Market Overview

Murphy Oil Corporation Announces First Quarter Financial and Operating Results


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

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

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


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

"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.


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.


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, 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.


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.


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


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  




  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  
View Comments and Join the Discussion!
Don't Miss Any Updates!
News Directly in Your Inbox
Subscribe to:
Benzinga Premarket Activity
Get pre-market outlook, mid-day update and after-market roundup emails in your inbox.
Market in 5 Minutes
Everything you need to know about the market - quick & easy.
Daily Analyst Rating
A summary of each day’s top rating changes from sell-side analysts on the street.
Fintech Focus
A daily collection of all things fintech, interesting developments and market updates.
Thank You

Thank you for subscribing! If you have any questions feel free to call us at 1-877-440-ZING or email us at