8-K Front for 3Q 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): November 7, 2018







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 November 7,  2018, Murphy Oil Corporation issued a news release announcing its financial and operating results for the quarter ended September 30, 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 November 7, 2018.  






 

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





DateNovember 7, 2018










 

Exhibit Index





 

99.1

News release dated November 7, 2018, as issued by Murphy Oil Corporation.




3Q 2018 Earnings Exhibit 991



Exhibit 99.1

MURPHY OIL CORPORATION ANNOUNCES THIRD QUARTER 2018 FINANCIAL AND OPERATING RESULTS

EL DORADO, Arkansas, November 7, 2018 – Murphy Oil Corporation (NYSE: MUR) today announced its financial and operating results for the third quarter ended September 30, 2018, including net income of $94 million, or $0.54 per diluted share. Third quarter highlights and recent announcements include:

Financial highlights for the third quarter include:

·

Generated net income of $94 million, or $0.54 per diluted share

·

Achieved oil price realization of over $69 per barrel, which is the highest quarterly year-to-date realization

·

Realized EBITDA of over $28 per barrel of oil equivalent sold

·

Registered annualized year-to-date EBITDA to average capital employed of 21 percent

·

Returned 12 percent of operating cash flow to shareholders through long-standing dividend

·

Preserved balance sheet strength with approximately 30 percent net debt to total capital employed 

Operating highlights for the third quarter include:

·

Produced 169 thousand barrels of oil equivalent per day, with 58 percent liquids

·

Increased production in the profitable Kaybob Duvernay by over 2.5 times, year-over-year

·

Delineated Samurai-2 sidetrack accumulation and confirmed the presence of high-quality reservoir sands leading to increased discovered resource  

In early October, announced the following:

·

Entered into accretive oil-weighted Gulf of Mexico joint venture with Petrobras

·

Received upgrade to ‘BB+’ with a ‘Stable Outlook’ from Fitch Ratings

·

Amended Credit Agreement with less restrictive covenants

THIRD QUARTER 2018 RESULTS

Murphy recorded net income of $94 million, or $0.54 per diluted share, for the third quarter 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 $61 million, or $0.35 per diluted share. The adjusted income excludes the following after-tax items: an unrealized mark-to-market gain on crude oil derivative contracts of $21 million, proceeds from an Ecuador arbitration settlement of $21 million, a loss on foreign exchange of $18 million and a net gain of $9 million relating to the combination of Brunei working interest income in the Brunei portion of the Gumusut-Kakap Field, partially offset by an incremental redetermination expense related to the Malaysian portion thereof. There is no change to Murphy’s working interest in the quarter in the Gumusut-Kakap Field. The Ecuador arbitration settlement relates to a change in fiscal terms for a block previously owned by the company. Details for third quarter results can be found in the attached schedules.

1


 

Earnings before interest, taxes, depreciation and amortization (EBITDA) totaled $433 million, or $28.23 per barrel of oil equivalent (BOE) sold. Earnings before interest, taxes, depreciation, amortization and exploration expenses (EBITDAX) totaled $455 million, or $29.60 per BOE sold. Details for third quarter EBITDA and EBITDAX reconciliation can be found in the attached schedules.

In the third quarter 2018, the company produced 169 thousand barrels of oil equivalent per day (MBOEPD). Production exceeded the high end of guidance primarily driven by outperformance in the Tupper Montney onshore Canada, outperformance in Sarawak natural gas in Malaysia and higher than forecasted volumes due to a delay to late in the third quarter and extended into the fourth quarter for the scheduled turnaround in the non-operated Hibernia Field offshore Canada.

“Now with three-quarters of the year behind us, we continue to successfully implement our 2018 plan with third quarter production exceeding the high end of our guidance range. We continue to benefit from a diverse, oil-weighted portfolio that generates high cash flow per barrel metrics, driving over a 20 percent return on cash flow to capital employed. Our high price realizations, competitive cash returns, long-standing dividend policy and successful exploration program along with our recently announced accretive Gulf of Mexico joint venture will continue to reward our shareholders over the long-term,” stated Roger W. Jenkins, President and Chief Executive Officer.

FINANCIAL POSITION

As of September 30, 2018, the company had $2.8 billion of outstanding long-term, fixed-rate notes while maintaining $2.0 billion of liquidity. The fixed-rate notes have a weighted average maturity of 8.0 years and a weighted average coupon of 5.5 percent. The next senior note maturity for the company is in 2022. There were no borrowings on the $1.1 billion unsecured senior credit facility at quarter end.

2


 

REGIONAL OPERATIONS SUMMARY                                                        

North American Onshore

The North American onshore business produced over 98 MBOEPD in the third quarter, a 15 percent increase year-over-year.

Eagle Ford Shale  – Production in the quarter averaged 46 MBOEPD, with 88 percent liquids. As planned, the company brought nine operated wells online during the quarter, all in the Catarina area.

Tupper Montney – Natural gas production in the quarter averaged over 240 million cubic feet per day (MMCFD).

Kaybob Duvernay –  During the quarter, the company achieved record production averaging 10 MBOEPD with 61 percent liquids. Murphy has increased production in this profitable play for six consecutive quarters. As planned, the company brought ten operated wells online across the Kaybob Duvernay acreage: a five well pad in Kaybob West, a three well pad in Kaybob North and a two well pad in Kaybob East. All these wells are performing at or above pre-drill estimates with average initial gross production rates over 30 days (IP30 rate) ranging from approximately 725 to over 1,200 barrels of oil equivalent per day (BOEPD). With these wells being brought online, the company has advanced the appraisal of the play, with the exception of the Two Creeks area, which is expected to occur next year.

“As part of our long-term strategy, we plan to continue increasing production, while spending within cash flow, across our North American onshore assets. In the Eagle Ford Shale, we are executing on our field development plan with over 1,800 locations remaining in our undrilled inventory. In the Kaybob Duvernay we are growing production and lowering costs, while adding a deep inventory of future quality locations and in the Tupper Montney, we are consistently achieving all our targets. From a cost perspective, I am especially pleased with the lease operating expense across our North American onshore business in the quarter, of just over $6 per barrel of oil equivalent,” commented Jenkins.

Global Offshore

The offshore business produced over 70 MBOEPD for the third quarter, with 71 percent liquids. 

Malaysia & Brunei – Production in the quarter averaged 47 MBOEPD, with 61 percent liquids. Block K and Sarawak averaged 28 thousand barrels of liquids per day, while Sarawak natural gas production averaged 106 MMCFD. The Kikeh gas lift project was completed, successfully commissioned and tested in the quarter.

North America  Production in the quarter for the Gulf of Mexico and offshore Canada averaged 24 MBOEPD, with 90 percent liquids.

3


 

In the Gulf of Mexico, the company commenced installation of the Dalmatian subsea pump late in the third quarter. Subsequent to quarter end, the installation was completed. Currently, the project is delivering incremental production of 7,000 BOEPD (gross), with rates exceeding 11,000 BOEPD (gross), an increase of 250 percent from prior quarter production.

EXPLORATION 

Gulf of Mexico Exploration – During the third quarter, Murphy continued drilling the Samurai-2 appraisal sidetrack (Green Canyon 476) of the previously announced Samurai-2 discovery well (Green Canyon 432). Total depth was reached in mid-October. The well successfully delineated the Samurai accumulation and confirmed the presence of high-quality reservoir sands and resources on the company’s Green Canyon Block 476. The sands encountered in the sidetrack are equivalent and hydrostatically connected to those announced in the Samurai-2 well. Following the logging of the sidetrack appraisal well, Murphy is increasing the previously announced discovered resource to approximately 90 million barrels of oil equivalent (MMBOE). At this time, Murphy and its partner are evaluating development plans for the Samurai discovery, as well as possible drilling plans for 2019.

Mexico Exploration – During the third quarter, Murphy submitted the drilling permit to the Comisión Nacional de Hidrocarburos (“CNH”) for the Deepwater Block 5 Exploration Plan. Following the CNH approval, the company plans to spud the exploration prospect 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, in the first quarter of 2019. 

SUBSEQUENT TO QUARTER END

On October 10, 2018, Murphy announced it entered into a definitive agreement to form a new joint venture company with Petrobras America Inc. (“PAI”), a subsidiary of Petrobras. The joint venture, which will be owned 80 percent by Murphy and 20 percent by PAI, will be comprised of all Gulf of Mexico producing assets from Murphy and PAI with Murphy overseeing the operations. The transaction has an effective date of October 1, 2018 and is expected to close by year end 2018. Murphy will pay cash consideration of $900 million to PAI, subject to normal closing adjustments. The company currently anticipates accounting for the PAI share of this transaction as a ‘non-controlling interest’ after closing.

In conjunction with the joint venture, the company entered into an amendment of its existing Credit Agreement. In addition to permitting the contribution of assets to the joint venture, the amendment, which will be fully effective upon the closing of the joint venture transaction, removes certain covenants and increases financial flexibility. 

Also, subsequent to quarter end, Fitch Ratings upgraded Murphy’s debt rating to ‘BB+’ from ‘BB’ with a ‘Stable Outlook’.

4


 

“As we anticipated, the announcement of our joint venture formation with Petrobras has been well received. This transaction ties directly to our long-term strategy. The improvement in our bond rating is reflective of our increased high-value oil production growth, accretive cash flow and long-standing, strong balance sheet,” stated Jenkins.

PRODUCTION AND CAPITAL EXPENDITURE GUIDANCE

The company is maintaining full year 2018 production guidance to be in the range of 168,500 to 170,500 BOEPD. In addition, full year capital expenditures are being maintained at $1.18 billion. Production for the fourth quarter 2018 is estimated to be in the range of 167,000 to 169,000 BOEPD. Full year and fourth quarter production, as well as capital expenditures guidance excludes any impact from the previously announced Gulf of Mexico joint venture.

“Several recent events across many of our assets are affecting our fourth quarter production. The Gulf of Mexico was impacted by an active hurricane and tropical storm season early in the quarter. Malaysia was impacted by a series of mechanical issues affecting both operated and non-operated facilities. In offshore Canada, the turnaround in the non-operated Hibernia Field was extended into the fourth quarter. We have rectified these issues and have restored production to expected levels. Lastly, the Eagle Ford Shale is still being negatively impacted by excessive rains causing wide-spread flooding washing out roads to some of our key producing areas,” commented Jenkins. “Looking forward, we are eager to close our cash flow providing Gulf of Mexico transaction before year end, and then early in the new year provide our formal 2019 annual guidance. Directionally, we remain committed to our strategy of delivering free cash flow in addition to covering our dividend while growing oil-weighted production,” Jenkins added.

CONFERENCE CALL AND WEBCAST SCHEDULED FOR NOVEMBER 8, 2018

Murphy will host a conference call to discuss third quarter 2018 financial and operating results on Thursday, November 8, 2018, at 11:00 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 10390401.

FINANCIAL DATA

Summary financial data and operating statistics for third 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 fourth quarter and full year 2018.

5


 

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.

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.

6


 

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







7


 

MURPHY OIL CORPORATION

SUMMARIZED CONSOLIDATED STATEMENTS OF OPERATIONS  (unaudited)

(Thousands of dollars, except per share amounts)







 

 

 

 

 

 

 

 



 

Three Months Ended

 

Nine Months Ended



 

September 30,

 

September 30,



 

2018

 

2017 1

 

2018

 

2017 1



 

 

 

 

 

 

 

 

Revenues

 

 

 

 

 

 

 

 

     Revenue from sales to customers

$

659,806 

 

511,192 

 

1,921,910 

 

1,498,093 

     (Loss) gain on crude contracts

 

(2,223)

 

(13,573)

 

(69,349)

 

50,365 

     Gain on sale of assets and other income

 

17,214 

 

700 

 

26,035 

 

134,780 

Total revenues

 

674,797 

 

498,319 

 

1,878,596 

 

1,683,238 



 

 

 

 

 

 

 

 

Costs and expenses

 

 

 

 

 

 

 

 

     Lease operating expenses

 

133,141 

 

112,751 

 

406,226 

 

346,072 

     Severance and ad valorem taxes

 

15,067 

 

10,816 

 

40,100 

 

32,771 

     Exploration expenses, including undeveloped
      lease amortization

 

21,838 

 

28,492 

 

69,911 

 

77,356 

     Selling and general expenses

 

64,107 

 

51,374 

 

173,324 

 

155,438 

     Depreciation, depletion and amortization

 

241,833 

 

243,636 

 

710,563 

 

714,782 

     Accretion of asset retirement obligations

 

11,099 

 

10,654 

 

32,041 

 

31,638 

     Redetermination expense

 

11,332 

 

 -

 

11,332 

 

 -

     Other expense (benefit)

 

(34,387)

 

2,454 

 

(44,776)

 

10,988 

Total costs and expenses

 

464,030 

 

460,177 

 

1,398,721 

 

1,369,045 

Operating income from continuing operations

 

210,767 

 

38,142 

 

479,875 

 

314,193 



 

 

 

 

 

 

 

 

Other income (loss)

 

 

 

 

 

 

 

 

     Interest and other income (loss)

 

(19,478)

 

(53,019)

 

(19,445)

 

(106,345)

     Interest expense, net

 

(44,492)

 

(48,681)

 

(134,264)

 

(138,423)

Total other loss

 

(63,970)

 

(101,700)

 

(153,709)

 

(244,768)



 

 

 

 

 

 

 

 

Income (loss) from continuing operations before income taxes

 

146,797 

 

(63,558)

 

326,166 

 

69,425 

Income tax expense (benefit)

 

51,038 

 

2,760 

 

15,801 

 

95,602 

Income (loss) from continuing operations

 

95,759 

 

(66,318)

 

310,365 

 

(26,177)

Income (loss) from discontinued operations,
    net of income taxes

 

(1,815)

 

425 

 

(2,650)

 

1,177 



 

 

 

 

 

 

 

 

NET INCOME (LOSS)

$

93,944 

 

(65,893)

 

307,715 

 

(25,000)



 

 

 

 

 

 

 

 

INCOME (LOSS) PER COMMON SHARE – BASIC

 

 

 

 

 

 

 

 

     Continuing operations

$

0.55 

 

(0.38)

 

1.79 

 

(0.15)

     Discontinued operations

 

(0.01)

 

 -

 

(0.01)

 

0.01 

         Net Income (Loss)

$

0.54 

 

(0.38)

 

1.78 

 

(0.14)



 

 

 

 

 

 

 

 

INCOME (LOSS) PER COMMON SHARE – DILUTED

 

 

 

 

 

 

 

 

     Continuing operations

$

0.55 

 

(0.38)

 

1.78 

 

(0.15)

     Discontinued operations

 

(0.01)

 

 -

 

(0.01)

 

0.01 

         Net Income (Loss)

$

0.54 

 

(0.38)

 

1.77 

 

(0.14)



 

 

 

 

 

 

 

 

Cash dividends per Common share

 

0.25 

 

0.25 

 

0.75 

 

0.75 



 

 

 

 

 

 

 

 

Average Common shares outstanding (thousands)

 

 

 

 

 

 

 

 

     Basic

 

173,047 

 

172,573 

 

172,949 

 

172,509 

     Diluted

 

174,175 

 

172,573 

 

174,202 

 

172,509 




1 Reclassified to conform to current presentation.

8


 

MURPHY OIL CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)

(Thousands of dollars)





 

 

 

 

 

 

 

 

 



 

Three Months Ended

 

Nine Months Ended

 



 

September 30,

 

September 30,

 



 

2018

 

2017

 

2018

 

2017

 

Operating Activities

 

 

 

 

 

 

 

 

 

Net income (loss)

$

93,944 

 

(65,893)

 

307,715 

 

(25,000)

 

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

  operations activities:

 

 

 

 

 

 

 

 

 

Loss (Income) from discontinued operations

 

1,815 

 

(425)

 

2,650 

 

(1,177)

 

Depreciation, depletion and amortization

 

241,833 

 

243,636 

 

710,563 

 

714,782 

 

Dry hole costs (credits)

 

4,537 

 

(3,043)

 

4,526 

 

(1,139)

 

Amortization of undeveloped leases

 

8,770 

 

20,553 

 

31,544 

 

40,859 

 

Accretion of asset retirement obligations

 

11,099 

 

10,654 

 

32,041 

 

31,638 

 

Deferred income tax charge (benefit)

 

17,734 

 

(36,697)

 

(138,755)

 

(3,567)

 

Pretax (gain) loss from sale of assets

 

(124)

 

(117)

 

(6)

 

(130,765)

 

Net (increase) decrease in noncash operating working capital

 

(87,990)

 

(41,511)

 

(2,550)

 

1,070 

 

Other operating activities, net

 

80,781 

 

100,179 

 

49,217 

 

192,097 

 

Net cash provided by continuing operations activities

 

372,399 

 

227,336 

 

996,945 

 

818,798 

 



 

 

 

 

 

 

 

 

 

Investing Activities

 

 

 

 

 

 

 

 

 

Property additions and dry hole costs

 

(243,212)

 

(274,763)

 

(858,356)

 

(706,417)

 

Proceeds from sales of property, plant and equipment

 

505 

 

4,843 

 

1,128 

 

69,146 

 

Purchases of investment securities 1

 

– 

 

– 

 

– 

 

(212,661)

 

Proceeds from maturity of investment securities 1

 

– 

 

36,635 

 

– 

 

320,828 

 

Net cash required by investing activities

 

(242,707)

 

(233,285)

 

(857,228)

 

(529,104)

 



 

 

 

 

 

 

 

 

 

Financing Activities

 

 

 

 

 

 

 

 

 

Borrowings of debt, net of issuance costs

 

– 

 

541,772 

 

– 

 

541,772 

 

Repayments of debt

 

– 

 

(550,000)

 

– 

 

(550,000)

 

Capital lease obligation payments

 

(2,516)

 

(2,704)

 

(7,164)

 

(14,687)

 

Withholding tax on stock-based incentive awards

 

– 

 

(70)

 

(6,922)

 

(7,151)

 

Cash dividends paid

 

(43,263)

 

(43,143)

 

(129,780)

 

(129,421)

 

Net cash required by financing activities

 

(45,779)

 

(54,145)

 

(143,866)

 

(159,487)

 



 

 

 

 

 

 

 

 

 

Effect of exchange rate changes on cash and cash equivalents

 

(37,489)

 

(1,186)

 

(13,107)

 

(5,797)

 

Net increase (decrease) in cash and cash equivalents

 

46,424 

 

(61,280)

 

(17,256)

 

124,410 

 

Cash and cash equivalents at beginning of period

 

901,308 

 

1,058,487 

 

964,988 

 

872,797 

 

Cash and cash equivalents at end of period

$

947,732 

 

997,207 

 

947,732 

 

997,207 

 




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

9


 

MURPHY OIL CORPORATION

SCHEDULE OF ADJUSTED INCOME (LOSS)

(unaudited)

(Millions of dollars, except per share amounts)







 

 

 

 

 

 

 

 



 

Three Months Ended

 

Nine Months Ended



 

September 30,

 

September 30,



 

2018

 

2017

 

2018

 

2017

Net income (loss)

$

93.9 

 

(65.9)

 

307.7 

 

(25.0)

Discontinued operations loss (income)

 

1.8 

 

(0.4)

 

2.7 

 

(1.2)

Income from continuing operations

 

95.7 

 

(66.3)

 

310.4 

 

(26.2)

Adjustments:

 

 

 

 

 

 

 

 

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

 

(20.6)

 

11.8 

 

0.8 

 

(28.9)

Foreign exchange losses (gains)

 

17.6 

 

43.9 

 

14.1 

 

86.6 

Impact of tax reform

 

– 

 

– 

 

(120.0)

 

– 

Seal insurance proceeds

 

(7.0)

 

– 

 

(15.2)

 

– 

Ecuador arbitration settlement

 

(20.5)

 

– 

 

(20.5)

 

– 

Brunei working interest income

 

(16.0)

 

– 

 

(16.0)

 

– 

Malaysia/ Brunei unitization/ redetermination expense

 

7.0 

 

– 

 

7.0 

 

– 

Write-off of previously suspended exploration wells

 

4.5 

 

– 

 

4.5 

 

– 

Deferred tax on undistributed foreign earnings

 

– 

 

4.7 

 

– 

 

65.2 

Tax benefits on investments in foreign areas

 

– 

 

– 

 

– 

 

(32.9)

Gain on sale of assets

 

– 

 

– 

 

– 

 

(96.0)

Oil Insurance Limited dividends

 

– 

 

– 

 

– 

 

(2.8)

Total adjustments after taxes

 

(35.0)

 

60.4 

 

(145.3)

 

(8.8)

Adjusted income (loss)

$

60.7 

 

(5.9)

 

165.1 

 

(35.0)



 

 

 

 

 

 

 

 

Adjusted income (loss) per diluted share

$

0.35 

 

(0.03)

 

0.95 

 

(0.20)



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.



Note: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

 

Nine Months Ended



 

September 30, 2018

 

September 30, 2018



 

Pretax

 

Tax

 

Net

 

Pretax

 

Tax

 

Net

Exploration & Production:

 

 

 

 

 

 

 

 

 

 

 

 

  Canada

$

(9.7)

 

2.7 

 

(7.0)

 

(21.0)

 

5.8 

 

(15.2)

  Malaysia

 

11.3 

 

(4.3)

 

7.0 

 

11.3 

 

(4.3)

 

7.0 

  Other International

 

(11.5)

 

 –

 

(11.5)

 

(11.5)

 

 –

 

(11.5)

Total E&P

 

(9.9)

 

(1.6)

 

(11.5)

 

(21.2)

 

1.5 

 

(19.7)

Corporate 1:

 

(34.1)

 

10.6 

 

(23.5)

 

(11.6)

 

(114.0)

 

(125.6)

Total adjustments

$

(44.0)

 

9.0 

 

(35.0)

 

(32.8)

 

(112.5)

 

(145.3)



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.

10


 



MURPHY OIL CORPORATION

SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION

AND AMORTIZATION (EBITDA) AND EXPLORATION EXPENSES (EBITDAX)

(unaudited)

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









 

 

 

 

 

 

 

 



 

Three Months Ended

 

Nine Months Ended



 

September 30,

 

September 30,



 

2018

 

2017

 

2018

 

2017

Net income (loss) (GAAP)

$

93.9 

 

(65.9)

 

307.7 

 

(25.0)

Discontinued operations loss (income)

 

1.8 

 

(0.4)

 

2.7 

 

(1.2)

Income tax expense (benefit)

 

51.0 

 

2.8 

 

15.8 

 

95.6 

Interest expense, net

 

44.5 

 

48.7 

 

134.3 

 

138.4 

Depreciation, depletion and amortization expense

 

241.8 

 

243.6 

 

710.6 

 

714.8 

EBITDA (Non-GAAP)

$

433.0 

 

228.8 

 

1,171.1 

 

922.6 

Foreign exchange losses (gains)

 

17.9 

 

50.3 

 

13.3 

 

99.1 

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

 

(26.0)

 

18.1 

 

1.1 

 

(44.5)

Gain on sale of assets

 

– 

 

– 

 

– 

 

(130.8)

Accretion of asset retirement obligations

 

11.1 

 

10.7 

 

32.0 

 

31.6 

Seal insurance proceeds

 

(9.7)

 

– 

 

(21.0)

 

– 

Ecuador arbitration settlement

 

(26.0)

 

– 

 

(26.0)

 

– 

Brunei working interest income

 

(16.0)

 

– 

 

(16.0)

 

– 

Malaysia/ Brunei unitization/ redetermination expense

 

11.3 

 

– 

 

11.3 

 

– 

Write-off of previously suspended exploration wells

 

4.5 

 

– 

 

4.5 

 

– 

Oil Insurance Limited dividends

 

– 

 

– 

 

– 

 

(4.4)

Adjusted EBITDA (Non-GAAP)

$

400.1 

 

307.9 

 

1,170.3 

 

873.6 



 

 

 

 

 

 

 

 

Memo:

 

 

 

 

 

 

 

 

Adjusted EBITDA (Non-GAAP)

 

400.1 

 

307.9 

 

1,170.3 

 

873.6 

Exploration expense included in Adjusted EBITDA

 

(4.5)

 

– 

 

(4.5)

 

– 

Exploration expenses

 

21.8 

 

28.5 

 

69.9 

 

77.4 

Adjusted EBITDAX (Non-GAAP)

 

417.4 

 

336.4 

 

1,235.7 

 

951.0 



 

 

 

 

 

 

 

 

Total barrels of oil equivalents sold (thousands of barrels)

 

15,336.8 

 

14,879.2 

 

45,912.0 

 

44,215.1 



 

 

 

 

 

 

 

 

EBITDA per barrel of oil equivalents sold

$

28.23 

 

15.38 

 

25.51 

 

20.87 

Adjusted EBITDA per barrel of oil equivalents sold

$

26.09 

 

20.69 

 

25.49 

 

19.76 

Adjusted EBITDAX per barrel of oil equivalents sold

$

27.22 

 

22.61 

 

26.91 

 

21.51 



Non-GAAP Financial Measures

Presented above is a reconciliation of Net income (loss) to Earnings before interest, taxes, depreciation and amortization (EBITDA), adjusted EBITDA, and adjusted earnings before interest, taxes, depreciation, amortization, and exploration expenses (EBITDAX).  Management believes EBITDA, adjusted EBITDA, 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.  EBITDA, adjusted EBITDA, 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 EBITDA per barrel of oil equivalent sold, adjusted EBITDA per barrel of oil equivalent sold, adjusted EBITDAX per barrel of oil equivalents sold. Management believes EBITDA per barrel of oil equivalent sold, adjusted EBITDA per barrel of oil equivalent sold, and adjusted EBITDAX per barrel of oil equivalents 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, adjusted EBITDA per barrel of oil equivalent sold, and adjusted EBITDAX per barrel of oil equivalent sold are non-GAAP financial metrics.

11


 



MURPHY OIL CORPORATION

FUNCTIONAL RESULTS OF OPERATIONS (unaudited)

(Millions of dollars)







 

 

 

 

 

 

 

 

 



Three Months Ended September 30, 2018

 

 

Three Months Ended September 30, 2017



 

Revenues

 

Income
(Loss)

 

 

Revenues

 

Income
(Loss)

Exploration and production

 

 

 

 

 

 

 

 

 

    United States 1

$

348.7 

 

91.6 

 

 

209.4 

 

(11.2)

    Canada

 

107.1 

 

12.5 

 

 

81.9 

 

(3.2)

    Malaysia

 

201.2 

 

54.1 

 

 

220.5 

 

67.7 

    Other

 

19.9 

 

1.3 

 

 

– 

 

(11.0)

        Total exploration and production

 

676.9 

 

159.5 

 

 

511.8 

 

42.3 

Corporate 1

 

(2.1)

 

(63.8)

 

 

(13.5)

 

(108.6)

Revenue/income from continuing operations

 

674.8 

 

95.7 

 

 

498.3 

 

(66.3)

Discontinued operations, net of tax

 

– 

 

(1.8)

 

 

– 

 

0.4 

Total revenues/net income (loss)

$

674.8 

 

93.9 

 

 

498.3 

 

(65.9)



 

 

 

 

 

 

 

 

 



 

 

 

 

 

 

 

 

 



 

 

 

 

 

 

 

 

 



Nine Months Ended September 30, 2018

 

 

Nine Months Ended September 30, 2017



 

Revenues

 

Income
(Loss)

 

 

Revenues

 

Income
(Loss)

Exploration and production

 

 

 

 

 

 

 

 

 

    United States

$

945.6 

 

200.3 

 

 

646.3 

 

(21.8)

    Canada  2

 

333.8 

 

46.7 

 

 

388.1 

 

102.6 

    Malaysia

 

640.7 

 

208.4 

 

 

594.4 

 

173.9 

    Other

 

19.9 

 

(28.8)

 

 

– 

 

(10.9)

        Total exploration and production

 

1,940.0 

 

426.6 

 

 

1,628.8 

 

243.8 

Corporate 3

 

(61.4)

 

(116.2)

 

 

54.4 

 

(270.0)

Revenue/income from continuing operations

 

1,878.6 

 

310.4 

 

 

1,683.2 

 

(26.2)

Discontinued operations, net of tax

 

– 

 

(2.7)

 

 

– 

 

1.2 

Total revenues/net income (loss)

$

1,878.6 

 

307.7 

 

 

1,683.2 

 

(25.0)



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 (losses) of ($2.2) million and ($13.6) million are included in the Corporate segment for the three months ended September 30, 2018 and 2017, respectively. Realized and unrealized gains (losses) of ($69.3) million and $50.4 million are included in the Corporate segment for the nine months ended September 30, 2018 and 2017, respectively. Corporate segment loss for the three-month periods ended September 30, 2018 and 2017 included foreign exchange losses of $16.8 million and $50.3 million, respectively.  Corporate segment loss for the nine-month periods ended September 30, 2018 and 2017 included foreign exchange losses of $14.0 million and $99.1 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 Income for the nine-month period ended September 30, 2018 included a credit to income tax expense of $120.0 million related to an IRS interpretation of the Tax Cuts and Jobs Act.  

12


 

MURPHY OIL CORPORATION
OIL AND GAS OPERATING RESULTS (unaudited)
THREE MONTHS ENDED SEPTEMBER 30,  2018 AND 2017



 

 

 

 

 

 



 

 

 

 

 

 



 

 

 

 

 

 



 

United

 

 

 

 

(Millions of dollars)

 

States 1

Canada

Malaysia

Other

Total

Three Months Ended September 30, 2018

 

 

 

 

 

 

Oil and gas sales and other revenues

$

348.7  107.1  201.2  19.9  676.9 

Lease operating expenses

 

52.0  31.5  49.4  0.2  133.1 

Severance and ad valorem taxes

 

14.8  0.3 

– 

– 

15.1 

Depreciation, depletion and amortization

 

132.6  58.6  44.3  1.0  236.5 

Accretion of asset retirement obligations

 

4.5  1.9  4.7 

– 

11.1 

Redetermination expense

 

– 

– 

11.3 

– 

11.3 

Exploration expenses

 

 

 

 

 

 

    Dry holes

 

– 

– 

– 

4.5  4.5 

    Geological and geophysical

 

0.4 

– 

0.1  0.7  1.2 

    Other exploration

 

1.6  0.2 

– 

5.5  7.3 



 

2.0  0.2  0.1  10.7  13.0 

    Undeveloped lease amortization

 

7.8  0.2 

– 

0.8  8.8 

        Total exploration expenses

 

9.8  0.4  0.1  11.5  21.8 

Selling and general expenses

 

14.0  6.4  3.4  6.2  30.0 

Other

 

4.5  (9.5) 0.6  0.6  (3.8)

Results of operations before taxes

 

116.5  17.5  87.4  0.4  221.8 

Income tax provisions (benefits)

 

24.9  5.0  33.3  (0.9) 62.3 

Results of operations (excluding
  corporate overhead and interest)

$

91.6  12.5  54.1  1.3  159.5 



 

 

 

 

 

 

Three Months Ended September 30, 2017

 

 

 

 

 

 

Oil and gas sales and other revenues

$

209.4  81.9  220.5 

– 

511.8 

Lease operating expenses

 

43.5  28.7  40.6 

– 

112.8 

Severance and ad valorem taxes

 

10.5  0.3 

– 

– 

10.8 

Depreciation, depletion and amortization

 

128.5  45.9  63.7  1.0  239.1 

Accretion of asset retirement obligations

 

4.3  2.0  4.4 

– 

10.7 

Exploration expenses

 

 

 

 

 

 

    Dry holes

 

(0.6)

– 

(2.5)

– 

(3.1)

    Geological and geophysical

 

0.1 

– 

– 

1.5  1.6 

    Other exploration

 

1.5  0.2 

– 

7.7  9.4 



 

1.0  0.2  (2.5) 9.2  7.9 

    Undeveloped lease amortization

 

20.4  0.2 

– 

– 

20.6 

        Total exploration expenses

 

21.4  0.4  (2.5) 9.2  28.5 

Selling and general expenses

 

13.2  7.3  4.6  5.1  30.2 

Other

 

4.2  0.1  1.4 

– 

5.7 

Results of operations before taxes

 

(16.2) (2.8) 108.3  (15.3) 74.0 

Income tax provisions (benefits)

 

(5.0) 0.4  40.6  (4.3) 31.7 

Results of operations (excluding
  corporate overhead and interest)

$

(11.2) (3.2) 67.7  (11.0) 42.3 



13


 

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.

MURPHY OIL CORPORATION

OIL AND GAS OPERATING RESULTS (unaudited)

NINE MONTHS ENDED SEPTEMBER 30,  2018 AND 2017





 

 

 

 

 

 



 

 

 

 

 

 



 

 

 

 

 

 



 

United

 

 

 

 

(Millions of dollars)

 

States 1

Canada 2

Malaysia

Other

Total

Nine Months Ended September 30, 2018

 

 

 

 

 

 

Oil and gas sales and other revenues

$

945.6  333.8  640.7  19.9  1,940.0 

Lease operating expenses

 

162.6  91.0  152.4  0.2  406.2 

Severance and ad valorem taxes

 

39.2  0.9 

– 

– 

40.1 

Depreciation, depletion and amortization

 

382.4  171.1  141.9  2.4  697.8 

Accretion of asset retirement obligations

 

13.4  5.8  12.8 

– 

32.0 

Redetermination expense

 

– 

– 

11.3 

– 

11.3 

Exploration expenses

 

 

 

 

 

 

    Dry holes

 

– 

– 

– 

4.5  4.5 

    Geological and geophysical

 

6.5 

– 

0.6  4.3  11.4 

    Other exploration

 

5.1  0.3 

– 

17.0  22.4 



 

11.6  0.3  0.6  25.8  38.3 

    Undeveloped lease amortization

 

29.2  0.6 

– 

1.7  31.5 

        Total exploration expenses

 

40.8  0.9  0.6  27.5  69.8 

Selling and general expenses

 

39.0  20.7  8.3  18.1  86.1 

Other

 

12.4  (20.9) (0.8) 1.2  (8.1)

Results of operations before taxes

 

255.8  64.3  314.2  (29.5) 604.8 

Income tax provisions (benefits)

 

55.5  17.6  105.8  (0.7) 178.2 

Results of operations (excluding
  corporate overhead and interest)

$

200.3  46.7  208.4  (28.8) 426.6 



 

 

 

 

 

 

Nine Months Ended September 30, 2017

 

 

 

 

 

 

Oil and gas sales and other revenues

$

646.3  388.1  594.4 

– 

1,628.8 

Lease operating expenses

 

135.7  76.8  133.6 

– 

346.1 

Severance and ad valorem taxes

 

31.6  1.2 

– 

– 

32.8 

Depreciation, depletion and amortization

 

402.3  136.6  160.0  2.9  701.8 

Accretion of asset retirement obligations

 

12.8  5.9  12.9 

– 

31.6 

Exploration expenses

 

 

 

 

 

 

    Dry holes

 

(1.9)

– 

0.8 

– 

(1.1)

    Geological and geophysical

 

1.0  0.1 

– 

6.0  7.1 

    Other exploration

 

5.5  0.3 

– 

24.8  30.6 



 

4.6  0.4  0.8  30.8  36.6 

    Undeveloped lease amortization

 

39.4  1.4 

– 

– 

40.8 

        Total exploration expenses

 

44.0  1.8  0.8  30.8  77.4 

Selling and general expenses

 

38.7  20.9  10.2  15.0  84.8 

Other

 

11.5  0.7  9.4 

– 

21.6 

Results of operations before taxes

 

(30.3) 144.2  267.5  (48.7) 332.7 

Income tax provisions (benefits)

 

(8.5) 41.6  93.6  (37.8) 88.9 

Results of operations (excluding
  corporate overhead and interest)

$

(21.8) 102.6  173.9  (10.9) 243.8 



14


 

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

MURPHY OIL CORPORATION

PRODUCTION-RELATED EXPENSES

(unaudited)

(Dollars per barrel of oil equivalents sold)







 

 

 

 

 

 

 

 



Three Months Ended

 

Nine Months Ended



September 30,

 

September 30,



 

2018

 

2017

 

2018

 

2017



 

 

 

 

 

 

 

 

United States – Eagle Ford Shale

 

 

 

 

 

 

 

 

     Lease operating expense

$

8.26 

 

6.93 

 

8.23 

 

7.60 

     Severance and ad valorem taxes

 

3.48 

 

2.56 

 

3.22 

 

2.54 

     Depreciation, depletion and amortization (DD&A) expense

 

24.43 

 

25.42 

 

24.59 

 

25.74 



 

 

 

 

 

 

 

 

United States – Gulf of Mexico

 

 

 

 

 

 

 

 

     Lease operating expense

$

10.29 

 

12.48 

 

12.79 

 

10.61 

     DD&A expense

 

17.57 

 

20.07 

 

17.25 

 

21.13 



 

 

 

 

 

 

 

 

Canada – Onshore

 

 

 

 

 

 

 

 

     Lease operating expense

$

4.33 

 

5.49 

 

4.69 

 

5.11 

     Severance and ad valorem taxes

 

0.07 

 

0.08 

 

0.07 

 

0.11 

     DD&A expense

 

10.69 

 

10.03 

 

10.47 

 

9.97 



 

 

 

 

 

 

 

 

Canada – Offshore

 

 

 

 

 

 

 

 

     Lease operating expense

$

22.42 

 

13.25 

 

13.36 

 

9.76 

     DD&A expense

 

14.76 

 

13.66 

 

13.47 

 

12.96 



 

 

 

 

 

 

 

 

Malaysia – Sarawak

 

 

 

 

 

 

 

 

     Lease operating expense

$

7.29 

 

5.28 

 

8.07 

 

5.49 

     DD&A expense

 

8.19 

 

8.53 

 

8.55 

 

8.09 



 

 

 

 

 

 

 

 

Malaysia – Block K

 

 

 

 

 

 

 

 

     Lease operating expense

$

19.98 

 

10.50 

 

17.77 

 

14.07 

     DD&A expense

 

15.16 

 

16.20 

 

14.72 

 

14.65 



 

 

 

 

 

 

 

 

Total oil and gas operations

 

 

 

 

 

 

 

 

     Lease operating expense

$

8.68 

 

7.58 

 

8.85 

 

7.83 

     Severance and ad valorem taxes

 

0.98 

 

0.73 

 

0.87 

 

0.74 

     DD&A expense

 

15.77 

 

16.07 

 

15.48 

 

15.87 



 

 

 

 

 

 

 

 



15


 

MURPHY OIL CORPORATION

OTHER FINANCIAL DATA

(unaudited)

(Millions of dollars)





 

 

 

 

 

 

 

 

 



 

Three Months Ended

 

Nine Months Ended

 



 

September 30,

 

September 30,

 



 

2018

 

2017

 

2018

 

2017

 

Capital expenditures

 

 

 

 

 

 

 

 

 

     Exploration and production

 

 

 

 

 

 

 

 

 

         United States

$

128.2 

 

204.7 

 

454.6 

 

427.5 

 

         Canada

 

89.0 

 

68.7 

 

291.3 

 

204.6 

 

         Malaysia

 

41.3 

 

(3.4)

 

85.8 

 

7.7 

 

         Other

 

21.2 

 

13.6 

 

38.9 

 

54.9 

 

              Total

 

279.7 

 

283.6 

 

870.6 

 

694.7 

 



 

 

 

 

 

 

 

 

 

     Corporate

 

12.2 

 

3.1 

 

22.4 

 

6.9 

 

              Total capital expenditures

 

291.9 

 

286.7 

 

893.0 

 

701.6 

 



 

 

 

 

 

 

 

 

 

     Charged to exploration expenses 1

 

 

 

 

 

 

 

 

 

         United States

 

2.0 

 

1.0 

 

11.6 

 

4.6 

 

         Canada

 

0.2 

 

0.2 

 

0.3 

 

0.4 

 

         Malaysia

 

0.1 

 

(2.5)

 

0.6 

 

0.8 

 

         Other

 

10.7 

 

9.2 

 

25.8 

 

30.8 

 

              Total charged to exploration expenses

 

13.0 

 

7.9 

 

38.3 

 

36.6 

 



 

 

 

 

 

 

 

 

 

              Total capitalized

$

278.9 

 

278.8 

 

854.7 

 

665.0 

 



 

 

 

 

 

 

 

 

 



1 Excludes amortization of undeveloped leases of $8.8 million and $20.6 million for the three months ended September 30, 2018 and 2017,  
   respectively, and $31.5 million and $40.9 million for the nine months ended September 30, 2018 and 2017, respectively.



 

16


 



 

 

 

 

 



 

 

 

 

 

MURPHY OIL CORPORATION

CONDENSED BALANCE SHEETS (unaudited)

(Millions of dollars)



 

 

 

 

 



 

September 30, 2018

 

 

December 31, 2017

     Assets

 

 

 

 

 

     Cash and cash equivalents

$

947.7 

 

 

965.0 

     Other current assets

 

433.6 

 

 

406.6 

     Property, plant and equipment – net

 

8,244.2 

 

 

8,220.0 

     Other long-term assets

 

401.2 

 

 

269.3 

          Total assets

$

10,026.7 

 

 

9,860.9 



 

 

 

 

 

     Liabilities and Stockholders' Equity

 

 

 

 

 

     Current maturities of long-term debt

$

10.5 

 

 

9.9 

     Other current liabilities

 

865.1 

 

 

824.3 

     Long-term debt 1

 

2,903.9 

 

 

2,906.5 

     Other long-term liabilities

 

1,480.3 

 

 

1,500.0 

     Total stockholders' equity

 

4,766.9 

 

 

4,620.2 

          Total liabilities and stockholders' equity

$

10,026.7 

 

 

9,860.9 



1 Includes a capital lease on production equipment of $128.4 million at September 30, 2018 and $134.0 million at December 31, 2017.



 

17


 

MURPHY OIL CORPORATION

STATISTICAL SUMMARY

(unaudited)







 

 

 

 

 

 

 



Three Months Ended

 

Nine Months Ended



September 30,

 

September 30,



2018

 

2017

 

2018

 

2017

Net crude oil and condensate produced – barrels per day

87,755 

 

84,230 

 

88,781 

 

89,580 

United States – Eagle Ford Shale

33,757 

 

33,070 

 

32,347 

 

33,281 

– Gulf of Mexico

14,530 

 

10,240 

 

14,253 

 

11,309 

Canada    – Onshore

6,096 

 

3,240 

 

5,242 

 

2,729 

– Offshore

5,570 

 

6,225 

 

7,237 

 

8,100 

– Heavy 1

– 

 

– 

 

– 

 

201 

Malaysia – Sarawak

11,608 

 

11,508 

 

11,936 

 

12,727 

– Block K

15,661 

 

19,947 

 

17,200 

 

21,233 

         Brunei

533 

 

– 

 

566 

 

– 



 

 

 

 

 

 

 

Net crude oil and condensate sold – barrels per day

85,598 

 

92,033 

 

87,745 

 

89,597 

United States – Eagle Ford Shale

33,757 

 

33,070 

 

32,347 

 

33,281 

– Gulf of Mexico

14,530 

 

10,240 

 

14,253 

 

11,309 

Canada    – Onshore

6,096 

 

3,240 

 

5,242 

 

2,729 

– Offshore

5,116 

 

6,533 

 

7,197 

 

7,812 

– Heavy 1

– 

 

– 

 

– 

 

201 

Malaysia – Sarawak

9,469 

 

13,083 

 

12,080 

 

13,350 

– Block K

16,169 

 

25,867 

 

16,471 

 

20,915 

         Brunei

461 

 

– 

 

155 

 

– 



 

 

 

 

 

 

 

Net natural gas liquids produced – barrels per day

9,556 

 

9,128 

 

9,525 

 

9,140 

United States – Eagle Ford Shale

6,663 

 

6,669 

 

6,735 

 

6,812 

– Gulf of Mexico

1,109 

 

910 

 

1,112 

 

967 

Canada   – Onshore

1,095 

 

510 

 

1,005 

 

410 

Malaysia – Sarawak

689 

 

1,039 

 

673 

 

951 



 

 

 

 

 

 

 

Net natural gas liquids sold – barrels per day

9,641 

 

9,213 

 

9,642 

 

9,165 

United States – Eagle Ford Shale

6,663 

 

6,669 

 

6,735 

 

6,812 

– Gulf of Mexico

1,109 

 

910 

 

1,112 

 

967 

Canada   – Onshore

1,095 

 

510 

 

1,005 

 

410 

Malaysia – Sarawak

774 

 

1,124 

 

790 

 

976 



 

 

 

 

 

 

 

Net natural gas sold – thousands of cubic feet per day

428,790 

 

362,901 

 

424,733 

 

379,182 

United States – Eagle Ford Shale

32,718 

 

29,476 

 

32,172 

 

32,862 

– Gulf of Mexico

14,798 

 

11,232 

 

13,968 

 

11,654 

Canada   – Onshore

272,061 

 

223,032 

 

266,077 

 

220,121 

Malaysia – Sarawak

106,183 

 

90,181 

 

106,016 

 

106,481 

– Block K

3,030 

 

8,980 

 

6,500 

 

8,064 



 

 

 

 

 

 

 

Total net hydrocarbons produced – equivalent barrels per day 2

168,776 

 

153,842 

 

169,095 

 

161,917 

Total net hydrocarbons sold – equivalent barrels per day 2

166,704 

 

161,730 

 

168,176 

 

161,959 



 

 

 

 

 

 

 



 

 

 

 

 

 

 



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

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



 

18


 

MURPHY OIL CORPORATION

STATISTICAL SUMMARY (Continued)

(unaudited) 







 

 

 

 

 

 

 

 

 



 

Three Months Ended

 

 

Nine Months Ended



 

September 30,

 

 

September 30,



 

2018

 

2017

 

 

2018

 

2017

Weighted average Exploration and Production sales prices

 

 

 

 

 

 

 

 

 

Crude oil and condensate – dollars per barrel

 

 

 

 

 

 

 

 

 

United States 1 – Eagle Ford Shale

$

72.08 

 

48.49 

 

$

68.29 

 

48.42 

    – Gulf of Mexico

 

70.46 

 

47.82 

 

 

67.41 

 

47.48 

Canada 2  – Onshore

 

58.52 

 

43.15 

 

 

57.67 

 

43.64 

 – Offshore

 

73.92 

 

51.26 

 

 

69.94 

 

50.35 

Malaysia – Sarawak 3

 

63.82 

 

52.62 

 

 

66.25 

 

52.07 

 – Block K 3

 

68.67 

 

51.36 

 

 

66.35 

 

50.95 

          Brunei

 

74.37 

 

– 

 

 

74.37 

 

– 



 

 

 

 

 

 

 

 

 

Natural gas liquids – dollars per barrel

 

 

 

 

 

 

 

 

 

United States – Eagle Ford Shale

$

27.65 

 

17.89 

 

$

22.96 

 

16.12 

 – Gulf of Mexico

 

34.49 

 

19.00 

 

 

26.85 

 

17.84 

Canada 2 – Onshore

 

41.06 

 

22.77 

 

 

40.28 

 

22.48 

Malaysia – Sarawak 3

 

69.64 

 

49.66 

 

 

70.26 

 

49.94 



 

 

 

 

 

 

 

 

 

Natural gas – dollars per thousand cubic feet

 

 

 

 

 

 

 

 

 

United States – Eagle Ford Shale

$

2.27 

 

2.44 

 

$

2.26 

 

2.53 

  – Gulf of Mexico

 

2.48 

 

2.49 

 

 

2.40 

 

2.56 

Canada 2 – Onshore

 

1.41 

 

1.84 

 

 

1.42 

 

1.99 

Malaysia – Sarawak 3

 

3.91 

 

3.60 

 

 

3.72 

 

3.50 

  – Block K 3

 

0.24 

 

0.25 

 

 

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.



 

19


 









 

 

 

 

 

 

 

 

 

 

 

 

MURPHY OIL CORPORATION

COMMODITY HEDGE POSITIONS (unaudited)

AS OF SEPTEMBER 30, 2018



 

 

 

 

 

 

 

 

 

 

 

 



 

 

 

 

 

Volumes

 

Price

 

Remaining Period

Area

 

Commodity

 

Type

 

(Bbl/d)

 

(USD/Bbl)

 

Start Date

 

End Date

United States

 

WTI

 

Fixed price derivative swap 1

 

21,000 

 

$54.88 

 

10/1/2018

 

12/31/2018



 

 

 

 

 

 

 

 

 

 

 

 



 

 

 

 

 

Volumes

 

Price

 

Remaining Period

Area

 

Commodity

 

Type

 

(MMcf/d)

 

(Mcf)

 

Start Date

 

End Date

Montney

 

Natural Gas

 

Fixed price forward sales

 

59 

 

C$2.81

 

10/1/2018

 

12/31/2020



 

 

 

 

 

 

 

 

 

 

 

 



 

 

 

 

 

 

 

 

 

 

 

 





1  Realized and unrealized gains and losses on Fixed price derivatives swaps are reported in the Corporate segment to reflect how segments are currently evaluated, how resources are allocated and how risk is managed by the Company.









 

20


 



MURPHY OIL CORPORATION

FOURTH QUARTER 2018 GUIDANCE



 

 

 



 

 

 



Liquids

 

Gas



BOPD

 

MCFD

Production – net

 

 

 

     U.S.  – Eagle Ford Shale

36,000 

 

29,100 

              – Gulf of Mexico

18,500 

 

14,300 



 

 

 

     Canada – Tupper Montney

– 

 

230,400 

                  – Kaybob Duvernay and Placid Montney

8,500 

 

37,600 

                  – Offshore

6,200 

 

– 

     Malaysia – Sarawak

11,900 

 

101,600 

                     – Block K / Brunei

17,000 

 

6,400 



 

 

 



 

 

 

            Total net production (BOEPD)

 

167,000 - 169,000



 

 

 

            Total net sales (BOEPD)

 

173,000 - 175,000



 

 

 

Realized oil prices (dollars per barrel):

 

 

 

     Malaysia – Sarawak

 

$69.50 

 

                     – Block K

 

$76.80 

 



 

 

 

Realized natural gas price ($ per MCF):

 

 

 

     Malaysia – Sarawak

 

$4.00 

 



 

 

 

Exploration expense ($ millions)

 

$42 

 



 

 

 



 

 

 



 

 

 

FULL YEAR  2018 GUIDANCE



 

 

 

Total production (BOEPD)

 

168,500 to 170,500



 

 

 

Capital expenditures ($ billions)

 

$1.18 

 



21