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Murphy Oil Corporation Announces Preliminary First Quarter 2017 Financial and Operating Results

EL DORADO, Ark.--(BUSINESS WIRE)--May 3, 2017-- Murphy Oil Corporation (NYSE: MUR) today announced its preliminary financial and operating results for the first quarter ended March 31, 2017, including net income of $58 million, or $0.34 per diluted share.

Operating and financial highlights for the first quarter 2017 include:

  • Produced volumes of 169 Mboepd, on track to achieve full year production guidance
  • Spent $215 million on capital expenditures, in line with planned annual capital budget of $890 million for full year 2017
  • Reduced selling and general expenses by approximately 17 percent year-over-year, excluding severance expense in the prior year
  • Closed the divestiture of Canadian heavy oil asset generating a $132 million pre-tax gain
  • Executed planned quarterly Kaybob Duvernay appraisal program by drilling five wells, including the longest lateral to date of 9,500 feet, and brought three wells online

FIRST QUARTER 2017 FINANCIAL RESULTS

Murphy recorded net income of $58 million, or $0.34 per diluted share, for the first quarter 2017. The company reported an adjusted loss, which excludes both the results of discontinued operations and certain other items that affect comparability of results between periods, of $10 million, or $0.06 per diluted share. The most significant reconciling items affecting the adjusted loss were a $96 million after-tax gain on the sale of Seal properties in Canada, an after-tax gain of $26 million for mark-to-market of open crude oil hedge contracts and a $55 million deferred tax expense related to undistributed foreign earnings. The tax expense is the result of the company determining that first quarter earnings from its subsidiaries operating in Canada, Malaysia and other Southeast Asia areas will not be considered reinvested into local operations and are expected to be repatriated to the U.S. in future periods. Details for first quarter results can be found in the attached schedules.

Earnings before interest, taxes, depreciation and amortization (EBITDA) from continuing operations totaled $436 million, or $29.52 per barrel of oil equivalent (boe) sold. Earnings before interest, taxes, depreciation, amortization and exploration expenses (EBITDAX) totaled $464 million, or $31.47 per boe sold. Both EBITDA and EBITDAX include a $132 million pre-tax gain on the sale of Seal heavy oil properties. Production in the first quarter 2017 averaged 169 thousand barrels of oil equivalent per day (Mboepd).

“Murphy had strong first quarter results as we exceeded production guidance with high uptime performance across all our assets. Our production is outstanding considering that we brought online fewer wells than planned in our Eagle Ford Shale asset, as our base production and new wells during the quarter both exceeded our expectations. I continue to be pleased with the significant free cash flow generated by our offshore business. We also addressed the tax status regarding future foreign earnings repatriation, which will allow for additional cash management flexibility across our company,” stated Roger W. Jenkins, President and Chief Executive Officer.

FINANCIAL POSITION

As of March 31, 2017, the company had $2.8 billion of outstanding fixed rate notes and $1.1 billion in cash and liquid invested securities. The long term, fixed-rate notes, excluding the current maturity, have a weighted average maturity of 9.8 years and a weighted average coupon of 5.6 percent. There were no borrowings on the senior credit facilities at quarter end.

REGIONAL OPERATIONS SUMMARY

North American Onshore

The North American onshore business produced over 85 Mboepd in the first quarter with 51 percent liquids. First quarter 2017 operating expenses were $6.51 per boe, a 12 percent decrease from full year 2016.

Eagle Ford Shale – Production in the quarter averaged 46 Mboepd, comprised of 88 percent liquids. During the quarter, the company brought 13 wells online utilizing high sand concentration fracs, which were comprised of six Lower Eagle Ford Shale wells, four Upper Eagle Ford Shale wells and three Austin Chalk wells. The six Lower Eagle Ford Shale wells achieved an average IP 30-day rate over 1,300 barrels of oil equivalent per day (boepd), the four Upper Eagle Ford Shale wells achieved an average IP 30-day rate over 1,200 boepd and two wells on the same pad in the Austin Chalk achieved an average IP 30-day rate over 1,100 boepd. For the remainder of 2017, the company expects to bring almost 60 wells online, of which 19 will be in the second quarter, with full year production averaging approximately 50 Mboepd.

Tupper Montney – Murphy averaged 207 million cubic feet per day (Mmcfd) of natural gas production in the quarter. There was one well drilled in the first quarter and four wells previously drilled that were completed early in the second quarter. Strong production results from these wells, in addition to wells completed in 2016, are yielding projected ultimate recoveries exceeding 17 billion cubic feet equivalent (Bcfe) per well. This exceeds the previously projected recovery range of 10 to 14 Bcfe per well. The exceptional well results continue to support the company’s new well designs of longer laterals that are approaching 10,000 feet, as well as higher sand concentration of up to 2,000 pounds per foot.

Kaybob Duvernay – Production for the quarter averaged almost 3 Mboepd, comprised of 53 percent liquids. During the quarter, five wells were drilled and three wells brought online including a two well pad in the condensate window and a one well pad in the oil window. All three wells are performing above or in line with pre-drill expectations. As the company continues executing on its appraisal plans in the second quarter, for the first-time Murphy is beginning to drill wells with optimal azimuth and lateral lengths exceeding 9,100 feet. For the remainder of 2017, the company expects to drill and bring online 11 wells, including five in the second quarter, two located in the oil window and three in the condensate window.

Offshore

The offshore business produced 84 Mboepd for the first quarter with 73 percent liquids.

Malaysia – Block K and Sarawak averaged 38 thousand barrels of liquids per day, while Sarawak natural gas production averaged 117 Mmcfd during the first quarter.

North America Gulf of Mexico and East Coast Canada averaged 25 Mboepd, comprised of 92 percent liquids, in the quarter.

PRODUCTION AND CAPITAL EXPENDITURE GUIDANCE

Production for the second quarter 2017 is estimated in the range of 160 to 164 Mboepd. Second quarter guidance includes the previously announced redetermination in the non-operated Kakap field, which reduces the company’s net production by approximately 2,900 boepd from the first quarter 2017. Also, in accordance with the Production Sharing Contracts in Malaysia, there is a planned cost recovery entitlement change for Sarawak natural gas and oil that will lower production by approximately 1,500 boepd in the second quarter as compared to the first quarter 2017. Other items affecting second quarter production, as compared to first quarter production, are planned downtime for Kikeh and Siakap North of 1,400 boepd as well as a 10-day plant turnaround in the Tupper Montney of 2,200 boepd.

Full year 2017 production is being reaffirmed in the range of 162 to 168 Mboepd. Full year capital expenditure guidance is being maintained at $890 million. Details for production can be found in the attached schedules.

“As we progress through the second quarter, we are experiencing a previously announced redetermination and an anticipated entitlement change associated with our Malaysian offshore business. Also in the second quarter, we will experience offshore planned maintenance and a brief shut-in at our Tupper Montney asset associated with a plant turnaround. Our full year production remains within the previously announced guidance range. Our base production in the Eagle Ford Shale continues to outperform expectations and, with a majority of this year’s wells being brought online in the second and third quarters, this will lead to a mid-year production increase. In our new Kaybob Duvernay asset, we are pleased with early results as our team systematically de-risks the play with five wells to be placed online in the second quarter,” Jenkins added.

CONFERENCE CALL AND WEBCAST SCHEDULED FOR MAY 3, 2017

Murphy will host a conference call to discuss first quarter 2017 financial and operating results on Thursday, May 4, 2017, at 11:00 a.m. EDT. 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 1-877-795-3649. The telephone reservation number for the call is 7717232. Replays of the call will be available through the same address on the company’s website and a recording of the call will be available through May 18, 2017 by calling 1-888-203-1112 and referencing reservation number 7717232. A replay of the conference call will also be available on the Murphy website at http://ir.murphyoilcorp.com.

FINANCIAL DATA

Summary financial data, operating statistics and a summary balance sheet for the first quarter 2017 with comparisons to the same period from the previous year are contained in the following schedules. Additionally, a schedule indicating the impacts of items affecting comparability of results between periods and schedules comparing EBITDA and EBITDAX between periods are included with these schedules as well as guidance for the second quarter.

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 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.

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.

RESERVE REPORTING TO THE SECURITIES 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 news release, such as “resource”, “gross resource”, “recoverable resource”, “net risked PMEAN 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. The SEC permits the optional disclosure of probable and possible reserves; however, we have not disclosed the company’s probable and possible reserves in our 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.

     

MURPHY OIL CORPORATION

SUMMARIZED CONSOLIDATED STATEMENTS OF INCOME (Unaudited)

(Thousands of dollars, except per share amounts)

 
Three Months Ended
  March 31,
  2017 2016
 
Revenues
Sales and other operating revenues $ 544,658

429,094

Gain on sale of assets 131,982 22
Interest and other income (loss)   (12,021 )

1,179

 
Total revenues   664,619   430,295  
 
Costs and expenses
Lease operating expenses 122,142 159,103
Severance and ad valorem taxes 11,213 12,637
Exploration expenses 28,663 26,916
Selling and general expenses 54,255 73,507
Depreciation, depletion and amortization 236,154 286,149
Accretion of asset retirement obligations 10,556 12,125
Impairment of assets 95,088
Interest expense 45,690 32,061
Interest capitalized (1,093 ) (1,841 )
Other expense (benefit)   2,157   (416 )
  509,737   695,329  
 
Income (loss) from continuing operations before income taxes 154,882 (265,034 )
Income tax expense (benefit)   97,387   (65,549 )
Income (loss) from continuing operations 57,495 (199,485 )
Income from discontinued operations, net of income taxes   969   683  
 
Net income (loss) $ 58,464   (198,802 )
 
Income (loss) per Common share – Basic
Continuing operations $ 0.33 (1.16 )
Discontinued operations   0.01    
Net income (loss) $ 0.34   (1.16 )
 
Income (loss) per Common share – Diluted
Continuing operations $ 0.33 (1.16 )
Discontinued operations   0.01    
Net income (loss) $ 0.34   (1.16 )
 
Cash dividends per Common share 0.25 0.35
 
Average Common shares outstanding (thousands)
Basic 172,422 172,114
Diluted 173,089 172,114
     

MURPHY OIL CORPORATION

CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited)

(Thousands of dollars)

 
Three Months Ended
  March 31,
  2017 2016
Operating Activities
Net income (loss) $ 58,464 (198,802 )

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

Income from discontinued operations (969 ) (683 )
Depreciation, depletion and amortization 236,154 286,149
Impairment of assets 95,088
Amortization of deferred major repair costs 2,002
Dry hole costs 2,904 (69 )
Amortization of undeveloped leases 9,957 10,469
Accretion of asset retirement obligations 10,556 12,125
Deferred income tax expense (benefit)

58,533

(85,683 )
Pretax gains from disposition of assets (131,982 ) (22 )

Net (increase) decrease in noncash operating working capital1

43,418

(104,347 )
Other operating activities, net   18,478   27,085  
Net cash provided by continuing operations activities   305,513   43,312  
 
Investing Activities
Property additions and dry hole costs (211,631 ) (210,029 )
Proceeds from sales of property, plant and equipment 64,097 33
Purchases of investment securities2 (212,661 ) (49,277 )
Proceeds from maturity of investment securities2 113,210 86,983
Other investing activities, net     (21,658 )
Net cash required by investing activities   (246,985 ) (193,948 )
 
Financing Activities
Borrowings of debt 371,000
Capital lease obligation payments (9,660 ) (2,690 )
Withholding tax on stock-based incentive awards (5,808 ) (1,052 )
Cash dividends paid   (43,136 ) (60,267 )
Net cash (required) provided by financing activities   (58,604 ) 306,991  
 
Cash Flows from Discontinued Operations
Operating activities 2,312
Investing activities
Changes in cash included in current assets held for sale     (2,312 )
Net change in cash and cash equivalents of discontinued operations      
Effect of exchange rate changes on cash and cash equivalents   3,132   (16,475 )
 
Net increase in cash and cash equivalents 3,056 139,880
Cash and cash equivalents at beginning of period   872,797   283,183  
Cash and cash equivalents at end of period $ 875,853   423,063  
 
1 2016 balance includes payments for deepwater rig contract exit of $253.2 million.
2 Investments are Canadian government securities with maturities greater than 90 days at the date of acquisition.
     

MURPHY OIL CORPORATION

SCHEDULE OF ADJUSTED LOSS

(Unaudited)

(Millions of dollars, except per share amounts)

 
Three Months Ended
March 31,
  2017 2016
Net income (loss) $ 58.5 (198.8 )
Discontinued operation earnings

(1.0

)

(0.7

)

Income (loss) from continuing operations 57.5 (199.5 )
Adjustments:
Mark-to-market (gain) loss on crude oil derivative contracts (26.0 ) 13.3
Foreign exchange (gains) losses 11.6 (1.7 )
Gain on sale of Seal (96.0 )
Deferred tax on undistributed foreign earnings 54.6
Tax benefits on investments in foreign areas (11.9 )
Impairments of assets 68.9
Restructuring charges     6.2  
Total adjustments after taxes   (67.7 ) 86.7  
Adjusted loss   (10.2 ) (112.8 )
 
Adjusted loss per diluted share $ (0.06 ) (0.66 )
 

Non-GAAP Financial Measures

Presented above is a reconciliation of Net income (loss) to Adjusted loss. Adjusted 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 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 loss are presented net of applicable income taxes based on the statutory rate applicable by jurisdiction. The 2017 and 2016 pretax and income tax impacts for adjustments shown above are as follows by area of operations.

                         
Three Months Ended Three Months Ended
March 31, 2017 March 31, 2016
Pretax Tax Net Pretax Tax Net
Exploration & Production:
United States (40.0 ) 14.0 (26.0 ) 23.9 (8.4 ) 15.5
Canada (132.4 ) 36.4 (96.0 ) 96.4 (26.5 ) 69.9
Malaysia 1.5 (0.5 ) 1.0
Other International   (11.9 ) (11.9 ) 2.2 (0.6 ) 1.6  
Total E&P (172.4 ) 38.5 (133.9 ) 124.0 (36.0 ) 88.0
Corporate: 13.2   53.0   66.2   0.6 (1.9 ) (1.3 )
Total adjustments (159.2 ) 91.5   (67.7 ) 124.6 (37.9 ) 86.7  
 

Income taxes are presented based on the estimated statutory tax effect each adjustment item had on taxes in the applicable tax jurisdiction.

 
MURPHY OIL CORPORATION
SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION
AND AMORTIZATION (EBITDA)
(Unaudited)
(Millions of dollars, except per barrel of oil equivalents sold)
   
Three Months Ended
March 31,
2017 2016
Income (loss) from continuing operations $ 57.5 (199.5 )
Income tax expense (benefit) 97.4 (65.5 )
Interest expense 45.7 32.1
Interest capitalized (1.1 ) (1.8 )
Depreciation, depletion and amortization expense 236.2 286.1
Impairments of long-lived assets     95.1  

Earnings before interest, taxes, depreciation and amortization (EBITDA)

$ 435.7   * 146.5  
 
Total barrels of oil equivalents sold (thousands of barrels)   14,757.5   17,546.2  
 
EBITDA per barrel of oil equivalents sold $ 29.52   8.35  
 

Non-GAAP Financial Measures

Presented above is a reconciliation of Income (loss) from continuing operations to Earnings before interest, taxes, depreciation and amortization (EBITDA). Management believes EBITDA 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. EBITDA is a non-GAAP financial measure 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.

* Includes $132.4 million pre-tax gain on sale of Seal properties in Canada in January 2017.

   

MURPHY OIL CORPORATION

SCHEDULE OF EARNINGS BEFORE INTEREST, TAXES, DEPRECIATION,

AMORTIZATION AND EXPLORATION (EBITDAX)

(Unaudited)

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

 
Three Months Ended
March 31,
2017 2016
Income (loss) from continuing operations $ 57.5 (199.5 )
Income tax expense (benefit) 97.4 (65.5 )
Interest expense 45.7 32.1
Interest capitalized (1.1 ) (1.8 )
Depreciation, depletion and amortization expense 236.2 286.1
Exploration expenses 28.7 26.9
Impairment of long-lived assets     95.1  

Earnings before interest, taxes, depreciation, amortization and exploration expenses (EBITDAX)

$ 464.4   * 173.4  
 
Total barrels of oil equivalents sold (thousands of barrels)   14,757.5   17,546.2  
 
EBITDAX per barrel of oil equivalents sold $ 31.47   9.88  
 

Non-GAAP Financial Measures

Presented above is a reconciliation of Income (loss) from continuing operations to Earnings before interest, taxes, depreciation, amortization and exploration (EBITDAX). Management believes EBITDAX 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. EBITDAX is a non-GAAP financial measure 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.

* Includes $132.4 million pre-tax gain on sale of Seal properties in Canada in January 2017.

           

MURPHY OIL CORPORATION

FUNCTIONAL RESULTS OF OPERATIONS (Unaudited)

(Millions of dollars)

                       
     

Three Months Ended
March 31, 2017

   

Three Months Ended
March 31, 2016

        Revenues  

Income
(Loss)

    Revenues   Income
(Loss)
Exploration and production
United States $ 261.3 23.0 174.7 (65.6 )
Canada 218.0 100.6 106.1 (87.3 )
Malaysia 197.3 58.6 148.2 22.3
Other           (7.1 )     0.1   (26.2 )
Total exploration and production 676.6 175.1 429.1 (156.8 )
Corporate and other       (12.0 )   (117.6 )     1.2   (42.7 )
Revenue/income from continuing operations 664.6 57.5 430.3 (199.5 )
Discontinued operations, net of tax           1.0         0.7  
Total revenues/net income (loss)     $ 664.6     58.5       430.3   (198.8 )
                       

MURPHY OIL CORPORATION

OIL AND GAS OPERATING RESULTS (Unaudited)

THREE MONTHS ENDED MARCH 31, 2017 AND 2016

                                       
Canada
United Conven- Syn-
(Millions of dollars)       States     tional     thetic     Malaysia     Other     Total
Three Months Ended March 31, 2017                                      
Oil and gas sales and other revenues $ 261.3 218.0 197.3 676.6
Lease operating expenses 48.0 22.6 51.5 122.1
Severance and ad valorem taxes 10.7 0.5 11.2
Depreciation, depletion and amortization 138.3 44.7 47.9 1.0 231.9
Accretion of asset retirement obligations 4.2 2.0 4.4 10.6
Exploration expenses
Dry holes (0.3 ) 3.2 2.9
Geological and geophysical 0.3 0.1 4.4 4.8
Other       2.0       0.1                   8.9       11.0  
2.0 0.2 3.2 13.3 18.7
Undeveloped lease amortization       8.9       1.1                         10.0  
Total exploration expenses       10.9       1.3             3.2       13.3       28.7  
Selling and general expenses 15.5 7.2 2.3 4.9 29.9
Other expenses (benefits)       (3.0 )                 5.1             2.1  
Results of operations before taxes 36.7 139.7 82.9 (19.2 ) 240.1
Income tax provisions (benefits)       13.7       39.1             24.3       (12.1 )     65.0  
Results of operations (excluding
corporate overhead and interest)     $ 23.0       100.6             58.6       (7.1 )     175.1  
                                       
Three Months Ended March 31, 2016                                      
Oil and gas sales and other revenues $ 174.7 57.6 48.5 148.2 0.1 429.1
Lease operating expenses 55.5 17.6 38.1 47.9 159.1
Severance and ad valorem taxes 10.4 1.1 1.1 12.6
Depreciation, depletion and amortization 168.8 45.0 13.4 54.1 1.4 282.7
Accretion of asset retirement obligations 4.2 2.6 1.2 4.1 12.1
Impairment of assets 95.1 95.1
Exploration expenses
Dry holes 0.3 (0.4 ) (0.1 )
Geological and geophysical 0.3 2.9 0.3 4.3 7.8
Other       1.1       0.3                   7.3       8.7  
1.7 3.2 (0.1 ) 11.6 16.4
Undeveloped lease amortization       8.9       1.3                   0.3       10.5  
Total exploration expenses       10.6       4.5             (0.1 )     11.9       26.9  
Selling and general expenses 22.5 7.6 0.2 3.4 10.1 43.8
Other expenses (benefits)       0.2       (1.5 )                 1.0       (0.3 )
Results of operations before taxes (97.5 ) (114.4 ) (5.5 ) 38.8 (24.3 ) (202.9 )
Income tax provisions (benefits)       (31.9 )     (31.0 )     (1.6 )     16.5       1.9       (46.1 )
Results of operations (excluding
corporate overhead and interest)     $ (65.6 )     (83.4 )     (3.9 )     22.3       (26.2 )     (156.8 )
 

MURPHY OIL CORPORATION

PRODUCTION-RELATED EXPENSES

(Dollars per barrel of oil equivalents sold)

         
Three Months Ended
March 31,
2017 2016
 
United States – Eagle Ford Shale
Lease operating expense $ 7.90 7.92
Severance and ad valorem taxes 2.57 2.02
Depreciation, depletion and amortization (DD&A) expense 26.33 24.82
 
United States – Gulf of Mexico
Lease operating expense $ 10.86 8.58
DD&A expense 20.69 23.56
 
Canada – Conventional operations
Lease operating expense $ 5.36 4.07
Severance and ad valorem taxes 0.13 0.24
DD&A expense 10.59 10.32
 
Canada – Synthetic oil operations*
Lease operating expense $ 26.90
Severance and ad valorem taxes 0.86
DD&A expense 9.49
 
Malaysia – Sarawak

 

Lease operating expense

$

6.31 7.81
DD&A expense 7.78 9.68
 
Malaysia – Block K
Lease operating expense $ 16.78 12.40
DD&A expense 12.54 12.49
 
Total oil and gas operations
Lease operating expense $ 8.28 9.07
Severance and ad valorem taxes 0.76 0.72
DD&A expense 15.71 16.11
 
Total oil and gas operations – excluding synthetic oil operations
Lease operating expense $ 8.28 7.50
Severance and ad valorem taxes 0.76 0.71
DD&A expense 15.71 16.69
 

* The Company sold its 5% non-operated interest in Syncrude Canada Ltd. on June 23, 2016.

         

MURPHY OIL CORPORATION

OTHER FINANCIAL DATA

(Unaudited)

(Millions of dollars)

 
Three Months Ended
March 31,
2017 2016
Capital expenditures
Exploration and production
United States $ 98.4 65.6
Canada 88.2 32.5
Malaysia 1.7 27.6
Other   25.3 10.8  
Total   213.6 136.5  
 
Corporate   0.9 8.4  
Total capital expenditures   214.5 144.9  
 
Charged to exploration expenses1
United States 2.0 1.7
Canada 0.2 3.2
Malaysia 3.2 (0.1 )
Other   13.3 11.6  
Total charged to exploration expenses   18.7 16.4  
 
Total capitalized $ 195.8 128.5  
 
1 Excludes amortization of undeveloped leases of $ 10.0 10.5  
         
MURPHY OIL CORPORATION
CONDENSED BALANCE SHEET (Unaudited)
(Millions of dollars)
 
March 31,
2017
December 31,
2016
 

Assets

Cash and cash equivalents $ 875.9 872.8
Canadian government securities 211.5 111.5
Other current assets 522.5 574.8
Property, plant and equipment – net 8,253.1 8,316.2
Other long-term assets

409.0

420.6
Total assets $

10,272.0

10,295.9
 

Liabilities and Stockholders' Equity

Current maturities of long-term debt $ 562.4 569.8
Other current liabilities

906.3

932.6
Long-term debt* 2,421.6 2,422.8
Other long-term liabilities 1,423.2 1,454.0
Total stockholders' equity 4,958.5 4,916.7
Total liabilities and stockholders' equity $

10,272.0

10,295.9
 
* Includes a capital lease on production equipment of $193.5 million at March 31, 2017 and $195.8 million at December 31, 2016.
         

MURPHY OIL CORPORATION

STATISTICAL SUMMARY

 
Three Months Ended
March 31,
2017 2016
Net crude oil and condensate produced – barrels per day 95,604 123,475
United States – Eagle Ford Shale 33,603 42,538
– Gulf of Mexico 12,364 14,098
Canada – light 1,882 131
– heavy1 610 3,319
– offshore 9,916 8,821
– synthetic1 15,559
Malaysia – Sarawak 13,518 13,035
– Block K 23,712 25,974
 
Net crude oil and condensate sold – barrels per day 89,887 119,195
United States – Eagle Ford Shale 33,603 42,537
– Gulf of Mexico 12,364 14,098
Canada – light 1,882 131
– heavy1 610 3,319
– offshore 7,982 9,382
– synthetic1 15,559
Malaysia – Sarawak 13,476 13,759
– Block K 19,970 20,410
 
Net natural gas liquids produced – barrels per day 8,916 9,235
United States – Eagle Ford Shale 6,848 7,225
– Gulf of Mexico 1,113 1,227
Canada 260 12
Malaysia – Sarawak 695 771
 
Net natural gas liquids sold – barrels per day 9,382 9,762
United States – Eagle Ford Shale 6,848 7,225
– Gulf of Mexico 1,113 1,227
Canada 260 12
Malaysia – Sarawak 1,160 1,298
 
Net natural gas sold – thousands of cubic feet per day 388,224 383,150
United States – Eagle Ford Shale 34,328 38,294
– Gulf of Mexico 12,115 23,409
Canada 217,095 209,823
Malaysia – Sarawak 116,560 98,255
– Block K 8,125 13,369
 
Total net hydrocarbons produced – equivalent barrels per day2 169,224 196,568
Total net hydrocarbons sold – equivalent barrels per day2 163,972 192,815
 
1 The Company sold the Seal area heavy oil field in January 2017 and its 5% non-operated interest in Syncrude Canada Ltd. in June 2016.
2 Natural gas converted on an energy equivalent basis of 6:1.
 

MURPHY OIL CORPORATION

STATISTICAL SUMMARY (Continued)

       
Three Months Ended
March 31,
2017 2016
Weighted average sales prices
Crude oil and condensate – dollars per barrel
United States – Eagle Ford Shale $ 48.65 $ 34.81

– Gulf of Mexico

47.24 35.18
Canada1 – light 47.16 30.28
– heavy2 25.12 6.89
– offshore 51.92 30.70
– synthetic2 33.81
Malaysia – Sarawak3 55.01 37.89
– Block K3 51.33 36.03
 
Natural gas liquids – dollars per barrel
United States – Eagle Ford Shale $ 16.45 $ 8.20
– Gulf of Mexico 19.24 9.31
Canada1 22.09 28.63
Malaysia – Sarawak3 47.52 41.21
 
Natural gas – dollars per thousand cubic feet
United States – Eagle Ford Shale $ 2.54 $ 1.47
– Gulf of Mexico 2.56

1.74

Canada1 2.09 1.55
Malaysia – Sarawak3 3.50 3.67
– Block K3 0.25 0.24
 
1   U.S. dollar equivalent.
2 The Company sold the Seal area heavy oil field in January 2017 and its 5% non-operated interest in Syncrude Canada Ltd. in June 2016.
3 Prices are net of payments under the terms of the respective production sharing contracts.
 

MURPHY OIL CORPORATION

COMMODITY HEDGE POSITIONS

AS OF MARCH 31, 2017

       

 

               
Volumes Price Remaining Period
Area Commodity Type (Bbl/d) (USD/Bbl) Start Date End Date
United States WTI Fixed price derivative swap 22,000 $ 50.41 4/1/2017 12/31/2017
 
Volumes Price Remaining Period
Area Commodity Type (MMcf/d) (CAD/Mcf) Start Date End Date
Montney Natural Gas Fixed price forward sales 124 C$2.97 4/1/2017 12/31/2017
Montney Natural Gas Fixed price forward sales 59 C$2.81 1/1/2018 12/31/2020
 

MURPHY OIL CORPORATION

SECOND QUARTER 2017 GUIDANCE

   
Liquids Gas
BOPD MCFD
Production – net
U.S. – Eagle Ford Shale 41,500 32,000
– Gulf of Mexico 12,000 11,000
 
Canada – Tupper Montney 200,000
– Kaybob Duvernay and Placid Montney 4,000 16,500
– Offshore 9,000

-

Malaysia – Sarawak 13,000 109,000
– Block K 20,000 6,500
 
 
Total net production (BOEPD) 160,000 – 164,000
 
Total net sales (BOEPD) 156,000 – 160,000
 
Realized oil prices ($ per barrel):
Malaysia – Sarawak $ 52.78
– Block K $ 50.88
 
Realized natural gas price ($ per MCF):
Malaysia – Sarawak $ 3.75
 
Exploration expense ($ millions) $ 50.2
 
 
FULL YEAR 2017 GUIDANCE
 
Total production (BOEPD) 162,000 – 168,000
 
Capital expenditures ($ millions) $ 890.0

Source: Murphy Oil Corporation

Murphy Oil Corporation
Investor Contacts:
Kelly Whitley, 281-675-9107
kelly_whitley@murphyoilcorp.com
or
Emily McElroy, 870-864-6324
emily_mcelroy@murphyoilcorp.com

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