8-K Front for 4Q 2018 Earnings

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549







FORM 8-K





CURRENT REPORT

PURSUANT TO SECTION 13 OR 15(d) OF THE

SECURITIES EXCHANGE ACT OF 1934





Date of report (Date of earliest event reported): January 31, 2019







MURPHY OIL CORPORATION

(Exact name of registrant as specified in its charter)





 

 

 

 



 

 

 

 

Delaware

 

1-8590

 

71-0361522

(State or other jurisdiction of incorporation)

 

(Commission File Number)

 

(I.R.S. Employer Identification No.)



 

 

 

 



 

 

 

 







 

 

300 Peach Street

 

 

P.O. Box 7000, El Dorado AR

 

71730-7000

(Address of principal executive offices)

 

(Zip Code)

       





Registrant’s telephone number, including area code 870-862-6411



                                                  Not applicable                                                  

(Former Name or Former Address, if Changed Since Last Report)





Check the appropriate box below if the Form 8-K filing is intended to simultaneously satisfy the filing obligation of the registrant under any of the following provisions (see General Instruction A.2. below):



 

[  ]

Written communications pursuant to Rule 425 under the Securities Act (17 CFR 230.425)



 

[  ]

Soliciting material pursuant to Rule 14a-12 under the Exchange Act (17 CFR 240.14a-12)



 

[  ]

Pre-commencement communications pursuant to Rule 14d-2(b) under the Exchange Act (17 CFR 240.14d-2(b))



 

[  ]

Pre-commencement communications pursuant to Rule 13e-4(c) under the Exchange Act (17 CFR 240.13e-4(c))



Indicate by check mark whether the registrant is an emerging growth company as defined in Rule 405 of the Securities Act of 1933 (§230.405 of this chapter) or Rule 12b-2 of the Securities Exchange Act of 1934 (§240.12b-2 of this chapter). Emerging growth company [  ]



If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.    [  ]



 


 

Item 2.02.   Results of Operations and Financial Condition



The following information is furnished pursuant to Item 2.02, “Results of Operations and Financial Condition.”



On January 31, 2019, Murphy Oil Corporation issued a news release announcing its financial and operating results for the quarter and year ended December 31, 2018.    The full text of this news release is attached hereto as Exhibit 99.1.





Item 9.01.  Financial Statements and Exhibits





 

(d)

Exhibits



 

99.1

A news release dated January 31, 2019.  






 

Signature



Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned hereunto duly authorized.







 

 

 

MURPHY OIL CORPORATION



 

 

 

By:

/s/ Christopher D. Hulse

 



Christopher D. Hulse

 



Vice President and Controller





DateJanuary 31, 2019










 

Exhibit Index





 

99.1

News release dated January 31, 2019, as issued by Murphy Oil Corporation.




4Q 2018 Earnings Exhibit 99.1

Exhibit 99.1



MURPHY OIL CORPORATION ANNOUNCES FOURTH QUARTER AND

FULL YEAR 2018 FINANCIAL AND OPERATING RESULTS,

2019 CAPITAL INVESTMENT PROGRAM



Increased Proved Reserves by 17% with 166% Organic Reserve Replacement

EL DORADO, Arkansas, January 31, 2019 – Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the fourth quarter ended December 31, 2018, including net income attributable to Murphy, which excludes noncontrolling interest, of $103 million, or $0.59 per diluted share. Net income including noncontrolling interest was $112 million.

With 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.

Highlights for the fourth quarter include:

·

Produced 176 thousand barrels of oil equivalent per day, in line with guidance

·

Closed accretive, deep water, oil-weighted Gulf of Mexico transaction, which included the addition of over 70 million barrels of oil equivalent of proved reserves                                                                                    

·

Realized EBITDA of over $25 per barrel of oil equivalent sold

·

Received credit rating upgrades from Moody’s and Fitch Ratings

·

Closed $1.6 billion senior unsecured revolving credit facility, with more favorable covenants

Highlights for the full year 2018 include:

·

Increased proved reserves by 17 percent to 816 million barrels oil equivalent, with 57 percent liquids-weighting

·

Achieved 166 percent organic reserve replacement with a finding and development cost of $10.92 per barrel of oil equivalent

·

Maintained reserve life index in excess of 10 years

·

Produced 171 thousand barrels of oil equivalent per day, a 4 percent increase from prior year

·

Increased production in the Kaybob Duvernay to over 8,500 barrels of oil equivalent per day, more than double the prior year

·

Registered annualized EBITDA to average capital employed of 21 percent

·

Returned 14 percent of operating cash flow to shareholders through long-standing dividend policy

·

Preserved balance sheet strength with approximately 37 percent net debt to total capital

1


 

FOURTH QUARTER 2018 RESULTS

The company recorded net income, attributable to Murphy, of $103 million, or $0.59 per diluted share, for the fourth quarter 2018. The company reported adjusted income attributable to Murphy, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, of $54 million, or $0.31 per diluted share. The adjusted income excludes the following after-tax items: a gain of $30 million associated with tax impacts, an unrealized mark-to-market gain on crude oil derivative contracts of $28 million and a $16 million impairment on select Midland properties. Details for fourth quarter results can be found in the attached schedules.

Earnings before interest, taxes, depreciation and amortization (EBITDA) attributable to Murphy, totaled $421 million, or $25.67 per barrel of oil equivalent (BOE) sold. Earnings before interest, taxes, depreciation, amortization and exploration expenses (EBITDAX) attributable to Murphy, totaled $456 million, or $27.74 per BOE sold. Details for fourth quarter EBITDA and EBITDAX reconciliation can be found in the attached schedules.

Production in the fourth quarter averaged 176 thousand barrels of oil equivalent per day (MBOEPD), which was in line with guidance. Details for fourth quarter production can be found in the attached schedules.

FULL YEAR 2018 RESULTS

The company recorded a net income, attributable to Murphy,  of $411 million, or $2.36 per diluted share, for the full year 2018. The company reported adjusted income, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, of $219 million, or $1.26 per diluted share. Details for full year 2018 results can be found in the attached schedules.

Production for the full year averaged 171 MBOEPD, which was in line with guidance. Details for 2018 production can be found in the attached tables.

“2018 was a really good year for Murphy with our net income at the highest level in four years. We continued to benefit from our diverse, growing, oil-weighted portfolio that was able to continuously generate high cash flow per barrel metrics. We demonstrated again that we are proven deal-makers by successfully closing on an accretive oil-weighted transaction that will further enhance our ability to generate cash flow. Also, we remain committed to rewarding shareholders with cash returns through our long-standing competitive dividend, while we keep investment in our assets in line with our cash flows,” stated Roger W. Jenkins, President and Chief Executive Officer.

2


 

FINANCIAL POSITION

As of December 31, 2018, 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 $387 million in cash and cash equivalents, including noncontrolling interest, at year-end. The fixed-rate notes had a weighted average maturity of 7.8 years and a weighted average coupon of 5.5 percent.

YEAR-END 2018 PROVED RESERVES

Murphy’s preliminary year-end 2018 proved reserves were 816 million barrels of oil equivalent (MMBOE), a 17 percent increase from 698 MMBOE at year-end 2017. The change in year-over-year reserves is mainly attributed to the acquisition of Gulf of Mexico reserves through the MP GOM transaction as well as organic additions in both the Eagle Ford Shale and Tupper Montney assets. Organic reserve replacement was 166 percent and one-year finding and development cost were $10.92 per BOE, with a three-year cumulative finding and development cost of $10.62 per BOE.

2018 Proved Reserves – Preliminary *

Category

Net Liquid

(MMBBLS)

Net Gas
(BCF)

Net Equiv. 
(MMBBLS)

Proved Developed Producing (PDP)

257

913

409

Proved Undeveloped (PUD)

203

1,220

407

Total Proved

460

2,133

816

* Reserve quantities represent amounts attributable to Murphy and exclude noncontrolling interest

“Our team did an excellent job adding low-cost, high-value reserves in 2018. We were able to increase our proved reserves by 17 percent and more importantly increase our oil reserves by 24 percent from 2017. We continue to replace reserves with finding and development costs tracking below $11 per BOE. We are especially pleased with the additional oil reserves from our new Gulf of Mexico assets where the initial booking at year-end was above our original estimated volumes,” commented Jenkins.

3


 

REGIONAL OPERATIONS SUMMARY                                                        

North American Onshore

The North American onshore business produced over 93 MBOEPD in the fourth quarter.

Eagle Ford Shale  – Production in the quarter averaged over 40 MBOEPD, with 88 percent liquids. As planned, the company brought eight operated wells online during the quarter, all in the Catarina area.

Tupper Montney – Natural gas production in the quarter averaged over 230 million cubic feet per day (MMCFD), after allowing for over 6 MMCFD impacts related to third-party plant and pipeline restrictions. During the fourth quarter, the company celebrated the asset’s tenth anniversary milestone, producing over 600 billion cubic feet (BCF) gross since inception.

Kaybob Duvernay – During the quarter, the company achieved record production averaging 11 MBOEPD with 59 percent liquids. Murphy has increased production in this play for seven consecutive quarters. As planned, the company brought five operated wells online: a four well pad in Kaybob West and one well in Two Creeks. The four well pad in Kaybob West performed in-line with pre-drill estimates, achieving average initial gross production rates over 30 days (IP30 rate) of over 900 BOEPD per well, with 67 percent liquids. The Two Creeks well, drilled by the previous operator at a less than optimal lateral length of 5,500 feet, was completed and brought online at initial gross production rates of 600 barrels of oil (BOPD) with 87 percent liquids. Over the course of 2018 the company brought 27 wells online, which advanced the appraisal of the play.

“We continue to be pleased with our North American unconventional business. Our steadfast Tupper Montney asset continues to provide free cash flow at current prices due to our market diversity and execution. Success continues in the Kaybob Duvernay, with strong well performance across the play, and promising early results in the Two Creeks area, support our plan to retain the vast majority of our acreage. In Eagle Ford Shale we jump-started our 2019 program and are currently running four rigs and two frac spreads, adding profitable production growth in the asset with additional capital allocation going forward,” commented Jenkins.

Global Offshore

The offshore business produced 83 MBOEPD for the fourth quarter, with 76 percent liquids.

Malaysia & Brunei – Production in the quarter averaged 46 MBOEPD, with 63 percent liquids. Block K and Sarawak averaged 28 thousand barrels of liquids per day, while Sarawak natural gas production averaged over 99 MMCFD.  

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

North America  Production in the quarter for the Gulf of Mexico averaged 32 MBOEPD, with 92 percent liquids. Canada offshore averaged 5 MBOEPD.

4


 

As previously announced in fourth quarter 2018 Murphy closed a Gulf of Mexico transaction with Petrobras America Inc., a subsidiary of Petrobras, for a net, after closing adjustments, cash consideration of $795 million and a 20 percent NCI in MP GOM. The bolt-on transaction provides oil-weighted production and reserves with areas that have additional upside, while utilizing the company’s proven deep-water execution expertise. The contribution from MP GOM in the above volume was limited to one-month only, and was negatively impacted by a well in the Chinook field experiencing a mechanical malfunction, resulting in a daily loss of 4,400 BOEPD net. This well is expected to be worked over in late 2019.

Also in the quarter, the Dalmatian subsea pump was installed. Currently, the pump is delivering gross incremental production of over 10,000 BOEPD, an increase of 250 percent from prior quarter production, with 96 percent uptime.

EXPLORATION 

Gulf of Mexico Exploration – During the fourth quarter, Murphy drilled the King Cake exploration well (Atwater Valley 23) which encountered non-commercial quantities of hydrocarbons and was subsequently plugged and abandoned. The well, which Murphy operated at a 35 percent working interest, cost $16 million net, pre-tax, which is included in the company’s fourth quarter dry hole expense.

Mexico Exploration – During the fourth quarter, Murphy secured its drilling permit from the Comisión Nacional de Hidrocarburos (“CNH”) for the Cholula exploration well and expects to spud the well in the first quarter of 2019.

Vietnam ExplorationMurphy expects to spud the LDT-1X well, in Block 15-01/05 in the Cuu Long Basin, during the first quarter of 2019.

2019 CAPITAL EXPENDITURE AND PRODUCTION GUIDANCE

Murphy is planning 2019 capital expenditures to be in the range of $1.25 to $1.45 billion with full year 2019 production to be in the range of 202 to 210 MBOEPD. Production for the first quarter 2019 is estimated to be in the range of 198 to 202 MBOEPD. Both production and CAPEX guidance ranges exclude Gulf of Mexico noncontrolling interest (NCI). The 2019 plan reflects the company’s ongoing commitment of keeping spending in line with cash flows while simultaneously returning cash to shareholders.

The table below illustrates the capital allocation by area.



 

2019 Capital Expenditure Guidance

Area

Percent of Total CAPEX

U.S. Onshore

43

Canada Onshore

20

North America Offshore

19

SE Asia

9

Exploration

8

Other

1




5


 

For 2019, Murphy is allocating $878 million of capital, or 63 percent, to its North America onshore assets, in comparison to $780 million, or 66 percent in 2018.

In the Eagle Ford Shale, Murphy will spend approximately $600 million in 2019, a 40 percent increase from 2018. The Eagle Ford Shale capital includes approximately $470 million for drilling and completing wells and $130 million for field development and nine non-operated wells. The 2019 plan includes 90 operated wells being brought online which are expected to be equally distributed across the company’s acreage. This is over an 80 percent increase in operated wells online compared to 2018.

The company is allocating $280 million to Canada onshore in the Kaybob Duvernay, Tupper Montney and Placid Montney. In the Kaybob Duvernay, Murphy is allocating $200 million, which is 25 percent lower than in 2018. The Kaybob Duvernay capital allocation will focus only on lease retention across the play. The Kaybob Duvernay, Tupper Montney and Placid Montney will deliver 12, 8, and 7 wells online respectively.

2019 Operated Onshore Wells Online



1Q 2019

2Q 2019

3Q 2019

4Q 2019

2019 Total

Eagle Ford Shale

14

31

25

20

90

Kaybob Duvernay

4

6

2

0

12

Tupper Montney

3

0

5

0

8

Placid Montney

0

0

0

7

7

Production for North America onshore assets, for full year 2019, is expected to increase approximately six percent, to over 100,800 BOEPD as compared to over 94,600 BOEPD for full year 2018. Production in the Eagle Ford Shale is expected to increase from 2018 levels by 4 to 6 MBOEPD. The Kaybob Duvernay and Placid Montney areas are expected to have annual production over 12 MBOEPD, an 8 percent increase from 2018. In the Tupper Montney, production is expected to be approximately 235 MMCFD, in line with 2018 volumes.

Murphy is allocating approximately $360 million of capital to its global offshore assets of which 60 percent will be spent in the Gulf of Mexico, 30 percent in Malaysia, Vietnam, and Brunei, and the remainder in Canada offshore. The capital in the Gulf of Mexico is primarily related to field development projects, including the Dalmatian subsea pump and the Samurai field development activities. Murphy will also be investing capital for a pre-FEED waterflood study for the St. Malo field. In Malaysia, the 2019 capital is primarily related to the Block H FLNG project which is expected to come online in 2020, in addition to development drilling projects related to Gumusut-Kakap and Sarawak, as well as Kikeh Gas Lift.

The company is allocating approximately $110 million to exploration in 2019, with 53 percent for drilling, 21 percent for geological and geophysical studies, and the remainder for other explorations costs.

6


 

“Our 2019 capital program supports our strategy of allocating capital to high margin, oil-weighted assets by investing in our profitable Eagle Ford Shale business while supporting our long-lived, free cash flow providing offshore assets. Our investment program is based on spending within our means while generating free cash flow in addition to our current dividend level,” commented Jenkins.

Detailed guidance for the first quarter and full year 2019 is contained in the following schedule.

CONFERENCE CALL AND WEBCAST SCHEDULED FOR JANUARY 31, 2019

Murphy will host a conference call to discuss 2018 financial and operating results as well as provide 2019 guidance on Thursday, January 31, 2019, at 9:00 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 22385243.

FINANCIAL DATA

Summary financial data and operating statistics for fourth quarter 2018, 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 first quarter and full year 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 offshore production in Southeast Asia, Canada and the Gulf of Mexico, as well as North America onshore plays in the Eagle Ford Shale, Kaybob Duvernay and Montney. Additional information can be found on the company’s website at http://www.murphyoilcorp.com.

7


 

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, increased volatility or deterioration in the level of crude oil and natural gas prices, 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.

RESERVES REPORTING TO THE SECURITIES AND EXCHANGE COMMISSION

The SEC requires oil and natural gas companies, in their filings with the SEC, to disclose proved reserves that a company has demonstrated by actual production or conclusive formation tests to be economically and legally producible under existing economic and operating conditions.  We may use certain terms in this new release, such as “resource”, “gross resource”, “recoverable resource”, “recoverable oil”, “resource base”, “EUR”, or “estimated ultimate recovery” and similar terms that the SEC’s rules prohibit us from including in filings with the SEC.  Investors are urged to consider closely the disclosures and risk factors in our most recent Annual Report on Form 10-K filed with the 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.

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.

Investor Contacts:

Kelly Whitley, kelly_whitley@murphyoilcorp.com, 281-675-9107

Bryan Arciero, bryan_arciero@murphyoilcorp.com, 832-319-5374

Emily McElroy, emily_mcelroy@murphyoilcorp.com, 870-864-6324





8


 

MURPHY OIL CORPORATION

SUMMARIZED CONSOLIDATED STATEMENTS OF OPERATIONS  (unaudited)

(Thousands of dollars, except per share amounts)







 

 

 

 

 

 

 

 



 

Three Months Ended

 

Year Ended



 

December 31,

 

December 31,



 

2018

 

2017 1

 

2018

 

2017 1



 

 

 

 

 

 

 

 

Revenues

 

 

 

 

 

 

 

 

     Revenue from sales to customers

$

664,717 

 

580,455 

 

2,586,627 

 

2,078,548 

     (Loss) gain on crude contracts

 

27,374 

 

(40,799)

 

(41,975)

 

9,566 

     Gain on sale of assets and other income

 

(84)

 

1,929 

 

25,951 

 

137,015 

Total revenues

 

692,007 

 

541,585 

 

2,570,603 

 

2,225,129 



 

 

 

 

 

 

 

 

Costs and expenses

 

 

 

 

 

 

 

 

     Lease operating expenses

 

149,668 

 

122,251 

 

555,894 

 

468,323 

     Severance and ad valorem taxes

 

11,972 

 

10,847 

 

52,072 

 

43,618 

     Exploration expenses, including undeveloped

       lease amortization

 

34,066 

 

45,478 

 

103,977 

 

122,834 

     Selling and general expenses

 

42,700 

 

48,135 

 

216,024 

 

203,573 

     Depreciation, depletion and amortization

 

261,338 

 

242,937 

 

971,901 

 

957,719 

     Accretion of asset retirement obligations

 

12,518 

 

10,953 

 

44,559 

 

42,590 

     Impairment of assets

 

20,000 

 

 -

 

20,000 

 

 -

     Redetermination expense

 

 -

 

15,000 

 

11,332 

 

15,000 

     Other expense (benefit)

 

9,903 

 

19,718 

 

(34,873)

 

30,706 

Total costs and expenses

 

542,165 

 

515,319 

 

1,940,886 

 

1,884,363 

Operating income from continuing operations

 

149,842 

 

26,266 

 

629,717 

 

340,766 



 

 

 

 

 

 

 

 

Other income (loss)

 

 

 

 

 

 

 

 

     Interest and other income (loss)

 

3,670 

 

19,164 

 

(15,775)

 

(87,181)

     Interest expense, net

 

(47,340)

 

(43,360)

 

(181,604)

 

(181,783)

Total other loss

 

(43,670)

 

(24,196)

 

(197,379)

 

(268,964)



 

 

 

 

 

 

 

 

Income from continuing operations before income taxes

 

106,172 

 

2,375 

 

432,338 

 

71,802 

Income tax expense (benefit)

 

(6,471)

 

287,136 

 

9,330 

 

382,738 

Income (loss) from continuing operations

 

112,643 

 

(284,761)

 

423,008 

 

(310,936)

Income (loss) from discontinued operations,

    net of income taxes

 

(872)

 

(2,030)

 

(3,522)

 

(853)

Net income (loss) including noncontrolling interest

 

111,771 

 

(286,791)

 

419,486 

 

(311,789)

Less: Net income (loss) attributable to noncontrolling interest

 

8,392 

 

 -

 

8,392 

 

 -

NET INCOME (LOSS) ATTRIBUTABLE TO MURPHY

$

103,379 

 

(286,791)

 

411,094 

 

(311,789)



 

 

 

 

 

 

 

 

INCOME (LOSS) PER COMMON SHARE – BASIC

 

 

 

 

 

 

 

 

     Continuing operations

$

0.60 

 

(1.65)

 

2.39 

 

(1.81)

     Discontinued operations

 

 -

 

(0.01)

 

(0.01)

 

 -

         Net Income (Loss)

$

0.60 

 

(1.66)

 

2.38 

 

(1.81)



 

 

 

 

 

 

 

 

INCOME (LOSS) PER COMMON SHARE – DILUTED

 

 

 

 

 

 

 

 

     Continuing operations

$

0.59 

 

(1.65)

 

2.37 

 

(1.81)

     Discontinued operations

 

 -

 

(0.01)

 

(0.01)

 

 -

         Net Income (Loss)

$

0.59 

 

(1.66)

 

2.36 

 

(1.81)



 

 

 

 

 

 

 

 

Cash dividends per Common share

 

0.25 

 

0.25 

 

1.00 

 

1.00 



 

 

 

 

 

 

 

 

Average Common shares outstanding (thousands)

 

 

 

 

 

 

 

 

     Basic

 

173,055 

 

172,573 

 

172,974 

 

172,524 

     Diluted

 

174,312 

 

172,573 

 

174,209 

 

172,524 



1 Reclassified to conform to current presentation.

9


 

MURPHY OIL CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)

(Thousands of dollars)





 

 

 

 

 

 

 

 

 



 

Three Months Ended

 

Year Ended

 



 

December 31,

 

December 31,

 



 

2018

 

2017

 

2018

 

2017

 

Operating Activities

 

 

 

 

 

 

 

 

 

Net income (loss) including noncontrolling interest

$

111,771 

 

(286,791)

 

419,486 

 

(311,789)

 

Adjustments to reconcile net income (loss) to net cash provided by continuing

  operations activities:

 

 

 

 

 

 

 

 

 

Loss (Income) from discontinued operations

 

872 

 

2,030 

 

3,522 

 

853 

 

Depreciation, depletion and amortization

 

261,338 

 

242,937 

 

971,901 

 

957,719 

 

Impairment of assets

 

20,000 

 

– 

 

20,000 

 

– 

 

Dry hole costs (credits)

 

16,098 

 

(3,024)

 

20,624 

 

(4,163)

 

Amortization of undeveloped leases

 

8,633 

 

20,916 

 

40,177 

 

61,776 

 

Accretion of asset retirement obligations

 

12,518 

 

10,953 

 

44,559 

 

42,590 

 

Deferred income tax charge (benefit)

 

(44,925)

 

263,987 

 

(183,680)

 

260,420 

 

Pretax (gain) loss from sale of assets

 

(48)

 

3,332 

 

(54)

 

(127,434)

 

Net (increase) decrease in noncash operating working capital

 

(167,258)

 

135,344 

 

(169,808)

 

136,414 

 

Other operating activities, net

 

3,452 

 

(80,407)

 

52,669 

 

111,689 

 

Net cash provided by continuing operations activities

 

222,451 

 

309,277 

 

1,219,396 

 

1,128,075 

 



 

 

 

 

 

 

 

 

 

Investing Activities

 

 

 

 

 

 

 

 

 

Acquisition of oil properties

 

(794,623)

 

– 

 

(794,623)

 

– 

 

Property additions and dry hole costs

 

(244,449)

 

(303,250)

 

(1,102,805)

 

(1,009,667)

 

Proceeds from sales of property, plant and equipment

 

255 

 

360 

 

1,383 

 

69,506 

 

Purchases of investment securities 1

 

– 

 

– 

 

– 

 

(212,661)

 

Proceeds from maturity of investment securities 1

 

– 

 

– 

 

– 

 

320,828 

 

Net cash required by investing activities

 

(1,038,817)

 

(302,890)

 

(1,896,045)

 

(831,994)

 



 

 

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

 

 

 

 

Increase (decrease) in revolving credit facility

 

325,000 

 

– 

 

325,000 

 

– 

 

Borrowings of debt, net of issuance costs

 

– 

 

(175)

 

– 

 

541,597 

 

Repayments of debt

 

– 

 

– 

 

– 

 

(550,000)

 

Capital lease obligation payments

 

(2,586)

 

(2,446)

 

(9,750)

 

(17,133)

 

Withholding tax on stock-based incentive awards

 

(1,154)

 

35 

 

(8,076)

 

(7,116)

 

Issue cost of debt facility

 

(6,366)

 

– 

 

(6,366)

 

– 

 

Cash dividends paid

 

(43,264)

 

(43,144)

 

(173,044)

 

(172,565)

 

Net cash required by financing activities

 

271,630 

 

(45,730)

 

127,764 

 

(205,217)

 



 

 

 

 

 

 

 

 

 

Effect of exchange rate changes on cash and cash equivalents

 

(15,623)

 

7,124 

 

(28,730)

 

1,327 

 

Net increase (decrease) in cash and cash equivalents

 

(560,359)

 

(32,219)

 

(577,615)

 

92,191 

 

Cash and cash equivalents at beginning of period

 

947,732 

 

997,207 

 

964,988 

 

872,797 

 

Cash and cash equivalents at end of period

$

387,373 

 

964,988 

 

387,373 

 

964,988 

 



1    Investments are Canadian government securities with maturities greater than 90 days at the date of acquisition.

10


 

MURPHY OIL CORPORATION

SCHEDULE OF ADJUSTED INCOME (LOSS)

(unaudited)

(Millions of dollars, except per share amounts)







 

 

 

 

 

 

 

 



 

Three Months Ended

 

Year Ended



 

December 31,

 

December 31,



 

2018

 

2017

 

2018

 

2017

Net income (loss) attributable to Murphy (GAAP)

$

103.4 

 

(286.8)

 

411.1 

 

(311.8)

Discontinued operations loss (income)

 

0.9 

 

2.0 

 

3.5 

 

0.9 

Income from continuing operations

 

104.3 

 

(284.8)

 

414.6 

 

(310.9)

Adjustments:

 

 

 

 

 

 

 

 

Impact of tax reform

 

(15.7)

 

274.3 

 

(135.7)

 

274.3 

Mark-to-market (gain) loss on crude oil derivative contracts

 

(27.6)

 

20.0 

 

(26.8)

 

(8.9)

Ecuador arbitration settlement

 

– 

 

– 

 

(20.5)

 

– 

Brunei working interest income

 

– 

 

– 

 

(16.0)

 

– 

Impairment of assets

 

15.8 

 

– 

 

15.8 

 

– 

Seal insurance proceeds

 

– 

 

– 

 

(15.2)

 

– 

Tax benefits on investments in foreign areas

 

(14.7)

 

– 

 

(14.7)

 

(32.9)

Foreign exchange losses (gains)

 

(3.9)

 

(22.4)

 

10.2 

 

64.2 

Malaysia/ Brunei unitization/ redetermination expense

 

– 

 

9.3 

 

7.0 

 

9.3 

Write-off of previously suspended exploration wells

 

– 

 

– 

 

4.5 

 

– 

Mark-to-market (gain) loss on PAI contingent consideration

 

(3.8)

 

– 

 

(3.8)

 

– 

Deferred tax on undistributed foreign earnings

 

– 

 

– 

 

– 

 

65.2 

Gain on sale of assets

 

– 

 

2.5 

 

– 

 

(93.5)

Oil Insurance Limited dividends

 

– 

 

– 

 

– 

 

(2.9)

Materials inventory loss

 

– 

 

14.1 

 

– 

 

14.1 

Total adjustments after taxes

 

(49.9)

 

297.8 

 

(195.2)

 

288.9 

Adjusted income (loss) attributable to Murphy

$

54.4 

 

13.0 

 

219.4 

 

(22.0)



 

 

 

 

 

 

 

 

Adjusted income (loss) per diluted share

$

0.31 

 

0.08 

 

1.26 

 

(0.13)




Non-GAAP Financial Measures

Presented above is a reconciliation of Net income(loss) to Adjusted income  (loss).  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 (loss) 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

 

Year Ended



 

December 31, 2018

 

December 31, 2018



 

Pretax

 

Tax

 

Net

 

Pretax

 

Tax

 

Net

Exploration & Production:

 

 

 

 

 

 

 

 

 

 

 

 

  United States

$

15.2 

 

(3.2)

 

12.0 

 

15.2 

 

(3.2)

 

12.0 

  Canada

 

 –

 

 –

 

 –

 

(21.0)

 

5.8 

 

(15.2)

  Malaysia

 

 –

 

 –

 

 –

 

11.3 

 

(4.3)

 

7.0 

  Other International

 

 –

 

(14.7)

 

(14.7)

 

(11.5)

 

(14.7)

 

(26.2)

Total E&P

 

15.2 

 

(17.9)

 

(2.7)

 

(6.0)

 

(16.4)

 

(22.4)

Corporate 1:

 

(40.3)

 

(6.9)

 

(47.2)

 

(51.9)

 

(120.9)

 

(172.8)

Total adjustments

$

(25.1)

 

(24.8)

 

(49.9)

 

(57.9)

 

(137.3)

 

(195.2)



1 In 2018, the Company reported realized and unrealized gains and losses on crude oil contracts in the Corporate segment to reflect how segments are currently evaluated, how resources are allocated and how risk is managed by the Company.  The 2017 amounts have been reclassified from the Exploration and Production business for comparable disclosure.

11


 



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

 

Year Ended



 

December 31,

 

December 31,



 

2018

 

2017

 

2018

 

2017

Net income (loss) attributable to Murphy (GAAP)

$

103.4 

 

(286.8)

 

411.1 

 

(311.8)

Discontinued operations loss (income)

 

0.9 

 

2.0 

 

3.5 

 

0.9 

Income tax expense (benefit)

 

(6.5)

 

287.1 

 

9.3 

 

382.7 

Interest expense, net

 

47.3 

 

43.4 

 

181.6 

 

181.8 

Depreciation, depletion and amortization expense

 

256.3 

 

242.9 

 

966.9 

 

957.7 

Impairment of assets

 

20.0 

 

– 

 

20.0 

 

– 

EBITDA attributable to Murphy (Non-GAAP)

$

421.4 

 

288.6 

 

1,592.4 

 

1,211.3 

Accretion of asset retirement obligations

 

12.5 

 

11.0 

 

44.6 

 

42.6 

Mark-to-market (gain) loss on crude oil derivative contracts

 

(35.0)

 

30.8 

 

(33.9)

 

(13.7)

Ecuador arbitration settlement

 

– 

 

– 

 

(26.0)

 

– 

Seal insurance proceeds

 

– 

 

– 

 

(21.0)

 

– 

Brunei working interest income

 

– 

 

– 

 

(16.0)

 

– 

Malaysia/ Brunei unitization/ redetermination expense

 

– 

 

15.0 

 

11.3 

 

15.0 

Foreign exchange losses (gains)

 

(5.3)

 

(24.0)

 

8.1 

 

75.1 

Mark-to-market (gain) loss on PAI contingent consideration

 

(4.8)

 

– 

 

(4.8)

 

– 

Write-off of previously suspended exploration wells

 

– 

 

– 

 

4.5 

 

– 

Gain on sale of assets

 

– 

 

3.3 

 

– 

 

(127.4)

Oil Insurance Limited dividends

 

– 

 

– 

 

– 

 

(4.4)

Materials inventory loss

 

– 

 

21.0 

 

– 

 

21.0 

Adjusted EBITDA attributable to Murphy (Non-GAAP)

$

388.8 

 

345.7 

 

1,559.2 

 

1,219.5 



 

 

 

 

 

 

 

 

Total barrels of oil equivalents sold attributable to Murphy (thousands of barrels)

 

16,417.4 

 

15,106.4 

 

62,330.5 

 

59,321.6 



 

 

 

 

 

 

 

 

EBITDA per barrel of oil equivalents sold

$

25.67 

 

19.10 

 

25.55 

 

20.42 

Adjusted EBITDA per barrel of oil equivalents sold

$

23.68 

 

22.88 

 

25.02 

 

20.56 



Non-GAAP Financial Measures

Presented above is a reconciliation of Net income (loss) 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.





12


 

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

 

Year Ended



 

December 31,

 

December 31,



 

2018

 

2017

 

2018

 

2017

Net income (loss) attributable to Murphy (GAAP)

$

103.4 

 

(286.8)

 

411.1 

 

(311.8)

Discontinued operations loss (income)

 

0.9 

 

2.0 

 

3.5 

 

0.9 

Income tax expense (benefit)

 

(6.5)

 

287.1 

 

9.3 

 

382.7 

Interest expense, net

 

47.3 

 

43.4 

 

181.6 

 

181.8 

Depreciation, depletion and amortization expense

 

256.3 

 

242.9 

 

966.9 

 

957.7 

Impairment of assets

 

20.0 

 

– 

 

20.0 

 

– 

EBITDA attributable to Murphy (Non-GAAP)

 

421.4 

 

288.6 

 

1,592.4 

 

1,211.3 

Exploration expenses

 

34.1 

 

45.5 

 

104.0 

 

122.8 

EBITDAX attributable to Murphy (Non-GAAP)

$

455.5 

 

334.1 

 

1,696.4 

 

1,334.1 

Accretion of asset retirement obligations

 

12.5 

 

11.0 

 

44.6 

 

42.6 

Mark-to-market (gain) loss on crude oil derivative contracts

 

(35.0)

 

30.8 

 

(33.9)

 

(13.7)

Ecuador arbitration settlement

 

– 

 

– 

 

(26.0)

 

– 

Seal insurance proceeds

 

– 

 

– 

 

(21.0)

 

– 

Brunei working interest income

 

– 

 

– 

 

(16.0)

 

– 

Malaysia/ Brunei unitization/ redetermination expense

 

– 

 

15.0 

 

11.3 

 

15.0 

Foreign exchange losses (gains)

 

(5.3)

 

(24.0)

 

8.1 

 

75.1 

Mark-to-market (gain) loss on PAI contingent consideration

 

(4.8)

 

– 

 

(4.8)

 

– 

Gain on sale of assets

 

– 

 

3.3 

 

– 

 

(127.4)

Oil Insurance Limited dividends

 

– 

 

– 

 

– 

 

(4.4)

Materials inventory loss

 

– 

 

21.0 

 

– 

 

21.0 

Adjusted EBITDAX attributable to Murphy (Non-GAAP)

$

422.9 

 

391.2 

 

1,658.7 

 

1,342.3 



 

 

 

 

 

 

 

 

Total barrels of oil equivalents sold attributable to Murphy (thousands of barrels)

 

16,417.4 

 

15,106.4 

 

62,330.5 

 

59,321.6 



 

 

 

 

 

 

 

 

EBITDAX per barrel of oil equivalents sold

$

27.74 

 

22.12 

 

27.22 

 

22.49 

Adjusted EBITDAX per barrel of oil equivalents sold

$

25.76 

 

25.90 

 

26.61 

 

22.63 



Non-GAAP Financial Measures

Presented above is a reconciliation of Net income (loss) 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.

13


 



MURPHY OIL CORPORATION

FUNCTIONAL RESULTS OF OPERATIONS (unaudited)

(Millions of dollars)







 

 

 

 

 

 

 

 

 



Three Months Ended      December 31, 2018

 

 

Three Months Ended December 31, 2017



 

Revenues

 

Income

(Loss)

 

 

Revenues

 

Income
(Loss)

Exploration and production

 

 

 

 

 

 

 

 

 

    United States 1, 4

$

344.0 

 

42.6 

 

 

298.0 

 

22.4 

    Canada

 

104.8 

 

4.4 

 

 

97.4 

 

9.8 

    Malaysia

 

213.6 

 

61.1 

 

 

186.8 

 

50.3 

    Other

 

2.3 

 

12.3 

 

 

– 

 

(26.6)

        Total exploration and production

 

664.7 

 

120.4 

 

 

582.2 

 

55.9 

Corporate 1

 

27.3 

 

(7.7)

 

 

(40.6)

 

(340.7)

Revenue/income from continuing operations

 

692.0 

 

112.7 

 

 

541.6 

 

(284.8)

Discontinued operations, net of tax

 

– 

 

(0.9)

 

 

– 

 

(2.0)

Total revenues/net income (loss)

$

692.0 

 

111.8 

 

 

541.6 

 

(286.8)



 

 

 

 

 

 

 

 

 



 

 

 

 

 

 

 

 

 



 

 

 

 

 

 

 

 

 



Year Ended                        December 31, 2018

 

 

Year Ended                  December 31, 2017



 

Revenues

 

Income
(Loss)

 

 

Revenues

 

Income
(Loss)

Exploration and production

 

 

 

 

 

 

 

 

 

    United States 4

$

1,289.6 

 

242.9 

 

 

944.3 

 

(8.9)

    Canada  2

 

438.6 

 

51.1 

 

 

485.5 

 

112.5 

    Malaysia

 

854.2 

 

269.5 

 

 

781.1 

 

224.2 

    Other

 

22.2 

 

(16.6)

 

 

– 

 

(37.5)

        Total exploration and production

 

2,604.6 

 

546.9 

 

 

2,210.9 

 

290.3 

Corporate 3

 

(34.0)

 

(123.9)

 

 

14.2 

 

(601.2)

Revenue/income from continuing operations

 

2,570.6 

 

423.0 

 

 

2,225.1 

 

(310.9)

Discontinued operations, net of tax

 

– 

 

(3.5)

 

 

– 

 

(0.9)

Total revenues/net income (loss)

$

2,570.6 

 

419.5 

 

 

2,225.1 

 

(311.8)



1 In 2018, the Company reported realized and unrealized gains and losses on crude oil contracts in the Corporate segment to reflect how segments are currently evaluated, how resources are allocated and how risk is managed by the Company.  The 2017 amounts have been reclassified from the U.S. Exploration and production business to reflect comparable disclosure.  Realized and unrealized gains (losses) of $27.4 million and ($40.8) million are included in the Corporate segment for the three month periods ended December, 2018 and 2017, respectively. Realized and unrealized gains (losses) of ($42.0) million and $9.6 million are included in the Corporate segment for the years ended December 31, 2018 and 2017, respectively. Corporate segment loss for the three-month periods ended December 31, 2018 and 2017 included foreign exchange gain of $5.0 million and $23.7 million, respectively.  Corporate segment loss for the years ended December 31, 2018 and 2017 included foreign exchange losses of $9.0 million and $97.1 million, respectively. 

2  2017 revenue includes a pretax gain of $132.4 million ($96.0 million after-tax) related to the sale of the Seal heavy oil asset in Canada.

3 Corporate net loss for the year ended December 31, 2018 included a credit to income tax expense of $135.7 million related to an IRS interpretation of the Tax Cuts and Jobs Act (the Act).  Corporate net loss for the year ended December 31, 2017 included a charge of $274.3 million relating to the impact of the Act.

4 In 2018, includes results attributable to a noncontrolling interest in MP GOM LLC, a  Gulf of Mexico joint venture (MP GOM).  

14


 

MURPHY OIL CORPORATION
OIL AND GAS OPERATING RESULTS (unaudited)
THREE MONTHS ENDED DECEMBER 31,  2018 AND 2017



 

 

 

 

 

 



 

 

 

 

 

 



 

 

 

 

 

 



 

United

 

 

 

 

(Millions of dollars)

 

States 1

Canada

Malaysia

Other

Total

Three Months Ended December 31, 2018

 

 

 

 

 

 

Oil and gas sales and other revenues

$

344.0  104.8  213.6  2.3  664.7 

Lease operating expenses

 

67.9  31.6  49.7  0.4  149.6 

Severance and ad valorem taxes

 

11.7  0.3 

– 

– 

12.0 

Depreciation, depletion and amortization

 

137.1  61.3  56.7  1.0  256.1 

Accretion of asset retirement obligations

 

6.0  1.9  4.6 

– 

12.5 

Impairment of assets

 

20.0 

– 

– 

– 

20.0 

Exploration expenses

 

 

 

 

 

 

    Dry holes

 

16.0 

– 

0.1 

– 

16.1 

    Geological and geophysical

 

0.6 

– 

1.5  2.4  4.5 

    Other exploration

 

1.1  0.3 

– 

3.5  4.9 



 

17.7  0.3  1.6  5.9  25.5 

    Undeveloped lease amortization

 

7.6  0.3 

– 

0.7  8.6 

        Total exploration expenses

 

25.3  0.6  1.6  6.6  34.1 

Selling and general expenses

 

10.0  6.1  2.6  5.4  24.1 

Other

 

10.8  1.7  (0.2) 1.2  13.5 

Results of operations before taxes

 

55.2  1.3  98.6  (12.3) 142.8 

Income tax provisions (benefits)

 

12.6  (3.1) 37.5  (24.6) 22.4 

Results of operations (excluding
  corporate overhead and interest)

$

42.6  4.4  61.1  12.3  120.4 



 

 

 

 

 

 

Three Months Ended December 31, 2017

 

 

 

 

 

 

Oil and gas sales and other revenues

$

298.0  97.4  186.8 

– 

582.2 

Lease operating expenses

 

62.8  24.3  35.2 

– 

122.3 

Severance and ad valorem taxes

 

10.6  0.2 

– 

– 

10.8 

Depreciation, depletion and amortization

 

144.0  48.8  44.9  1.0  238.7 

Accretion of asset retirement obligations

 

4.6  2.0  4.3 

– 

10.9 

Redetermination expense

 

– 

– 

15.0 

– 

15.0 

Exploration expenses

 

 

 

 

 

 

    Dry holes

 

– 

– 

(0.1) (3.0) (3.1)

    Geological and geophysical

 

2.1 

– 

1.7  11.6  15.4 

    Other exploration

 

1.1  0.2 

– 

10.9  12.2 



 

3.2  0.2  1.6  19.5  24.5 

    Undeveloped lease amortization

 

20.7  0.2 

– 

– 

20.9 

        Total exploration expenses

 

23.9  0.4  1.6  19.5  45.4 

Selling and general expenses

 

13.2  7.2  3.5  4.5  28.4 

Other

 

18.5  1.9  (0.7)

– 

19.7 

Results of operations before taxes

 

20.4  12.6  83.0  (25.0) 91.0 

Income tax provisions (benefits)

 

(2.0) 2.8  32.7  1.6  35.1 

Results of operations (excluding
  corporate overhead and interest)

$

22.4  9.8  50.3  (26.6) 55.9 

1  In 2018, the Company reported realized and unrealized gains and losses on crude oil contracts in the Corporate segment to reflect how segments are currently evaluated, how resources are allocated and how risk is managed by the Company.  The 2017 amounts have been reclassified from the Exploration and Production business for comparable disclosure. 2018 also includes results attributable to a noncontrolling interest in MP GOM, effective November 30, 2018.

15


 



MURPHY OIL CORPORATION

OIL AND GAS OPERATING RESULTS (unaudited)

YEAR ENDED DECEMBER 31,  2018 AND 2017





 

 

 

 

 

 



 

 

 

 

 

 



 

 

 

 

 

 



 

United

 

 

 

 

(Millions of dollars)

 

States 1

Canada 2

Malaysia

Other

Total

Year Ended December 31, 2018

 

 

 

 

 

 

Oil and gas sales and other revenues

$

1,289.6  438.6  854.2  22.2  2,604.6 

Lease operating expenses

 

230.5  122.6  202.1  0.7  555.9 

Severance and ad valorem taxes

 

50.9  1.2 

– 

– 

52.1 

Depreciation, depletion and amortization

 

519.5  232.4  198.6  3.5  954.0 

Accretion of asset retirement obligations

 

19.5  7.7  17.4 

– 

44.6 

Impairment of assets

 

20.0 

– 

– 

– 

20.0 

Redetermination expense

 

– 

– 

11.3 

– 

11.3 

Exploration expenses

 

 

 

 

 

 

    Dry holes

 

16.0 

– 

0.1  4.5  20.6 

    Geological and geophysical

 

7.1 

– 

2.1  6.7  15.9 

    Other exploration

 

6.3  0.6 

– 

20.4  27.3 



 

29.4  0.6  2.2  31.6  63.8 

    Undeveloped lease amortization

 

36.8  0.8 

– 

2.5  40.1 

        Total exploration expenses

 

66.2  1.4  2.2  34.1  103.9 

Selling and general expenses

 

49.0  26.8  10.8  23.5  110.1 

Other

 

23.0  (19.1) (1.0) 2.3  5.2 

Results of operations before taxes

 

311.0  65.6  412.8  (41.9) 747.5 

Income tax provisions (benefits)

 

68.1  14.5  143.3  (25.3) 200.6 

Results of operations (excluding
  corporate overhead and interest)

$

242.9  51.1  269.5  (16.6) 546.9 



 

 

 

 

 

 

Year Ended December 31, 2017

 

 

 

 

 

 

Oil and gas sales and other revenues

$

944.3  485.5  781.1 

– 

2,210.9 

Lease operating expenses

 

198.5  101.1  168.8 

– 

468.4 

Severance and ad valorem taxes

 

42.2  1.5 

– 

– 

43.7 

Depreciation, depletion and amortization

 

546.1  185.4  204.6  3.8  939.9 

Accretion of asset retirement obligations

 

17.4  7.9  17.3 

– 

42.6 

Redetermination expense

 

– 

– 

15.0 

– 

15.0 

Exploration expenses

 

 

 

 

 

 

    Dry holes

 

(1.9)

– 

0.7  (3.0) (4.2)

    Geological and geophysical

 

3.1  0.1  1.7  17.6  22.5 

    Other exploration

 

6.6  0.4 

– 

35.7  42.7 



 

7.8  0.5  2.4  50.3  61.0 

    Undeveloped lease amortization

 

60.2  1.6 

– 

– 

61.8 

        Total exploration expenses

 

68.0  2.1  2.4  50.3  122.8 

Selling and general expenses

 

61.8  28.3  14.0  19.6  123.7 

Other

 

20.0  2.3  8.4 

– 

30.7 

Results of operations before taxes

 

(9.7) 156.9  350.6  (73.7) 424.1 

Income tax provisions (benefits)

 

(0.8) 44.4  126.4  (36.2) 133.8 

Results of operations (excluding
  corporate overhead and interest)

$

(8.9) 112.5  224.2  (37.5) 290.3 

1  In 2018, the Company reported realized and unrealized gains and losses on crude oil contracts in the Corporate segment to reflect how segments are currently evaluated, how resources are allocated and how risk is managed by the Company.  The 2017 amounts have been reclassified from the Exploration and Production business for comparable disclosure. 2018 also includes results attributable to a noncontrolling interest in MP GOM, effective November 30, 2018.

2 2017 revenue includes a pretax gain of $132.4 million related to the sale of Seal heavy oil assets in Canada.

16


 

MURPHY OIL CORPORATION

PRODUCTION-RELATED EXPENSES

(unaudited)

(Dollars per barrel of oil equivalents sold)







 

 

 

 

 

 

 

 



Three Months Ended

 

Year Ended



December 31,

 

December 31,



 

2018

 

2017

 

2018

 

2017



 

 

 

 

 

 

 

 

United States – Eagle Ford Shale

 

 

 

 

 

 

 

 

     Lease operating expense

$

10.83 

 

6.70 

 

8.84 

 

7.35 

     Severance and ad valorem taxes

 

3.13 

 

2.27 

 

3.20 

 

2.46 

     Depreciation, depletion and amortization (DD&A) expense

 

24.41 

 

25.39 

 

24.54 

 

25.64 



 

 

 

 

 

 

 

 

United States – Gulf of Mexico

 

 

 

 

 

 

 

 

     Lease operating expense

$

9.16 

 

22.29 

 

11.39 

 

13.71 

     DD&A expense

 

15.32 

 

17.62 

 

16.50 

 

20.20 



 

 

 

 

 

 

 

 

Canada – Onshore

 

 

 

 

 

 

 

 

     Lease operating expense

$

4.04 

 

4.50 

 

4.52 

 

4.95 

     Severance and ad valorem taxes

 

0.06 

 

0.07 

 

0.06 

 

0.10 

     DD&A expense

 

10.99 

 

9.79 

 

10.61 

 

9.92 



 

 

 

 

 

 

 

 

Canada – Offshore

 

 

 

 

 

 

 

 

     Lease operating expense

$

21.85 

 

9.08 

 

15.21 

 

9.61 

     DD&A expense

 

14.45 

 

12.93 

 

13.68 

 

12.95 



 

 

 

 

 

 

 

 

Malaysia – Sarawak

 

 

 

 

 

 

 

 

     Lease operating expense

$

8.26 

 

4.34 

 

8.12 

 

5.24 

     DD&A expense

 

8.95 

 

8.08 

 

8.65 

 

8.09 



 

 

 

 

 

 

 

 

Malaysia – Block K

 

 

 

 

 

 

 

 

     Lease operating expense

$

14.83 

 

14.35 

 

16.97 

 

14.13 

     DD&A expense

 

17.69 

 

14.42 

 

15.52 

 

14.60 



 

 

 

 

 

 

 

 

Total oil and gas operations

 

 

 

 

 

 

 

 

     Lease operating expense

$

8.91 

 

8.09 

 

8.86 

 

7.89 

     Severance and ad valorem taxes

 

0.71 

 

0.72 

 

0.83 

 

0.74 

     DD&A expense

 

15.56 

 

15.79 

 

15.50 

 

15.85 



 

 

 

 

 

 

 

 

Total oil and gas operations – excluding noncontrolling interest

 

 

 

 

 

 

 

 

     Lease operating expense

$

8.95 

 

 –

 

8.88 

 

 –

     Severance and ad valorem taxes

 

0.71 

 

 –

 

0.83 

 

 –

     DD&A expense

 

15.30 

 

 –

 

15.23 

 

 –





17


 

MURPHY OIL CORPORATION

OTHER FINANCIAL DATA

(unaudited)

(Millions of dollars)





 

 

 

 

 

 

 

 

 



 

Three Months Ended

 

Year Ended

 



 

December 31,

 

December 31,

 



 

2018

 

2017

 

2018

 

2017

 

Capital expenditures

 

 

 

 

 

 

 

 

 

     Exploration and production 1

 

 

 

 

 

 

 

 

 

         United States

$

934.5 

 

130.6 

 

1,389.1 

 

558.1 

 

         Canada

 

86.8 

 

91.8 

 

378.1 

 

296.4 

 

         Malaysia

 

54.8 

 

10.7 

 

140.6 

 

18.4 

 

         Other

 

12.7 

 

33.0 

 

51.6 

 

88.0 

 

              Total

 

1,088.8 

 

266.1 

 

1,959.4 

 

960.9 

 



 

 

 

 

 

 

 

 

 

     Corporate

 

5.5 

 

7.9 

 

27.9 

 

14.8 

 

              Total capital expenditures

 

1,094.3 

 

274.0 

 

1,987.3 

 

975.7 

 



 

 

 

 

 

 

 

 

 

     Charged to exploration expenses 2

 

 

 

 

 

 

 

 

 

         United States

 

17.7 

 

3.2 

 

29.4 

 

7.8 

 

         Canada

 

0.3 

 

0.2 

 

0.6 

 

0.5 

 

         Malaysia

 

1.6 

 

1.6 

 

2.2 

 

2.4 

 

         Other

 

5.9 

 

19.5 

 

31.6 

 

50.3 

 

              Total charged to exploration expenses

 

25.5 

 

24.5 

 

63.8 

 

61.0 

 



 

 

 

 

 

 

 

 

 

              Total capitalized  3

$

1,068.8 

 

249.5 

 

1,923.5 

 

914.7 

 



 

 

 

 

 

 

 

 

 

1  Includes 2018 acquisition capital expenditure related to MP GOM of $794.6 million.

2 Excludes amortization of undeveloped leases of $8.6 million and $20.9 million for the three months ended December 31, 2018 and 2017,  
   respectively, and $40.2 million and $61.8 million for the year ended December 31, 2018 and 2017, respectively.

3 Includes noncontrolling interest capital expenditures of $3.0 million. 

 

18


 



 

 

 

 

 

MURPHY OIL CORPORATION

CONDENSED BALANCE SHEETS (unaudited)

(Millions of dollars)



 

 

 

 

 



 

December 31, 2018

 

 

December 31, 2017



 

 

 

 

 

     Assets

 

 

 

 

 

     Cash and cash equivalents

$

387.4 

 

 

965.0 

     Other current assets

 

492.4 

 

 

406.6 

     Property, plant and equipment – net

 

9,757.6 

 

 

8,220.0 

     Other long-term assets

 

415.2 

 

 

269.3 

          Total assets

$

11,052.6 

 

 

9,860.9 



 

 

 

 

 

     Liabilities and Stockholders' Equity

 

 

 

 

 

     Current maturities of long-term debt

$

10.6 

 

 

9.9 

     Other current liabilities

 

835.5 

 

 

824.3 

     Long-term debt 1

 

3,227.1 

 

 

2,906.5 

     Other long-term liabilities

 

1,781.8 

 

 

1,500.0 

     Total equity 2

 

5,197.6 

 

 

4,620.2 

          Total liabilities and stockholders' equity

$

11,052.6 

 

 

9,860.9 

1 Includes a capital lease on production equipment of $125.8 million at December 31, 2018 and $134.0 million at December 31, 2017.

2  2018 includes noncontrolling interest of $368.3 million. 

 

19


 

MURPHY OIL CORPORATION

PRODUCTION SUMMARY

(unaudited)







 

 

 

 

 

 

 

 



 

Three Months Ended

 

Year Ended



 

December 31,

 

December 31,

Barrels per day unless otherwise noted

2018

 

2017

 

2018

 

2017

Net crude oil and condensate

 

 

 

 

 

 

 

United States

Onshore

29,609 

 

38,709 

 

31,787 

 

34,649 



Gulf of Mexico 1

32,412 

 

12,266 

 

18,702 

 

11,551 

Canada   

Onshore

7,017 

 

3,821 

 

5,690 

 

3,004 



Offshore

5,109 

 

8,064 

 

6,701 

 

8,091 



Heavy 2

– 

 

– 

 

– 

 

150 

Malaysia

Sarawak

11,958 

 

12,519 

 

11,942 

 

12,674 



Block K

15,351 

 

17,578 

 

16,734 

 

20,312 

         Brunei

 

537 

 

– 

 

558 

 

– 

Total net crude oil and condensate

101,993 

 

92,957 

 

92,114 

 

90,431 

Net natural gas liquids

 

 

 

 

 

 

 

 

United States

Onshore

6,049 

 

7,038 

 

6,578 

 

6,867 



Gulf of Mexico 1

1,312 

 

881 

 

1,147 

 

947 

Canada  

Onshore

1,273 

 

799 

 

1,073 

 

508 

Malaysia

Sarawak

1,145 

 

465 

 

792 

 

829 

Total net natural gas liquids

 

9,779 

 

9,183 

 

9,590 

 

9,151 

Net natural gas  – thousands of cubic feet per day

 

 

 

 

 

 

 

United States

Onshore

30,356 

 

31,956 

 

31,832 

 

32,629 



Gulf of Mexico 1

15,970 

 

12,619 

 

14,356 

 

11,901 

Canada  

Onshore

267,421 

 

244,309 

 

266,416 

 

226,218 

Malaysia

Sarawak

99,830 

 

99,080 

 

104,457 

 

104,616 



Block K

3,589 

 

9,230 

 

5,766 

 

8,358 

Total net natural gas - thousands of cubic feet per day

417,166 

 

397,194 

 

422,827 

 

383,722 

Total net hydrocarbons including NCI 3,4

181,300 

 

168,339 

 

172,175 

 

163,536 

Noncontrolling interest

 

 

 

 

 

 

 

 

Net crude oil and condensate – barrels per day

(4,500)

 

– 

 

(1,134)

 

– 

Net natural gas liquids – barrels per day

(94)

 

– 

 

(24)

 

– 

Net natural gas – thousands of cubic feet per day

(1,705)

 

– 

 

(430)

 

– 

Total noncontrolling interest

(4,878)

 

– 

 

(1,230)

 

– 

Total net hydrocarbons excluding NCI 3,4

176,422 

 

168,339 

 

170,946 

 

163,536 





1 2018 includes net volumes attributable to a noncontrolling interest in MP GOM, a Gulf of Mexico joint venture.

2  The Company sold the Seal area heavy oil field in January 2017.

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

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

 

20


 

MURPHY OIL CORPORATION

SALES SUMMARY

(unaudited)







 

 

 

 

 

 

 

 



 

Three Months Ended

 

Year Ended



 

December 31,

 

December 31,

Barrels per day unless otherwise noted

2018

 

2017

 

2018

 

2017

Net crude oil and condensate

 

 

 

 

 

 

 

United States

Onshore

29,609 

 

38,709 

 

31,787 

 

34,649 



Gulf of Mexico 1

28,554 

 

12,266 

 

17,729 

 

11,551 

Canada   

Onshore

7,017 

 

3,821 

 

5,690 

 

3,004 



Offshore

5,954 

 

6,673 

 

6,884 

 

7,525 



Heavy 2

– 

 

– 

 

– 

 

150 

Malaysia

Sarawak

13,354 

 

9,795 

 

12,401 

 

12,454 



Block K

18,672 

 

16,757 

 

17,025 

 

19,867 

         Brunei

 

463 

 

– 

 

233 

 

– 

Total net crude oil and condensate

103,623 

 

88,021 

 

91,749 

 

89,200 

Net natural gas liquids

 

 

 

 

 

 

 

 

United States

Onshore

6,049 

 

7,038 

 

6,578 

 

6,867 



Gulf of Mexico 1

1,312 

 

881 

 

1,147 

 

947 

Canada  

Onshore

1,273 

 

799 

 

1,073 

 

508 

Malaysia

Sarawak

773 

 

1,263 

 

786 

 

1,048 

Total net natural gas liquids

9,407 

 

9,981 

 

9,584 

 

9,370 

Net natural gas – thousands of cubic feet per day

 

 

 

 

 

 

 

United States

Onshore

30,356 

 

31,956 

 

31,832 

 

32,629 



Gulf of Mexico 1

15,970 

 

12,619 

 

14,356 

 

11,901 

Canada  

Onshore

267,421 

 

244,309 

 

266,416 

 

226,218 

Malaysia

Sarawak

99,830 

 

99,080 

 

104,457 

 

104,616 



Block K

3,589 

 

9,230 

 

5,766 

 

8,358 

Total net natural gas – thousands of cubic feet per day

417,166 

 

397,194 

 

422,827 

 

383,722 

Total net hydrocarbons including NCI 3,4

182,558 

 

164,201 

 

171,804 

 

162,524 

Noncontrolling interest

 

 

 

 

 

 

 

 

Net crude oil and condensate – barrels per day

(3,729)

 

– 

 

(940)

 

– 

Net natural gas liquids – barrels per day

(94)

 

– 

 

(24)

 

– 

Net natural gas – thousands of cubic feet per day

(1,705)

 

– 

 

(430)

 

– 

Total noncontrolling interest

 

(4,107)

 

– 

 

(1,036)

 

– 

Total net hydrocarbons excluding NCI 3,4

178,451 

 

164,201 

 

170,769 

 

162,524 

1 2018 includes net volumes attributable to a noncontrolling interest in MP GOM, a Gulf of Mexico joint venture.

2  The Company sold the Seal area heavy oil field in January 2017.

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

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

















 

21


 



MURPHY OIL CORPORATION

PRICE SUMMARY

(unaudited) 







 

 

 

 

 

 

 

 

 

 



 

 

Three Months Ended

 

 

Year Ended



 

 

December 31,

 

 

December 31,



 

 

2018

 

2017

 

 

2018

 

2017

Weighted average Exploration and Production sales prices

 

 

 

 

 

 

 

 

 

Crude oil and condensate – dollars per barrel

 

 

 

 

 

 

 

 

 

United States 1 

Onshore

$

63.14 

 

55.86 

 

$

67.08 

 

50.49 



Gulf of Mexico 4

 

54.97 

 

54.03 

 

 

62.36 

 

49.24 

Canada 2   

Onshore

 

35.80 

 

52.91 

 

 

50.87 

 

46.68 



Offshore

 

61.12 

 

60.78 

 

 

68.02 

 

53.39 

Malaysia 3

Sarawak

 

51.99 

 

58.76 

 

 

62.38 

 

53.26 



Block K

 

63.06 

 

58.91 

 

 

65.44 

 

52.72 

          Brunei

 

 

68.59 

 

– 

 

 

71.48 

 

– 



 

 

 

 

 

 

 

 

 

 

Natural gas liquids – dollars per barrel

 

 

 

 

 

 

 

 

 

United States

Onshore

$

19.71 

 

22.22 

 

$

22.21 

 

17.70 



Gulf of Mexico 4

 

18.82 

 

24.84 

 

 

24.54 

 

19.57 

Canada 2   

Onshore

 

30.78 

 

29.80 

 

 

37.44 

 

25.00 

Malaysia 3

Sarawak

 

65.34 

 

51.92 

 

 

69.04 

 

51.00 



 

 

 

 

 

 

 

 

 

 

Natural gas – dollars per thousand cubic feet

 

 

 

 

 

 

 

 

 

United States

Onshore

$

3.02 

 

2.36 

 

$

2.44 

 

2.49 



Gulf of Mexico 4

 

3.71 

 

2.31 

 

 

2.77 

 

2.49 

Canada 2 

Onshore

 

1.81 

 

1.90 

 

 

1.52 

 

1.97 

Malaysia 3

Sarawak

 

3.99 

 

3.64 

 

 

3.78 

 

3.55 



Block K

 

0.26 

 

0.23 

 

 

0.24 

 

0.24 

1  In 2018, the Company reported realized and unrealized gains and losses on crude oil contracts in the Corporate segment to reflect how segments are currently evaluated, how resources are allocated and how risk is managed by the Company.  The 2017 amounts have been reclassified from the Exploration and Production business for comparable disclosure.

2 U.S. dollar equivalent.

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

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

22


 













 

 

 

 

 

 

 

 

 

 

 

 

MURPHY OIL CORPORATION

COMMODITY HEDGE POSITIONS (unaudited)

AS OF DECEMBER 31, 2018



 

 

 

 

 

 

 

 

 

 

 

 



 

 

 

 

 

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

 

1/1/2019

 

12/31/2020



 

 

 

 

 

 

 

 

 

 

 

 



 

 

 

 

 

Volumes

 

Price

 

Remaining Period

Area

 

Commodity

 

Type

 

(MMcf/d)

 

(USD/MMBtu)

 

Start Date

 

End Date

Montney

 

Natural Gas

 

Fixed price forward sales  at AECO

 

10 

 

$             4.19

 

1/1/2019

 

3/31/2019

Montney

 

Natural Gas

 

Fixed price forward sales at AECO

 

10 

 

$             3.85

 

1/1/2019

 

3/31/2019

Montney

 

Natural Gas

 

Fixed price forward sales at Dawn

 

10 

 

$             4.20

 

1/1/2019

 

3/31/2019











 

23


 



MURPHY OIL CORPORATION

FIRST QUARTER 2019 GUIDANCE



 

 

 



 

 

 



Liquids

 

Gas



BOPD

 

MCFD

Production – net

 

 

 

     U.S.  – Eagle Ford Shale

34,800 

 

28,800 

              – Gulf of Mexico including NCI 1

65,900 

 

25,100 

              – Gulf of Mexico excluding NCI

52,750 

 

20,000 

     Canada – Tupper Montney

– 

 

220,000 

                  – Kaybob Duvernay and Placid Montney

8,400 

 

34,800 

                  – Offshore

7,650 

 

– 

     Malaysia – Sarawak

11,900 

 

103,700 

                     – Block K / Brunei

16,000 

 

6,700 



 

 

 



 

 

 

            Total net production (BOEPD) - including NCI 1

 

212,000 to 216,000

            Total net production (BOEPD) - excluding NCI

 

198,000 to 202,000



 

 

 

            Total net sales (BOEPD) - including NCI

 

214,000 to 223,000

            Total net sales (BOEPD) - excluding NCI

 

200,000 to 209,000



 

 

 

Realized oil prices (dollars per barrel):

 

 

 

     Malaysia – Sarawak

 

$55.00 

 

                     – Block K

 

$59.00 

 



 

 

 

Realized natural gas price ($ per MCF):

 

 

 

     Malaysia – Sarawak

 

$4.00 

 



 

 

 

Exploration expense ($ millions)

 

$40 

 



 

 

 

1 Includes noncontrolling interest of MP GOM of 13,150 BOPD liquids and 5,100 MCFD gas.



 

 

 

FULL YEAR  2019 GUIDANCE



 

 

 

Total production (BOEPD) - including NCI 2

 

215,000 to 223,000

Total production (BOEPD) - excluding NCI

 

202,000 to 210,000



 

 

 

Capital expenditures ($ billions) – excluding NCI  3

 

$1.25 - $1.45



2 Includes noncontrolling interest of MP GOM of 13,000 BOEPD.

3 Excludes noncontrolling interest of MP GOM of $48 million.





24