expenses   32.5   28.7  
EBITDAX attributable to Murphy (Non-GAAP) $ 291.9   234.9  
Mark-to-market (gain) loss on PAI contingent consideration 13.5
PAI transition service fee 12.5
Accretion of asset retirement obligations 9.3 6.4
Foreign exchange losses (gains) 2.6 (16.6 )
Mark-to-market (gain) loss on crude oil derivative contracts 14.4
Seal insurance proceeds     (11.3 )
Adjusted EBITDAX attributable to Murphy (Non-GAAP) $ 329.8   227.8  
 
Total barrels of oil equivalents sold from continuing operations
attributable to Murphy (thousands of barrels)
13,497.2 10,531.7
 
EBITDAX per barrel of oil equivalents sold $ 21.63 22.30
Adjusted EBITDAX per barrel of oil equivalents sold $ 24.43 21.63
 

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 (loss) or Cash provided by
operating activities as determined in accordance with accounting
principles generally accepted in the United States of America.

Presented above is EBITDAX per barrel of oil equivalent sold and
adjusted EBITDAX per barrel of oil equivalent sold. Management believes
EBITDAX per barrel of oil equivalent sold and adjusted EBITDAX per
barrel of oil equivalent sold are important information because they are
used by management to evaluate the Company's profitability of one barrel
of oil equivalent sold in that period. EBITDAX per barrel of oil
equivalent sold and adjusted EBITDAX per barrel of oil equivalent sold
are non-GAAP financial metrics.

         

MURPHY OIL CORPORATION

FUNCTIONAL RESULTS OF OPERATIONS (unaudited)

(Millions of dollars)

                     
   

Three Months Ended
March 31, 2019

   

Three Months Ended
March 31, 2018

      Revenues  

Income
(Loss)

    Revenues  

Income
(Loss)

Exploration and production
United States 1 $ 469.2 116.2 278.1 36.2
Canada 118.9 7.5 118.3 24.4
Other     2.9   (28.3 )         (15.4 )
Total exploration and production 591.0 95.4 396.4 45.2
Corporate       (72.4 )     (21.6 )   45.4  
Revenue/income from continuing operations 591.0 23.0 374.8 90.6
Discontinued operations, net of tax 2       49.8           77.7  
Total revenues/net income (loss)   $ 591.0   72.8       374.8     168.3  
 

1 2019 includes results attributable to a
noncontrolling interest in MP GOM LLC, a Gulf of Mexico joint
venture (MP GOM).

2 Malaysia is reported as discontinued operations
effective January 1, 2019.

 
       

MURPHY OIL CORPORATION

OIL AND GAS OPERATING RESULTS (unaudited)

THREE MONTHS ENDED MARCH 31, 2019 AND 2018

                   
 
United
(Millions of dollars)    

States 1

  Canada   Other   Total
Three Months Ended March 31, 2019                  
Oil and gas sales and other revenues $ 469.2 118.9 2.9 591.0
Lease operating expenses 92.4 39.0 0.3 131.7
Severance and ad valorem taxes 9.8 0.3 10.1
Depreciation, depletion and amortization 163.9 59.5 1.0 224.4
Accretion of asset retirement obligations 7.8 1.5 9.3
Exploration expenses
Dry holes and previously suspended exploration costs 0.1 13.1 13.2
Geological and geophysical 0.5 5.5 6.0
Other exploration     1.2   0.1   4.0   5.3
1.8 0.1 22.6 24.5
Undeveloped lease amortization     6.9   0.3   0.8   8.0
Total exploration expenses     8.7   0.4   23.4   32.5
Selling and general expenses 17.3 7.6 5.6 30.5
Other     30.6   0.2   0.3   31.1
Results of operations before taxes 138.7 10.4 (27.7) 121.4
Income tax provisions (benefits)     22.5   2.9   0.6   26.0

Results of operations (excluding corporate overhead and interest)

  $ 116.2   7.5   (28.3)   95.4
                   
Three Months Ended March 31, 2018                  
Oil and gas sales and other revenues $ 278.1 118.3 396.4
Lease operating expenses 58.5 30.4 88.9
Severance and ad valorem taxes 11.8 0.4 12.2
Depreciation, depletion and amortization 121.6 55.7 0.8 178.1
Accretion of asset retirement obligations 4.4 2.0 6.4
Exploration expenses
Geological and geophysical 5.9 2.9 8.8
Other exploration     1.2   0.1   5.4   6.7
7.1 0.1 8.3 15.5
Undeveloped lease amortization     12.7   0.2   0.3   13.2
Total exploration expenses     19.8   0.3   8.6   28.7
Selling and general expenses 14.4 7.7 5.9 28.0
Other     0.8   (11.7)   (0.1)   (11.0)

Results of operations before taxes

46.8 33.5 (15.2) 65.1
Income tax provisions (benefits)     10.6   9.1   0.2   19.9

Results of operations (excluding corporate overhead and interest)

  $ 36.2   24.4   (15.4)   45.2

 

1 2019 includes results attributable to a
noncontrolling interest in MP GOM, a Gulf of Mexico joint venture.

 
   

MURPHY OIL CORPORATION

PRODUCTION-RELATED EXPENSES

(unaudited)

(Dollars per barrel of oil equivalents sold)

 
Three Months Ended
March 31,
  2019 2018
Continuing operations
United States – Eagle Ford Shale
Lease operating expense $ 12.92 8.34
Severance and ad valorem taxes 3.03 3.01
Depreciation, depletion and amortization (DD&A) expense 23.90 24.84
 
United States – Gulf of Mexico
Lease operating expense $ 8.11 17.90
DD&A expense 14.39 17.35
 
Canada – Onshore
Lease operating expense $ 5.89 4.85
Severance and ad valorem taxes 0.06 0.10
DD&A expense 11.03 10.15
 
Canada – Offshore
Lease operating expense $ 17.43 10.96
DD&A expense 13.70 13.46
 
Total oil and gas continuing operations
Lease operating expense $ 8.93 8.43
Severance and ad valorem taxes 0.68 1.15
DD&A expense 15.78 16.90
 
Total oil and gas continuing operations – excluding noncontrolling
interest
Lease operating expense $ 9.01 8.43
Severance and ad valorem taxes 0.75 1.15
DD&A expense 15.54 16.90
 
   

MURPHY OIL CORPORATION

OTHER FINANCIAL DATA

(unaudited)

(Millions of dollars)

 
Three Months Ended
  March 31,
  2019 2018
Capital expenditures for continuing operations
Exploration and production
United States $ 205.5 147.5
Canada 95.7 119.0
Other   41.3 9.7
Total   342.5 276.2
 
Corporate   4.1 5.1
Total capital expenditures - continuing operations   346.6 281.3
 
Charged to exploration expenses 1
United States 1.8 7.1
Canada 0.1 0.1
Other   22.6 8.3
Total charged to exploration expenses - continuing operations   24.5 15.5
 
Total capitalized 2 $ 322.1 265.8
Memo: Capital expenditures (including exploration) on discontinued
operations
21.9 19.1
 

1 Excludes amortization of undeveloped leases of $8.0
million and $13.2 million for the three months ended March 31,
2019 and 2018, respectively.

2 Includes noncontrolling interest capital expenditures
of $13.1 million.

 
     
MURPHY OIL CORPORATION
CONDENSED BALANCE SHEETS (unaudited)
(Millions of dollars)
 
  March 31, 2019 December 31, 2018 1
 

Assets

Cash and cash equivalents $ 286.3 359.9
Other current assets 2 2,352.0 520.0
Property, plant and equipment – net 8,559.1 8,432.1
Other long-term assets   785.7 1,740.6
Total assets $ 11,983.1 11,052.6
 

Liabilities and Stockholders' Equity

Current maturities of long-term debt $ 0.7 0.7
Other current liabilities 2 1,637.5 845.4
Long-term debt 3,110.1 3,109.3
Other long-term liabilities 1,908.1 1,899.6
Total equity 3   5,326.7 5,197.6
Total liabilities and stockholders' equity $ 11,983.1 11,052.6
 

1 Reclassified to conform to current presentation.

2 Includes $1,861.2 million and $819.4 million in 2019
in Other current assets and Other current liabilities,
respectively, classified as held for sale related to Malaysia.

3 Includes noncontrolling interest of $377.9 million
and $368.3 million as of March 31, 2019 and December 31, 2018,
respectively.

 
         

MURPHY OIL CORPORATION

PRODUCTION SUMMARY

(unaudited)

 
Three Months Ended
March 31,

Barrels per day unless otherwise noted

2019 2018
Continuing operations
Net crude oil and condensate
United States Onshore 25,880 31,553
Gulf of Mexico 1 61,048 12,615
Canada Onshore 6,457 4,358
Offshore 7,928 8,189
Other 507 585
Total net crude oil and condensate - continuing operations 101,820 57,300
Net natural gas liquids
United States Onshore 5,301 6,745
Gulf of Mexico 1 2,760 808
Canada Onshore 1,093 884
Total net natural gas liquids - continuing operations 9,154 8,437
Net natural gas – thousands of cubic feet per day
United States Onshore 29,279 31,233
Gulf of Mexico 1 19,575 12,670
Canada Onshore 254,904 261,305
Total net natural gas - continuing operations 303,758 305,208
Total net hydrocarbons - continuing operations including NCI 2,3 161,600 116,605
Noncontrolling interest
Net crude oil and condensate – barrels per day (12,185)
Net natural gas liquids – barrels per day (554)
Net natural gas – thousands of cubic feet per day (3,895)

Total noncontrolling interest

(13,388)
Total net hydrocarbons - continuing operations excluding NCI 2,3 148,212 116,605
 
Discontinued operations
Net crude oil and condensate – barrels per day 25,954 31,233
Net natural gas liquids – barrels per day 744 455
Net natural gas – thousands of cubic feet per day 2 101,592 115,276
Total discontinued operations 43,630 50,901
Total net hydrocarbons produced excluding NCI 2,3 191,842 167,506
 

1 2019 includes net volumes attributable to a
noncontrolling interest in MP GOM, a Gulf of Mexico joint venture.

2 Natural gas converted on an energy equivalent basis
of 6:1.

3 NCI – noncontrolling interest in MP GOM, a Gulf of
Mexico joint venture.

 
     

MURPHY OIL CORPORATION

SALES SUMMARY

(unaudited)

 
Three Months Ended
March 31,

Barrels per day unless otherwise noted

2019 2018
Continuing operations
Net crude oil and condensate
United States Onshore 25,880 31,553
Gulf of Mexico 1 63,289 12,615
Canada Onshore 6,457 4,358
Offshore 7,932 9,188
Other 467
Total net crude oil and condensate - continuing operations 104,025 57,714
Net natural gas liquids
United States Onshore 5,301 6,745
Gulf of Mexico 1 2,760 808
Canada Onshore 1,093 884
Total net natural gas liquids - continuing operations 9,154 8,437
Net natural gas sold – thousands of cubic feet per day
United States Onshore 29,279 31,233
Gulf of Mexico 1 19,575 12,670
Canada Onshore 254,904 261,305
Total net natural gas - continuing operations 303,758 305,208
Total net hydrocarbons - continuing operations including NCI 2,3 163,805 117,019
Noncontrolling interest
Net crude oil and condensate – barrels per day (12,633)
Net natural gas liquids – barrels per day (554)
Net natural gas – thousands of cubic feet per day 2 (3,895)
Total noncontrolling interest (13,836)
Total net hydrocarbons - continuing operations excluding NCI 2,3 149,969 117,019
 
Discontinued operations
Net crude oil and condensate – barrels per day 26,260 29,954
Net natural gas liquids – barrels per day 663 966

Net natural gas – thousands of cubic feet per day 2

101,592 115,276
Total discontinued operations 43,855 50,133
Total net hydrocarbons sold excluding NCI 2,3 193,824 167,152
 

1 2019 includes net volumes attributable to a
noncontrolling interest in MP GOM, a Gulf of Mexico joint venture.

2 Natural gas converted on an energy equivalent basis
of 6:1.

3 NCI – noncontrolling interest in MP GOM, a Gulf of
Mexico joint venture.

 
     

MURPHY OIL CORPORATION

PRICE SUMMARY

(unaudited)

 
Three Months Ended
  March 31,
  2019 2018
Weighted average Exploration and Production sales prices
Continuing operations
Crude oil and condensate – dollars per barrel
United States Onshore $ 57.36 64.28
Gulf of Mexico 1 55.48 63.00
Canada 2 Onshore 47.06 54.29
Offshore 61.42 65.69
Other 67.90
Natural gas liquids – dollars per barrel
United States Onshore 12.89 19.93
Gulf of Mexico 1 16.81 22.57
Canada 2 Onshore 35.16 43.58
Natural gas – dollars per thousand cubic feet
United States Onshore 2.22 2.40
Gulf of Mexico 1 1.42 2.58
Canada 2 Onshore 1.95 1.68
Discontinued operations
Crude oil and condensate – dollars per barrel
Malaysia 3 Sarawak 62.70 64.48
Block K 65.40 63.18
Natural gas liquids – dollars per barrel
Malaysia 3 Sarawak 52.44 71.21
Natural gas – dollars per thousand cubic feet
Malaysia 3 Sarawak 4.54 3.37
Block K 0.24 0.22
 

1 Prices include noncontrolling interest for MP GOM, a
U.S. Gulf of Mexico joint venture.

2 U.S. dollar equivalent.

3 Prices are net of payments under the terms of the
respective production sharing contracts.

 
           
MURPHY OIL CORPORATION
COMMODITY HEDGE POSITIONS (unaudited)
AS OF APRIL 30, 2019
 
Volumes Price Remaining Period
Area Commodity Type (Bbl/d) (USD/Bbl) Start Date End Date

United States

WTI Fixed price derivative swap 20,000 $63.64 5/1/2019 12/31/2019

United States

WTI Fixed price derivative swap 20,000 $60.10 1/1/2020 12/31/2020
 
Volumes Price Remaining Period
Area Commodity Type (MMcf/d) (CAD/Mcf) Start Date End Date
Montney Natural Gas

Fixed price forward sales at AECO

59 C$2.81 4/1/2019 12/31/2020
 
     
MURPHY OIL CORPORATION
SECOND QUARTER 2019 GUIDANCE
 
Liquids Gas
BOPD MCFD BOEPD
Production – net

U.S. – Eagle Ford Shale

38,800 35,000 44,600
– Gulf of Mexico including NCI 1 55,875 24,125 59,900
– Gulf of Mexico excluding NCI 44,700 19,300 47,900
Canada – Tupper Montney - 206,700 34,500
– Kaybob Duvernay and Placid Montney 5,700 25,900 10,000
– Offshore 7,500

-

7,500

Other

500

-

500
 
Total net production (BOEPD) - including NCI 1 155,000 to 159,000
Total net production (BOEPD) - excluding NCI 143,000 to 147,000
 
Total net sales (BOEPD) - including NCI 154,500 to 158,500
Total net sales (BOEPD) - excluding NCI 142,500 to 146,500
 
Exploration expense ($ millions) $34
 
1 Includes noncontrolling interest of MP GOM of 11,175
BOPD liquids and 4,825 MCFD gas.
 
FULL YEAR 2019 GUIDANCE 2
 

Capital expenditures - excluding NCI ($ billions)

$1.15 - $1.35
 
2 Full year production guidance will be updated upon
completion of the previously announced business disposition and
acquisition.

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