Prepared by R.R. Donnelley Financial -- Form 10-Q
 
UNITED STATES
SECURITIES AND EXCHANGE COMMISSION
Washington, D.C. 20549
 

 
FORM 10-Q
 
(Mark one)
x
 
QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the quarterly period ended June 30, 2002
 
OR
 
¨
 
TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934
 
For the transition period from                           to                                 
 
Commission File Number 1-8590
 

 
MURPHY OIL CORPORATION
(Exact name of registrant as specified in its charter)
 
Delaware
(State or other jurisdiction of
incorporation or organization)
 
71-0361522
(I.R.S. Employer
Identification Number)
 
200 Peach Street
P. O. Box 7000, El Dorado, Arkansas
(Address of principal executive offices)
 
71731-7000
(Zip Code)
 
(870) 862-6411
(Registrant’s telephone number, including area code)
 

 
Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.  þ  Yes  ¨  No
 
Number of shares of Common Stock, $1.00 par value, outstanding at June 30, 2002, was 45,816,063.
 


PART I—FINANCIAL INFORMATION
 
ITEM 1.    FINANCIAL STATEMENTS
 
MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONSOLIDATED BALANCE SHEETS
(Thousands of dollars)
 
    
(Unaudited)
        
    
June 30,
2002

    
December 31,
2001

 
ASSETS
               
Current Assets
               
Cash and cash equivalents
  
$
140,986
 
  
82,652
 
Accounts receivable, less allowance for doubtful accounts of $11,487 in 2002 and $11,263 in 2001
  
 
383,660
 
  
262,022
 
Inventories
               
Crude oil and blend stocks
  
 
96,923
 
  
38,917
 
Finished products
  
 
100,466
 
  
85,133
 
Materials and supplies
  
 
60,061
 
  
49,098
 
Prepaid expenses
  
 
76,443
 
  
61,062
 
Deferred income taxes
  
 
20,466
 
  
19,777
 
    


  

Total current assets
  
 
879,005
 
  
598,661
 
Property, plant and equipment, at cost less accumulated depreciation and amortization of $3,425,548 in 2002 and $3,277,673 in 2001
  
 
2,754,150
 
  
2,525,807
 
Goodwill, net
  
 
52,908
 
  
50,412
 
Deferred charges and other assets
  
 
92,493
 
  
84,219
 
    


  

Total assets
  
$
3,778,556
 
  
3,259,099
 
    


  

LIABILITIES AND STOCKHOLDERS’ EQUITY
               
Current liabilities
               
Current maturities of long-term debt
  
$
50,441
 
  
48,250
 
Accounts payable and accrued liabilities
  
 
584,799
 
  
463,429
 
Income taxes
  
 
52,656
 
  
48,378
 
    


  

Total current liabilities
  
 
687,896
 
  
560,057
 
Notes payable
  
 
712,845
 
  
416,061
 
Nonrecourse debt of a subsidiary
  
 
92,456
 
  
104,724
 
Deferred income taxes
  
 
329,432
 
  
302,868
 
Accrued dismantlement costs
  
 
169,569
 
  
160,764
 
Accrued major repair costs
  
 
46,416
 
  
44,570
 
Deferred credits and other liabilities
  
 
168,504
 
  
171,892
 
Stockholders’ equity
               
Cumulative Preferred Stock, par $100, authorized 400,000 shares, none issued
  
 
—  
 
  
—  
 
Common stock, par $1.00, authorized 200,000,000 shares, issued 48,775,314 shares
  
 
48,775
 
  
48,775
 
Capital in excess of par value
  
 
547,098
 
  
527,126
 
Retained earnings
  
 
1,078,797
 
  
1,096,567
 
Accumulated other comprehensive loss
  
 
(25,649
)
  
(83,309
)
Unamortized restricted stock awards
  
 
(231
)
  
(968
)
Treasury stock, 2,959,251 shares of Common Stock in 2002, 3,444,234 shares in 2001, at cost
  
 
(77,352
)
  
(90,028
)
    


  

Total stockholders’ equity
  
 
1,571,438
 
  
1,498,163
 
    


  

Total liabilities and stockholders’ equity
  
$
3,778,556
 
  
3,259,099
 
    


  

 
See Notes to Consolidated Financial Statements, page 5.
 
The Exhibit Index is on page 20.

1


 
MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONSOLIDATED STATEMENTS OF INCOME (unaudited)
(Thousands of dollars, except per share amounts)
 
    
Three Months Ended
June 30,

    
Six Months Ended
June 30,

 
    
2002

    
2001

    
2002

    
2001

 
REVENUES
                             
Crude oil and natural gas sales
  
$
259,873
 
  
232,952
 
  
454,806
 
  
470,151
 
Petroleum product sales
  
 
734,680
 
  
778,071
 
  
1,258,410
 
  
1,450,302
 
Crude oil trading sales
  
 
90,889
 
  
157,866
 
  
154,109
 
  
396,326
 
Other operating revenues
  
 
48,276
 
  
128,145
 
  
95,293
 
  
165,950
 
Interest and other nonoperating revenues
  
 
999
 
  
3,345
 
  
2,002
 
  
7,035
 
    


  

  

  

Total revenues
  
 
1,134,717
 
  
1,300,379
 
  
1,964,620
 
  
2,489,764
 
    


  

  

  

COSTS AND EXPENSES
                             
Crude oil, products and related operating expenses
  
 
914,394
 
  
922,413
 
  
1,600,476
 
  
1,835,624
 
Exploration expenses, including undeveloped lease amortization
  
 
61,767
 
  
41,589
 
  
103,788
 
  
79,550
 
Selling and general expenses
  
 
23,129
 
  
24,983
 
  
45,491
 
  
46,029
 
Depreciation, depletion and amortization
  
 
84,682
 
  
58,256
 
  
155,371
 
  
112,488
 
Amortization of goodwill
  
 
—  
 
  
785
 
  
—  
 
  
1,573
 
Interest expense
  
 
13,287
 
  
9,702
 
  
22,829
 
  
19,446
 
Interest capitalized
  
 
(4,607
)
  
(4,333
)
  
(9,424
)
  
(7,919
)
    


  

  

  

Total costs and expenses
  
 
1,092,652
 
  
1,053,395
 
  
1,918,531
 
  
2,086,791
 
    


  

  

  

Income before income taxes
  
 
42,065
 
  
246,984
 
  
46,089
 
  
402,973
 
Income tax expense
  
 
28,136
 
  
84,416
 
  
29,626
 
  
142,569
 
    


  

  

  

NET INCOME
  
$
13,929
 
  
162,568
 
  
16,463
 
  
260,404
 
    


  

  

  

NET INCOME PER COMMON SHARE
                             
Basic
  
$
.30
 
  
3.60
 
  
.36
 
  
5.77
 
Diluted
  
$
.30
 
  
3.56
 
  
.36
 
  
5.72
 
Average Common shares outstanding
                             
Basic
  
 
45,784,073
 
  
45,206,604
 
  
45,635,493
 
  
45,139,453
 
Diluted
  
 
46,133,432
 
  
45,644,457
 
  
46,029,510
 
  
45,490,094
 
 
See Notes to Consolidated Financial Statements, page 5.

2


 
MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (unaudited)
(Thousands of dollars)
 
    
Three Months Ended June 30,

    
Six Months Ended
June 30,

 
    
2002

  
2001

    
2002

    
2001

 
Net income
  
$
13,929
  
162,568
 
  
16,463
 
  
260,404
 
Other comprehensive income (loss), net of tax
                           
Cash flow hedges
                           
Net derivative gains
  
 
4,675
  
1,454
 
  
7,622
 
  
2,053
 
Reclassification adjustments
  
 
945
  
(232
)
  
(2,378
)
  
1,346
 
    

  

  

  

Total cash flow hedges
  
 
5,620
  
1,222
 
  
5,244
 
  
3,399
 
Net gain (loss) from foreign currency translation
  
 
57,412
  
29,571
 
  
52,416
 
  
(21,868
)
    

  

  

  

Other comprehensive income (loss) before cumulative effect of accounting change
  
 
63,032
  
30,793
 
  
57,660
 
  
(18,469
)
Cumulative effect of accounting change (Note B)
  
 
—  
  
—  
 
  
—  
 
  
6,642
 
    

  

  

  

Other comprehensive income (loss)
  
 
63,032
  
30,793
 
  
57,660
 
  
(11,827
)
    

  

  

  

COMPREHENSIVE INCOME
  
$
76,961
  
193,361
 
  
74,123
 
  
248,577
 
    

  

  

  

 
See Notes to Consolidated Financial Statements, page 5.
 

3


MURPHY OIL CORPORATION AND CONSOLIDATED SUBSIDIARIES
 
CONSOLIDATED STATEMENTS OF CASH FLOWS (unaudited)
(Thousands of dollars)
 
    
Six Months Ended
June 30,

 
    
2002

    
2001

 
OPERATING ACTIVITIES
               
Net income
  
$
16,463
 
  
260,404
 
Adjustments to reconcile net income to net cash provided by operating activities
               
Depreciation, depletion and amortization
  
 
155,371
 
  
112,488
 
Provisions for major repairs
  
 
9,332
 
  
11,051
 
Expenditures for major repairs
  
 
(9,805
)
  
(9,861
)
Dry holes
  
 
72,844
 
  
46,572
 
Amortization of undeveloped leases
  
 
12,267
 
  
10,852
 
Amortization of goodwill
  
 
—  
 
  
1,573
 
Deferred and noncurrent income tax charges
  
 
11,215
 
  
41,491
 
Pretax gains from disposition of assets
  
 
(5,700
)
  
(95,246
)
Net increase in operating working capital other than cash and cash equivalents
  
 
(96,364
)
  
(35,852
)
Other operating activities—net
  
 
5,349
 
  
8,447
 
    


  

Net cash provided by operating activities
  
 
170,972
 
  
351,919
 
    


  

INVESTING ACTIVITIES
               
Property additions and dry holes
  
 
(416,239
)
  
(393,823
)
Proceeds from sale of assets
  
 
28,648
 
  
159,079
 
Other investing activities—net
  
 
2
 
  
(258
)
    


  

Net cash required by investing activities
  
 
(387,589
)
  
(235,002
)
    


  

FINANCING ACTIVITIES
               
Increase (decrease) in notes payable
  
 
298,112
 
  
(9,714
)
Decrease in nonrecourse debt of a subsidiary
  
 
(13,629
)
  
(7,201
)
Cash dividend paid
  
 
(34,233
)
  
(33,835
)
Proceeds from exercise of stock options and employee stock purchase plan
  
 
23,024
 
  
14,333
 
Other financing activities—net
  
 
(2,526
)
  
(2,000
)
    


  

Net cash provided (required) by financing activities
  
 
270,748
 
  
(38,417
)
    


  

Effect of exchange rate changes on cash and cash equivalents
  
 
4,203
 
  
(5,234
)
    


  

Net increase in cash and cash equivalents
  
 
58,334
 
  
73,266
 
Cash and cash equivalents at January 1
  
 
82,652
 
  
132,701
 
    


  

Cash and cash equivalents at June 30
  
$
140,986
 
  
205,967
 
    


  

SUPPLEMENTAL DISCLOSURES OF CASH FLOW ACTIVITIES
               
Cash income taxes paid
  
$
10,916
 
  
79,828
 
Interest paid, net of amounts capitalized
  
 
9,082
 
  
7,908
 
 
See Notes to Consolidated Financial Statements, page 5.
 

4


NOTES TO CONSOLIDATED FINANCIAL STATEMENTS
 
These notes are an integral part of the financial statements of Murphy Oil Corporation and Consolidated Subsidiaries (Murphy/the Company) on pages 1 through 4 of this Form 10-Q report.
 
Note A—Interim Financial Statements
 
The consolidated financial statements of the Company presented herein have not been audited by independent auditors, except for the Consolidated Balance Sheet at December 31, 2001. In the opinion of Murphy’s management, the unaudited financial statements presented herein include all accruals necessary to present fairly the Company’s financial position, and the results of its operations and cash flows for such periods, in conformity with accounting principles generally accepted in the United States of America.
 
Financial statements and notes to consolidated financial statements included in this Form 10-Q report should be read in conjunction with the Company’s 2001 Form 10-K report, as certain notes and other pertinent information have been abbreviated or omitted in this report. Financial results for the six months ended June 30, 2002 are not necessarily indicative of future results.
 
Note B—New Accounting Principles
 
Effective January 1, 2002, the Company was required to adopt Statement of Financial Accounting Standards (SFAS) No. 142, Goodwill and Other Intangible Assets, which requires that amortization of goodwill be replaced with annual tests for impairment and that intangible assets other than goodwill be amortized over their useful lives. Murphy assesses the recoverability of goodwill by comparing the fair value of net assets for conventional oil and natural gas operations in Canada with the carrying value of these net assets, including goodwill. The fair value of the conventional oil and natural gas reporting unit is determined using the expected present value of future cash flows. The carrying amount of goodwill at June 30, 2002 was $52.9 million. The change in the carrying amount of goodwill for the period ended June 30, 2002 was due to a change in the exchange rate of Canadian dollars and U.S. dollars. Goodwill is tested for impairment at the end of the Company’s fiscal year after the oil and gas reserve information is available. Based on its assessment of the fair value of its Canadian conventional oil and natural gas operations, the Company believes the recorded value of goodwill is not impaired. Adjusted net income for the six-month period ended June 30, 2001, excluding goodwill amortization of $1.6 million ($.03 basic and diluted earnings per share), was $262 million. Adjusted basic and diluted earnings per share for the six-month period ended June 30, 2001 were $5.80 and $5.76, respectively.
 
Also effective January 1, 2002, Murphy was required to adopt SFAS No. 144, Accounting for the Impairment or Disposal of Long-Lived Assets, which supercedes SFAS No. 121, Accounting for the Impairment of Long-Lived Assets and for Long-Lived Assets to be Disposed of and the accounting and reporting provisions of APB Opinion No. 30, Reporting the Results of Operations-Reporting the Effects of Disposal of a Segment of a Business, and Extraordinary, Unusual, and Infrequently Occurring Events and Transactions. There was no effect of adopting SFAS No. 144 on the Company’s consolidated financial statements.
 
In July 2001, the FASB issued SFAS No. 143, Accounting for Asset Retirement Obligations, which will require the Company to record a liability equal to the fair value of the estimated cost to retire an asset. The asset retirement liability must be recorded in the period in which the obligation meets the definition of a liability, which is generally when the asset is placed in service. When the liability is initially recorded, the Company will increase the carrying amount of the related long-lived asset by an amount equal to the original liability. The liability is accreted to its present value each period, and the capitalized cost is depreciated over the useful life of the related long-lived asset. Upon adoption of SFAS No. 143 on January 1, 2003, the Company will recognize transition adjustments for existing asset retirement obligations, long-lived assets and accumulated depreciation, all net of related income tax effects, as the cumulative effect of a change in accounting principle. After adoption, any difference between costs incurred upon settlement of an asset retirement obligation and the recorded liability will be recognized as a gain or loss in the Company’s earnings. At this time, it is not practicable to reasonably estimate the impact of adopting SFAS No. 143 on the Company’s consolidated financial statements.

5


 
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)
 
Note B—New Accounting Principles (Contd.)
 
Effective January 1, 2001, Murphy adopted SFAS No. 133, Accounting for Derivative Instruments and Hedging Activities, as amended by SFAS No. 138 (SFAS Nos. 133/138). As a result of the change, Murphy records the fair values of its derivative instruments as either assets or liabilities. All such instruments have been designated as hedges of forecasted cash flow exposures. Changes in the fair value of a qualifying cash flow hedging derivative are deferred and recorded as a component of Accumulated Other Comprehensive Loss (AOCL) in the Consolidated Balance Sheet until the forecasted transaction occurs, at which time the derivative’s fair value will be recognized in earnings. Ineffective portions of a hedging derivative’s change in fair value are immediately recognized in earnings. Adoption of SFAS Nos. 133/138 resulted in a transition adjustment gain to AOCL of $6.6 million, net of $2.8 million in income taxes, for the cumulative effect on prior years; there was no cumulative effect on earnings. Excluding the transition adjustment, the effect of this accounting change increased AOCL for the six months ended June 30, 2002 and 2001 by $5.2 million and $3.4 million, net of $3.6 million and $2.7 million in income taxes, and increased income by an insignificant amount for the same periods, but did not affect income per diluted share. For the six months ended June 30, 2002, gains of $2.4 million, net of $1.4 million in taxes, were reclassified from AOCL to earnings. In the first six months of 2001, losses of $1.3 million, net of $1.2 million in taxes, were reclassified from AOCL to earnings.
 
Note C—Environmental Contingencies
 
The Company’s operations are subject to numerous laws and regulations intended to protect the environment and/or impose remedial obligations. The Company is also involved in personal injury and property damage claims, allegedly caused by exposure to or by the release or disposal of materials manufactured or used in the Company’s operations. The Company operates or has previously operated certain sites and facilities, including refineries, oil and gas fields, gasoline stations, and terminals, for which known or potential obligations for environmental remediation exist.
 
Under the Company’s accounting policies, an environmental liability is recorded when an obligation is probable and the cost can be reasonably estimated. If there is a range of reasonably estimated costs, the most likely amount will be recorded, or if no amount is most likely, the minimum of the range is used. Recorded liabilities are reviewed quarterly. Actual cash expenditures often occur one or more years after a liability is recognized.
 
The Company’s reserve for remedial obligations, which is included in “Deferred Credits and Other Liabilities” in the Consolidated Balance Sheets, contains certain amounts that are based on anticipated regulatory approval for proposed remediation of a former refinery waste site. If regulatory authorities require more costly alternatives than the proposed processes, future expenditures could exceed the amount reserved by up to an estimated $3 million.
 
The Company has received notices from the U.S. Environmental Protection Agency (EPA) that it is currently considered a Potentially Responsible Party (PRP) at three Superfund sites and has also been assigned responsibility by defendants at another Superfund site. The potential total cost to all parties to perform necessary remedial work at these sites may be substantial. Based on currently available information, the Company has reason to believe that it is a de minimus party as to ultimate responsibility at the four sites. The Company does not expect that its related remedial costs will be material to its financial condition or its results of operations, and it has not provided a reserve for remedial costs on Superfund sites. Additional information may become known in the future that would alter this assessment, including any requirement to bear a pro rata share of costs attributable to nonparticipating PRPs or indications of additional responsibility by the Company.
 
The Company does not believe that these or other known environmental matters will have a material adverse effect on its financial condition. There is the possibility that expenditures could be required at currently unidentified sites, and new or revised regulations could require additional expenditures at known sites. Such expenditures could materially affect the results of operations in a future period.
 
Certain environmental expenditures are likely to be recovered by the Company from other sources, primarily environmental funds maintained by certain states. Since no assurance can be given that future recoveries from other sources will occur, the Company has not recognized a benefit for likely recoveries at June 30, 2002.

6


 
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)
 
Note D—Other Contingencies
 
The Company’s operations and earnings have been and may be affected by various other forms of governmental action both in the United States and throughout the world. Examples of such governmental action include, but are by no means limited to: tax increases and retroactive tax claims; import and export controls; price controls; currency controls; allocation of supplies of crude oil and petroleum products and other goods; expropriation of property; restrictions and preferences affecting the issuance of oil and gas or mineral leases; restrictions on drilling and/or production; laws and regulations intended for the promotion of safety; governmental support for other forms of energy; and laws and regulations affecting the Company’s relationships with employees, suppliers, customers, stockholders and others. Because governmental actions are often motivated by political considerations, may be taken without full consideration of their consequences, and may be taken in response to actions of other governments, it is not practical to attempt to predict the likelihood of such actions, the form the actions may take or the effect such actions may have on the Company.
 
The Company and its subsidiaries are engaged in a number of legal proceedings, all of which the Company considers routine and incidental to its business and none of which is considered material. In the normal course of its business, the Company is required under certain contracts with various governmental authorities and others to provide financial guarantees or letters of credit that may be drawn upon if the Company fails to perform under those contracts. At June 30, 2002 the Company had contingent liabilities of $34.5 million under certain financial guarantees and $31.4 million on outstanding letters of credit.
 
Note E—Earnings per Share
 
Net income was used as the numerator in computing both basic and diluted income per Common share for the three-month and six-month periods ended June 30, 2002 and 2001. The following table reconciles the weighted-average shares outstanding used for these computations.
 
    
Three Months Ended
June 30,

  
Six Months Ended
June 30,

    
2002

  
2001

  
2002

  
2001

    
(Weighted-average shares)
Reconciliation of Shares Outstanding
                   
Basic method
  
45,784,073
  
45,206,604
  
45,635,493
  
45,139,453
Dilutive stock options
  
349,359
  
437,853
  
394,017
  
350,641
    
  
  
  
Diluted method
  
46,133,432
  
45,644,457
  
46,029,510
  
45,490,094
    
  
  
  
 
All stock options outstanding during each of the periods presented were dilutive.
 
Note F—Financial Instruments and Risk Management
 
Murphy utilizes derivative instruments on a limited basis to manage certain risks related to interest rates, commodity prices and foreign currency exchange rates. The use of derivative instruments for risk management is covered by operating policies and is closely monitored by the Company’s senior management. The Company does not hold any derivatives for trading purposes, and it does not use derivatives with leveraged or complex features. Derivative instruments are traded primarily with creditworthy major financial institutions or over national exchanges.
 
 
Interest Rate Risks—Murphy has variable-rate debt obligations that expose the Company to the effects of changes in interest rates. To partially reduce its exposure to interest rate risk, Murphy has interest rate swap agreements with notional amounts totaling $50 million at June 30, 2002 to hedge fluctuations in cash flows of a similar amount of variable rate debt. Interest rate swaps with notional amounts totaling $50 million matured during the second quarter of 2002. The remaining swaps mature in 2004. Under the interest rate swaps, the Company pays fixed rates averaging 6.17% over their composite lives and receives variable rates which averaged 2.02% at June 30, 2002. The variable rate received by the Company under each contract is repriced quarterly. The Company has a risk management control system to monitor interest rate cash flow risk attributable to the Company’s outstanding and forecasted debt obligations as well as the offsetting interest rate swaps. The control system involves using analytical techniques, including cash flow sensitivity analysis, to estimate the impact of interest rate changes on future cash flows. The fair value of the effective portions of the interest rate swaps and changes thereto is deferred in Accumulated Other Comprehensive Loss (AOCL) and is subsequently reclassified into Interest Expense in the periods in which the hedged interest payments on the variable-rate debt affect earnings. For the periods ended June 30, 2002 and 2001, the income effect from cash

7


 
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)
 
Note F—Financial Instruments and Risk Management (Contd.)
 
flow hedging ineffectiveness of interest rates was insignificant. The fair value of the interest rate swaps are estimated using projected Federal funds rates, Canadian overnight funding rates and LIBOR forward curve rates obtained from published indices and counterparties. The estimated fair value approximates the values based on quotes from each of the counterparties.
 
 
Natural Gas Fuel Price Risks—The Company purchases natural gas as fuel at its Meraux, Louisiana refinery, and as such, is subject to commodity price risk related to the purchase price of this gas. Murphy has hedged the cash flow risk associated with the cost of a portion of the natural gas it will purchase in 2004 through 2006 by entering into natural gas swap contracts with a total notional volume of 9.2 million British Thermal Units (MMBTU). Under the natural gas swaps, the Company pays a fixed rate averaging $2.78 per MMBTU and receives a floating rate in each month of settlement based on the average NYMEX price for the final three trading days of the month. Murphy has a risk management control system to monitor natural gas price risk attributable both to forecasted natural gas fuel requirements and to Murphy’s natural gas swaps. The control system involves using analytical techniques, including various correlations of natural gas purchase prices to futures prices, to estimate the impact of changes in natural gas fuel prices on Murphy’s cash flows. The fair value of the effective portions of the natural gas swaps and changes thereto is deferred in AOCL and is subsequently reclassified into Crude Oil, Products and Related Operating Expenses in the periods in which the hedged natural gas fuel purchases affect earnings. For the periods ended June 30, 2002 and 2001, the income effect from cash flow hedging ineffectiveness was insignificant.
 
 
Natural Gas Sales Price Risks—The sales price of natural gas produced by the Company is subject to commodity price risk. Murphy has hedged the cash flow risk associated with the sales price for a portion of the natural gas it will produce in the United States and Canada from July 2002 to October 2002 by entering into financial contracts known as natural gas swaps and collars. The swaps cover a combined notional volume averaging 47,000 MMBTU equivalents per day and require Murphy to pay the average relevant index (NYMEX or AECO “C”) price for each month and receive an average price of $3.38 per MMBTU equivalent. The natural gas collars are for a combined notional volume averaging 48,000 MMBTU equivalents per day and based upon the relevant index prices, provide Murphy with an average floor price of $2.73 per MMBTU and an average ceiling price of $4.88 per MMBTU. Murphy has a risk management control system to monitor natural gas price risk attributable both to forecasted natural gas sales prices and to Murphy’s hedging instruments. The control system involves using analytical techniques, including various correlations of natural gas sales prices to futures prices, to estimate the impact of changes in natural gas prices on Murphy’s cash flows from the sale of natural gas.
 
The natural gas price risk pertaining to a portion of gas sales from properties Murphy acquired from Beau Canada in 2000 was limited by natural gas swap agreements that expired in October 2001 that were obtained in the acquisition. These agreements hedged fluctuations in cash flows resulting from such risk. Certain swaps required Murphy to pay a floating price and receive a fixed price and were partially offset by swaps on a lesser volume that required Murphy to pay a fixed price and receive a floating price. The fair value of these swaps was recorded as a net liability upon the acquisition of Beau Canada and was adjusted on January 1, 2001 upon transition to SFAS 133. Net payments by the Company were recorded as a reduction of the associated liability, with any differences recorded as an adjustment of natural gas revenue.
 
The fair values of the effective portions of the natural gas swaps and collars and changes thereto are deferred in AOCL and are subsequently reclassified into Crude Oil and Natural Gas Sales in the periods in which the hedged natural gas sales affect earnings. For the period ended June 30, 2002, Murphy’s earnings were increased by $.3 million from recognition of the ineffective portions of cash flow hedging arising from the natural gas swaps and collars in the United States and western Canada. Murphy’s earnings in the 2001 period were not significantly affected by cash flow hedging ineffectiveness.
 
The fair value of the natural gas fuel swaps and the natural gas sales swaps and collars are both based on the average fixed price of the instruments and the published NYMEX or AECO “C” index futures price or natural gas price quotes from counterparties.

8


 
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)
 
Note F—Financial Instruments and Risk Management (Contd.)
 
 
Crude Oil Purchase Price Risks—Each month, the Company purchases crude oil as the primary feedstock for its U.S. refineries. Prior to April 2000, the Company was a party to crude oil swap agreements that limited the exposure of its U.S. refineries to the risks of fluctuations in cash flows resulting from changes in the prices of crude oil purchases in 2001 and 2002. Under each swap, Murphy would have paid a fixed crude oil price and would have received a floating price during the agreement’s contractual maturity period. In April 2000, the Company settled certain of the swaps and entered into offsetting contracts for the remaining swap agreements, locking in a total net gain of $7.7 million. The fair values of these settlement gains were recorded in AOCL as part of the transition adjustment at January 1, 2001 and are recognized as a reduction of costs of crude oil purchases in the period the forecasted transaction occurs. During the six-month period ended June 30, 2002, pretax gains of $3.6 million were reclassified from AOCL into earnings. No gains were reclassified into earnings in the second quarter of 2002 or in the six-month period ended June 30, 2001. The fair value of the offsetting crude oil swap contracts is based on the fixed swap price and the NYMEX crude oil futures price.
 
The Company expects to reclassify approximately $4 million in after-tax gains from AOCL into earnings during the next 12 months as the forecasted transactions covered by hedging instruments actually occur. All forecasted transactions currently being hedged are expected to occur by December 2006.
 
Note G—Accumulated Other Comprehensive Loss
 
Net gains (losses) in Accumulated Other Comprehensive Loss on the Consolidated Balance Sheets at June 30, 2002 and December 31, 2001 were as follows.
 
    
June 30, 2002

      
December 31, 2001

 
    
(Millions of dollars)
 
Foreign currency translation loss, net
  
$
(35.4
)
    
(87.8
)
Cash flow hedge gains, net
  
 
9.8
 
    
4.5
 
    


    

Accumulated other comprehensive loss
  
$
(25.6
)
    
(83.3
)
    


    

 
Note H—Financing Arrangements
 
In May 2002, the Company sold $350 million of 6.375 percent coupon notes due in 2012. Interest is payable November 1, 2002 and semiannually thereafter. The Company used a portion of the net proceeds to refinance outstanding indebtedness under existing credit facilities and will use the remaining proceeds to fund ongoing capital projects and for other general purposes.
 
Note I—Property, Plant and Equipment
 
During May, the Company and the U.S. government reached an agreement in principle where the U.S. government will pay Murphy $23 million to relinquish seven of nine leases in the Destin Dome field off the coast of Florida. As part of the agreement, the Company will have a 100% interest in the remaining two Destin Dome leases. These leases will run through 2022, with no development application allowed until at least 2012. The Company must obtain permission of both the U.S. government and the State of Florida to perform development operations during the 20-year lease term. There will be no gain or loss recorded in connection with the agreement, and after receipt of the proceeds, Murphy will have approximately $22.5 million of net costs in Property, Plant and Equipment associated with the remaining two leases. Should the U.S. government and/or the State of Florida refuse to permit development by the Company prior to expiration of the leases, the Company’s net investment would be impaired and charged to expense.

9


 
NOTES TO CONSOLIDATED FINANCIAL STATEMENTS (Contd.)
 
Note J—Business Segments
 
    
Total Assets at June 30, 2002

  
Three Months Ended
June 30, 2002

    
Three Months Ended
June 30, 2001

 
       
External
Revenues

    
Intersegment
Revenues

  
Income
(Loss)

    
External
Revenues

    
Intersegment
Revenues

  
Income
(Loss)

 
    
(Millions of dollars)
 
Exploration and production*
                                            
United States
  
$
644.5
  
30.7
    
12.7
  
(4.1
)
  
53.2
    
13.7
  
24.6
 
Canada
  
 
1,340.9
  
181.7
    
—  
  
54.0
 
  
119.3
    
9.1
  
23.8
 
United Kingdom
  
 
239.9
  
39.0
    
—  
  
9.2
 
  
51.2
    
—  
  
21.4
 
Ecuador
  
 
76.5
  
7.9
    
—  
  
3.3
 
  
10.2
    
—  
  
4.3
 
Malaysia
  
 
41.6
  
—  
    
—  
  
(32.1
)
  
—  
    
—  
  
(7.8
)
Other international
  
 
7.9
  
.5
    
—  
  
(.7
)
  
.4
    
—  
  
(5.7
)
    

  
    
  

  
    
  

Total
  
 
2,351.3
  
259.8
    
12.7
  
29.6
 
  
234.3
    
22.8
  
60.6
 
    

  
    
  

  
    
  

Refining and marketing
                                            
United States
  
 
955.5
  
773.9
    
—  
  
(9.8
)
  
838.7
    
—  
  
34.3
 
United Kingdom
  
 
205.2
  
100.0
    
—  
  
1.8
 
  
83.7
    
—  
  
2.0
 
Canada
  
 
1.1
  
—  
    
—  
  
—  
 
  
140.4
    
.1
  
68.4
 
    

  
    
  

  
    
  

Total
  
 
1,161.8
  
873.9
    
—  
  
(8.0
)
  
1,062.8
    
.1
  
104.7
 
    

  
    
  

  
    
  

Total operating segments
  
 
3,513.1
  
1,133.7
    
12.7
  
21.6
 
  
1,297.1
    
22.9
  
165.3
 
Corporate and other
  
 
265.5
  
1.0
    
—  
  
(7.6
)
  
3.3
    
—  
  
(2.7
)
    

  
    
  

  
    
  

Total consolidated
  
$
3,778.6
  
1,134.7
    
12.7
  
14.0
 
  
1,300.4
    
22.9
  
162.6
 
    

  
    
  

  
    
  

 
    
Six Months Ended
June 30, 2002

    
Six Months Ended
June 30, 2001

 
    
External Revenues

    
Intersegment Revenues

  
Income (Loss)

    
External Revenues

    
Intersegment Revenues

  
Income (Loss)

 
    
(Millions of dollars)
 
Exploration and production*
                                       
United States
  
$
53.8
    
22.6
  
(6.7
)
  
132.6
    
30.9
  
55.7
 
Canada
  
 
302.3
    
—  
  
71.8
 
  
219.0
    
30.0
  
51.9
 
United Kingdom
  
 
84.5
    
—  
  
22.4
 
  
101.5
    
—  
  
41.5
 
Ecuador
  
 
13.5
    
—  
  
4.1
 
  
20.3
    
—  
  
8.1
 
Malaysia
  
 
—  
    
—  
  
(40.1
)
  
—  
    
—  
  
(9.0
)
Other international
  
 
1.1
    
—  
  
(1.2
)
  
.9
    
—  
  
(7.0
)
    

    
  

  
    
  

Total
  
 
455.2
    
22.6
  
50.3
 
  
474.3
    
60.9
  
141.2
 
    

    
  

  
    
  

Refining and marketing
                                       
United States
  
 
1,322.3
    
—  
  
(21.3
)
  
1,544.9
    
—  
  
49.3
 
United Kingdom
  
 
185.1
    
—  
  
(.4
)
  
162.2
    
—  
  
3.8
 
Canada
  
 
—  
    
—  
  
—  
 
  
301.4
    
.2
  
71.2
 
    

    
  

  
    
  

Total
  
 
1,507.4
    
—  
  
(21.7
)
  
2,008.5
    
.2
  
124.3
 
    

    
  

  
    
  

Total operating segments
  
 
1,962.6
    
22.6
  
28.6
 
  
2,482.8
    
61.1
  
265.5
 
Corporate and other
  
 
2.0
    
—  
  
(12.1
)
  
7.0
    
—  
  
(5.1
)
    

    
  

  
    
  

Total consolidated
  
$
1,964.6
    
22.6
  
16.5
 
  
2,489.8
    
61.1
  
260.4
 
    

    
  

  
    
  


*
 
Additional details about results of operations are presented in the tables on page 17.

10


 
ITEM 2.    MANAGEMENT’S DISCUSSION AND ANALYSIS OF FINANCIAL CONDITION AND RESULTS OF OPERATIONS
 
Results of Operations
 
Murphy’s net income in the second quarter of 2002 totaled $14 million, $.30 a diluted share, compared to income of $95 million, $2.08 a diluted share, before a special item in the second quarter a year ago. Net income for the second quarter of 2001 totaled $162.6 million, $3.56 a diluted share, and included a gain on sale of Canadian pipeline assets of $67.6 million, $1.48 a diluted share.
 
In the current quarter, the Company’s exploration and production operations earned $29.6 million, a decrease of $31 million from $60.6 million earned in the 2001 period. The decline in income was primarily the result of significantly lower North American natural gas sales prices and higher exploration expenses partially offset by higher oil and gas sales volumes. The Company’s refining and marketing operations incurred a loss of $8 million in the 2002 period compared to earnings of $37.1 million before special items for the three months ended June 30, 2001. Due to negative margins throughout much of the period, Murphy’s U.S. operations lost $9.8 million in the just completed quarter compared to a profit of $34.3 million in the same quarter a year ago.
 
For the first six months of 2002, net income totaled $16.5 million, $.36 a diluted share, compared to income of $192.8 million, $4.24 a diluted share, before a special item for the first half of 2001. Net income a year ago was $260.4 million, $5.72 a diluted share, including an after-tax benefit of $67.6 million, $1.48 a diluted share, from the sale of the Company’s pipeline assets in Canada.
 
Exploration and production earnings in the first six months of 2002 were down $90.9 million from the prior year, mainly due to decreases in North American natural gas sales prices and higher exploration expenses, partially offset by record crude oil and natural gas sales volumes. The Company’s refining and marketing operations incurred a loss of $21.7 million in the first half of 2002 compared to earnings of $56.7 million before a special item in the 2001 period. U.S. refining margins were significantly lower in the 2002 period compared to a year ago.
 
The Company’s worldwide effective tax rate is significantly higher than the expected tax rate primarily because no tax benefit has been recorded for exploration expenses incurred in Malaysia.
 
Exploration and Production
 
Results of exploration and production operations are presented by geographic segment below.
 
    
Income (Loss)

 
    
Three Months Ended
June 30,

    
Six Months Ended
June 30,

 
    
2002

    
2001

    
2002

    
2001

 
    
(Millions of dollars)
 
Exploration and production
                             
United States
  
$
(4.1
)
  
24.6
 
  
(6.7
)
  
55.7
 
Canada
  
 
54.0
 
  
23.8
 
  
71.8
 
  
51.9
 
United Kingdom
  
 
9.2
 
  
21.4
 
  
22.4
 
  
41.5
 
Ecuador
  
 
3.3
 
  
4.3
 
  
4.1
 
  
8.1
 
Malaysia
  
 
(32.1
)
  
(7.8
)
  
(40.1
)
  
(9.0
)
Other International
  
 
(.7
)
  
(5.7
)
  
(1.2
)
  
(7.0
)
    


  

  

  

Total
  
$
29.6
 
  
60.6
 
  
50.3
 
  
141.2
 
    


  

  

  

 
Exploration and production operations in the United States reported a loss of $4.1 million in the second quarter of 2002 compared to earnings of $24.6 million a year ago. This decline was primarily due to lower sales prices for natural gas and oil, lower oil and natural gas sales volumes, and a $19.9 million increase in exploration expenses. Sales of natural gas averaged 99 million cubic feet a day, down from 119 million in the second quarter of 2001 due to lower production in the Gulf of Mexico. U.S. production expenses were up $1.6 million or 13%, primarily because of higher well workover costs.
 
Operations in the United States for the six months ended June 30, 2002 reflected a loss of $6.7 million compared to earnings of $55.7 million from 2001. The decrease was primarily due to lower natural gas sales prices and lower production volumes in the Gulf of Mexico, coupled with higher exploration expenses and increased well workover costs.

11


 
ITEM 2.    MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)
 
Results of Operations (Contd.)
 
Exploration and Production (Contd.)
 
Operations in Canada earned $54 million this quarter compared to $23.8 million a year ago as record production of oil and natural gas were offset by declines in average oil and natural gas sales prices. Also exploration expenses in the 2002 period declined $19.2 million from a year ago. Oil and gas liquids sales in Canada averaged 55,916 barrels a day, an increase of 50% over the prior year, primarily because of higher sales volumes at Hibernia and initial production and sales from the Terra Nova field in 2002, partially offset by a lower production at Syncrude due to maintenance activities. Canadian natural gas sales averaged 231 million cubic feet a day in the current quarter, up 52%, with the increase primarily attributable to higher production from the Ladyfern field. Higher oil and gas sales volumes caused a $7.2 million increase in Canadian production expenses in the 2002 quarter over the 2001 period.
 
In the first half of 2002, Canada operations earned $71.8 million compared to $51.9 million a year ago. Higher sales volumes for oil and natural gas were offset by declines in average oil and natural gas sales prices. Exploration expenses also declined $9.6 million versus 2001.
 
U.K. operations earned $9.2 million in the current quarter, down from $21.4 million in the prior year. Revenues from sales of oil and gas liquids in the United Kingdom decreased 16% primarily due to the timing of liftings and lower sales prices for U.K. crude oil. Income for the 2002 six-month period was $22.4 million compared to $41.5 million a year ago. The decline was primarily due to lower sales prices for U.K. crude oil, higher production expenses and a one-time tax adjustment. In April 2002, U.K. tax authorities announced a corporation tax rate increase from 30% to 40% for profits associated with North Sea oil production. It was also announced that the first-year allowance for North Sea capital expenditures would increase from 25% to 100%. During the second quarter of 2002, the Company recorded a $2 million tax charge due to the rate change. Based on current Company estimates, the net effect of these changes is expected to reduce U.K. income during the last half of 2002 by approximately $4 million.
 
Operations in Ecuador earned $3.3 million in the second quarter of 2002 compared to $4.3 million a year ago, while Malaysia and other international operations reported losses of $32.1 million and $.7 million, respectively, compared to losses of $7.8 million and $5.7 million in 2001. The higher loss in Malaysia in the current period was primarily due to dry holes costs associated with two unsuccessful deepwater wells in Block K. The higher loss in other international operations in the 2001 period was the result of an unsuccessful well offshore Ireland. Crude oil sales in Ecuador decreased 29% which more than offset an increase in the average sales price. Sales volumes in Ecuador were adversely affected by pipeline restrictions. Production expenses in Ecuador decreased by $.9 million in the 2002 period.
 
For the first six months of 2002, earnings in Ecuador were $4.1 million compared to $8.1 million for the 2001 period, while Malaysia and other international operations reported losses of $40.1 million and $1.2 million, respectively, compared to losses of $9 million and $7 million a year ago. Sales volumes in Ecuador decreased 31% in the first half of 2002 due to pipeline capacity restrictions. The higher loss in Malaysia was primarily due to the previously mentioned dry holes.
 
On a worldwide basis, the Company’s crude oil and condensate prices averaged $23.88 a barrel in the current quarter, an increase of 4% from the average of $22.97 in the 2001 period. The increase in the average price in 2002 versus 2001 was due to much stronger heavy oil prices in the 2002 period. Average crude oil and liquids production was a quarterly record of 78,050 barrels a day, up 20% over last year, while average sales volumes increased 19% to 83,313 barrels a day due to initial production and sales from Terra Nova. North American natural gas sales prices averaged $3.03 per MCF in the second quarter compared to $4.33 per MCF in the same quarter of 2001. Total natural gas sales volumes were also a Company record and averaged 336 million cubic feet a day in 2002, up 18% from the 2001 quarter. The tables on page 17 provide additional details of the results of exploration and production operations for the first half of each year.

12


 
ITEM 2.    MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)
 
Results of Operations (Contd.)
 
Exploration and Production (Contd.)
 
Selected operating statistics for the three and six-month periods ended June 30, 2002 and 2001 follow.
 
    
Three Months
Ended June 30,

  
Six Months
Ended June 30,

    
2002

  
2001

  
2002

  
2001

Net crude oil, condensate and gas liquids produced—barrels per day
  
 
78,050
  
64,913
  
76,181
  
66,973
United States
  
 
5,768
  
6,033
  
5,975
  
5,770
Canada—light
  
 
3,107
  
4,314
  
3,585
  
4,448
  —heavy
  
 
9,469
  
11,647
  
9,595
  
12,320
  —offshore
  
 
26,317
  
8,980
  
23,057
  
8,967
   —synthetic
  
 
8,828
  
9,254
  
10,078
  
9,800
United Kingdom
  
 
19,796
  
19,242
  
19,415
  
20,029
Ecuador
  
 
4,765
  
5,443
  
4,476
  
5,639
                       
Net crude oil, condensate and gas liquids sold—barrels per day
  
 
83,313
  
69,932
  
81,769
  
67,855
United States
  
 
5,768
  
6,033
  
5,975
  
5,770
Canada—light
  
 
3,107
  
4,314
  
3,585
  
4,448
  —heavy
  
 
9,469
  
11,647
  
9,595
  
12,320
  —offshore
  
 
34,512
  
12,030
  
28,010
  
9,606
   —synthetic
  
 
8,828
  
9,254
  
10,078
  
9,800
United Kingdom
  
 
17,348
  
20,650
  
20,282
  
19,734
Ecuador
  
 
4,281
  
6,004
  
4,244
  
6,177
                       
Net natural gas sold—thousands of cubic feet per day
  
 
335,954
  
283,979
  
322,696
  
266,486
United States
  
 
99,312
  
119,150
  
100,297
  
121,981
Canada
  
 
231,154
  
152,469
  
215,408
  
129,366
United Kingdom
  
 
5,488
  
12,360
  
6,991
  
15,139
                       
Total net hydrocarbons produced—equivalent barrels per day(1)
  
 
134,042
  
112,243
  
129,964
  
111,387
                       
Total net hydrocarbons sold—equivalent barrels per day(1)
  
 
139,305
  
117,262
  
135,552
  
112,269
                       
Weighted average sales prices Crude oil and condensate—dollars a barrel(2)
                     
United States
  
$
24.84
  
25.52
  
22.48
  
26.45
Canada(3)—light
  
 
24.67
  
24.52
  
20.41
  
24.75
      —heavy
  
 
17.49
  
10.86
  
15.42
  
10.11
      —offshore
  
 
25.47
  
26.76
  
24.13
  
26.84
      —synthetic
  
 
26.06
  
27.55
  
23.36
  
27.88
United Kingdom
  
 
23.56
  
25.91
  
22.03
  
26.47
Ecuador
  
 
20.54
  
18.63
  
17.74
  
18.18
                       
Natural gas—dollars a thousand cubic feet
                     
United States(2)
  
$
3.46
  
4.89
  
3.03
  
6.07
Canada(3)
  
 
2.85
  
3.89
  
2.52
  
4.67
United Kingdom(3)
  
 
2.84
  
2.26
  
2.91
  
2.42

(1)
 
Natural gas converted on an energy equivalent basis of 6:1
(2)
 
Includes intracompany transfers at market prices.
(3)
 
U.S. dollar equivalent.

13


 
ITEM2.    MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)
 
Results of Operations (Contd.)
 
Refining and Marketing
 
Results of refining and marketing operations are presented below by geographic segment.
 
    
Income (Loss)

    
Three Months Ended
June 30,

  
Six Months Ended
June 30,

    
2002

    
2001

  
2002

    
2001

    
(Millions of dollars)
Refining and marketing
                         
United States
  
$
(9.8
)
  
34.3
  
(21.3
)
  
49.3
United Kingdom
  
 
1.8
 
  
2.0
  
(.4
)
  
3.8
Canada
  
 
—  
 
  
.8
  
—  
 
  
3.6
    


  
  

  
Income (loss) before special items
  
 
(8.0
)
  
37.1
  
(21.7
)
  
56.7
Gain on sale of assets
  
 
—  
 
  
67.6
  
—  
 
  
67.6
    


  
  

  
Total income (loss)
  
$
(8.0
)
  
104.7
  
(21.7
)
  
124.3
    


  
  

  
 
Refining and marketing operations in the United States reported a loss of $9.8 million during the second quarter of 2002 compared to earnings of $34.3 million in the same period a year ago. The Company’s U.S. refining margins were significantly lower in the current quarter compared to margins in the same quarter of 2001. U.S. petroleum product sales averaged 179,376 barrels a day in 2002, a 6.4% increase from the second quarter of 2001. Earnings in the United Kingdom were $1.8 million in the 2002 period compared to $2 million a year ago. Worldwide refinery inputs were 161,363 barrels a day in the second quarter of 2002 compared to 172,890 in the 2001 quarter, and petroleum product sales were 214,708 barrels a day, up from 192,167 a year ago. U.S. refinery inputs were significantly lower in the 2002 period due to unscheduled outages of FCC units at the Meraux refinery. Earnings from purchasing, transporting and reselling crude oil in Canada were $.8 million in the 2001 quarter. The Company sold its Canadian pipeline and trucking operations in May 2001 resulting in a net gain of $67.6 million.
 
Refinery and marketing operations in the United States in the first half of 2002 reported a loss of $21.3 million compared to earnings of $49.3 million in the 2001 period. U.S. refining margins were negative during much of the current period compared to the positive margins experienced a year ago. The 2002 results include a net gain of $3.5 million from sale of the Company’s interest in Butte Pipe Line. Results in the United Kingdom reflected a loss of $.4 million in the six months ended June 30, 2002 compared to earnings of $3.8 million in 2001 due to lower refinery margins compared to the same period a year ago. Prior to the sale in the second quarter 2001, the Company earned $3.6 million from purchasing, transporting and reselling crude oil in Canada.
 
Selected operating statistics for the three-month and six-month periods ended June 30, 2002 and 2001 follow.
 
    
Three Months Ended
June 30,

  
Six Months Ended
June 30,

    
2002

  
2001

  
2002

  
2001

Refinery inputs—barrels a day
  
161,363
  
172,890
  
157,952
  
175,777
United States
  
123,568
  
147,751
  
120,660
  
149,692
United Kingdom
  
37,795
  
25,139
  
37,292
  
26,085
Petroleum products sold—barrels a day
  
214,708
  
192,167
  
203,079
  
190,643
United States
  
179,376
  
168,537
  
168,501
  
166,559
Gasoline
  
112,651
  
93,102
  
104,821
  
89,723
Kerosine
  
4,582
  
9,101
  
6,505
  
10,731
Diesel and home heating oils
  
39,071
  
39,958
  
37,407
  
41,322
Residuals
  
14,323
  
17,948
  
13,687
  
17,914
Asphalt, LPG and other
  
8,749
  
8,428
  
6,081
  
6,869
United Kingdom
  
35,332
  
23,630
  
34,578
  
24,084
Gasoline
  
12,865
  
9,502
  
12,856
  
9,440
Kerosine
  
2,438
  
1,418
  
2,546
  
1,997
Diesel and home heating oils
  
15,276
  
8,484
  
14,570
  
7,947
Residuals
  
3,412
  
1,196
  
3,116
  
1,857
LPG and other
  
1,341
  
3,030
  
1,490
  
2,843

14


 
MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)
 
Results of Operations (Contd.)
 
Corporate and other
 
The net costs of corporate activities, which include interest income and expense and corporate overhead not allocated to operating functions, was $7.6 million in the current quarter compared to $2.7 million in the 2001 quarter. In the first six months of 2002, corporate activities reflected a net cost of $12.1 million compared to $5.1 million a year ago. The net costs in both the 2002 periods increased compared to the respective 2001 period due to a decrease in interest income earned caused by lower levels of invested cash balances coupled with higher net interest expense due to increased long-term borrowings.
 
Financial Condition
 
Net cash provided by operating activities was $171 million for the first six months of 2002 compared to $351.9 million for the same period in 2001. Changes in operating working capital other than cash and cash equivalents used cash of $96.4 million and $35.9 million in the first six months of 2002 and 2001, respectively. Cash from operating activities was reduced by expenditures for refinery turnarounds and abandonment of oil and gas properties totaling $9.8 million in the current year and $9.9 million in 2001. Other predominant uses of cash in each year were for capital expenditures, which including amounts expensed, are summarized in the following table, and for dividends, which totaled $34.2 million in 2002 and $33.8 in 2001.
 
    
Six Months Ended June 30,

 
    
2002

    
2001

 
    
(Millions of dollars)
 
Capital Expenditures
               
Exploration and production
  
$
325.3
 
  
344.9
 
Refining and marketing
  
 
109.1
 
  
67.0
 
Corporate and other
  
 
.5
 
  
4.1
 
    


  

Total capital expenditures
  
 
434.9
 
  
416.0
 
Geological, geophysical and other exploration expenses charged to income
  
 
(18.7
)
  
(22.2
)
    


  

Total property additions and dry holes
  
$
416.2
 
  
393.8
 
    


  

 
Working capital at June 30, 2002 was $191.1 million, up $152.5 million from December 31, 2001. This level of working capital does not fully reflect the Company’s liquidity position, because the lower historical costs assigned to inventories under LIFO accounting were $109.7 million below current costs at June 30, 2002.
 
At June 30, 2002, long-term notes payable of $712.8 million were up $296.7 million from December 31, 2001 due to issuance of $350 million of 6.375% notes in May 2002. The Company used a portion of the net proceeds to refinance outstanding indebtedness under existing credit facilities and will use the remaining proceeds to fund ongoing capital projects and for other general purposes. Long-term nonrecourse debt of a subsidiary was $92.5 million, down $12.2 million from December 31, 2001, primarily due to repayments. A summary of capital employed at June 30, 2002 and December 31, 2001 follows.
 
    
June 30, 2002

  
December 31, 2001

    
Amount

  
%

  
Amount

  
%

    
(Millions of dollars)
Capital Employed    
                     
Notes payable
  
$
712.8
  
30
  
416.1
  
21
Nonrecourse debt of a subsidiary
  
 
92.5
  
4
  
104.7
  
5
Stockholders’ equity
  
 
1,571.4
  
66
  
1,498.2
  
74
    

  
  
  
    
$
2,376.7
  
100
  
2,019.0
  
100
    

  
  
  
 
Accounting Matters
 
As described in Note B on page 5 of this Form 10-Q report, Murphy adopted Statement of Financial Accounting Standards No. 142, Goodwill and Other Intangible Assets, and SFAS No. 144, Accounting for the Impairment of Disposal of Long-Lived Assets effective, January 1, 2002.

15


 
MANAGEMENT’S DISCUSSION AND ANALYSIS (Contd.)
 
Outlook
 
For the third quarter of 2002, the Company expects worldwide production to average approximately 117,000 barrels of oil equivalent a day, with lower volumes due to downtime for routine maintenance at Hibernia, Terra Nova and North Sea fields, and expected production decline at the Ladyfern field. Sales volumes are projected to average approximately 111,000 barrels of oil equivalent per day. In July 2002, the Company’s U.S. refining and marketing operations were experiencing losses due to negative refining margins.
 
Forward-Looking Statements
 
This Form 10-Q report contains statements of the Company’s expectations, intentions, plans and beliefs that are forward-looking and are dependent on certain events, risks and uncertainties that may be outside of the Company’s control. These forward-looking statements are made in reliance upon the safe harbor provisions of the Private Securities Litigation Reform Act of 1995. Actual results and developments could differ materially from those expressed or implied by such statements due to a number of factors including those described in the context of such forward-looking statements as well as those contained in the Company’s January 15, 1997 Form 8-K report on file with the U.S. Securities and Exchange Commission.
 
ITEM 3.    QUANTITATIVE AND QUALITATIVE DISCLOSURES ABOUT MARKET RISK
 
The Company was a party to interest rate swaps at June 30, 2002 with notional amounts totaling $50 million that were designed to hedge fluctuations in cash flows of a similar amount of variable-rate debt. These swaps mature in 2004. The swaps require the Company to pay an average interest rate of 6.17% over their composite lives, and at June 30, 2002, the interest rate to be received by the Company averaged 2.02%. The variable interest rate received by the Company under each swap contract is repriced quarterly. The Company considers these swaps to be a hedge against potentially higher future interest rates. The estimated fair value of these interest rate swaps was recorded as a liability of $3.2 million at June 30, 2002.
 
At June 30, 2002, 12% of the Company’s debt had variable interest rates and 4.6% was denominated in Canadian dollars. Based on debt outstanding at June 30, 2002, a 10% increase in variable interest rates would increase the Company’s interest expense approximately $.1 million for the next 12 months after including the favorable effect resulting from lower net settlement payments under the aforementioned interest rate swaps. A 10% increase in the exchange rate of the Canadian dollar versus the U.S. dollar would increase interest expense for the next 12 months by $.1 million for debt denominated in Canadian dollars.
 
Murphy was a party to natural gas price swap agreements at June 30, 2002 for a total notional volume of 9.2 MMBTU that are intended to hedge a portion of the financial exposure of its Meraux, Louisiana refinery to fluctuations in the future price of a portion of natural gas to be purchased for fuel during 2004 through 2006. In each month of settlement, the swaps require Murphy to pay an average natural gas price of $2.78 an MMBTU and to receive the average NYMEX price for the final three trading days of the month. At June 30, 2002, the estimated fair value of these agreements was recorded as an asset of $9.8 million. A 10% increase in the average NYMEX price of natural gas would have increased this asset by $3.2 million, while a 10% decrease would have reduced the asset by a similar amount.
 
In addition, the Company was a party to natural gas swap agreements and natural gas collar agreements at June 30, 2002 that are intended to hedge the financial exposure of a limited portion of its U.S. and Canadian natural gas production to changes in gas sales prices through October 2002. The swaps are for a combined notional volume that averages 47,700 MMBTU equivalents a day through October 2002 and require Murphy to pay the average relevant index price for each month and receive an average price of $3.38 per MMBTU. The collars are for a combined notional volume of 48,000 MMBTU equivalents a day and based upon the relevant index prices provide Murphy with an average floor price of $2.73 per MMBTU and an average ceiling price of $4.88 per MMBTU. At June 30, 2002, the estimated fair value of these agreements was recorded as an asset of $7.4 million. A 10% increase in the average index price of natural gas would have reduced this asset by $2.9 million, while a 10% decrease would have increased the asset by a similar amount.

16


 
OIL AND GAS OPERATING RESULTS (unaudited)
 
    
United States

    
Canada

  
United Kingdom

  
Ecuador

  
Malaysia

    
Other

    
Synthetic Oil- Canada

  
Total

    
(Millions of dollars)
Three Months Ended June 30, 2002
                                               
Oil and gas sales, other operating revenues
  
$
43.4
 
  
160.8
  
39.0
  
7.9
  
—  
 
  
.5
 
  
20.9
  
272.5
Production expenses
  
 
14.2
 
  
25.4
  
8.4
  
3.1
  
—  
 
  
—  
 
  
11.1
  
62.2
Depreciation, depletion and amortization
  
 
10.0
 
  
50.0
  
8.1
  
1.3
  
.2
 
  
—  
 
  
2.1
  
71.7
Exploration expenses
                                               
Dry holes
  
 
17.5
 
  
1.0
  
—  
  
—  
  
31.2
 
  
—  
 
  
—  
  
49.7
Geological and geophysical
  
 
1.3
 
  
1.3
  
—  
  
—  
  
.2
 
  
—  
 
  
—  
  
2.8
Other
  
 
1.8
 
  
.4
  
.3
  
—  
  
.5
 
  
—  
 
  
—  
  
3.0
    


  
  
  
  

  

  
  
    
 
20.6
 
  
2.7
  
.3
  
—  
  
31.9
 
  
—  
 
  
—  
  
55.5
Undeveloped lease amortization
  
 
2.7
 
  
3.6
  
—  
  
—  
  
—  
 
  
—  
 
  
—  
  
6.3
    


  
  
  
  

  

  
  
Total exploration expenses
  
 
23.3
 
  
6.3
  
.3
  
—  
  
31.9
 
  
—  
 
  
—  
  
61.8
    


  
  
  
  

  

  
  
Selling and general expenses
  
 
2.2
 
  
3.6
  
.8
  
.2
  
—  
 
  
1.4
 
  
—  
  
8.2
Income tax provisions (benefits)
  
 
(2.2
)
  
26.7
  
12.2
  
—  
  
—  
 
  
(.2
)
  
2.5
  
39.0
    


  
  
  
  

  

  
  
Results of operations (excluding
  corporate overhead and interest)
  
$
(4.1
)
  
48.8
  
9.2
  
3.3
  
(32.1
)
  
(.7
)
  
5.2
  
29.6
    


  
  
  
  

  

  
  
Three Months Ended June 30, 2001
                                               
Oil and gas sales, other operating revenues
  
$
66.9
 
  
105.1
  
51.2
  
10.2
  
—  
 
  
.4
 
  
23.3
  
257.1
Production expenses
  
 
12.6
 
  
18.2
  
7.6
  
4.0
  
—  
 
  
—  
 
  
13.3
  
55.7
Depreciation, depletion and amortization
  
 
10.4
 
  
23.7
  
8.9
  
1.8
  
.1
 
  
—  
 
  
2.1
  
47.0
Goodwill amortization
  
 
—  
 
  
.8
  
—  
  
—  
  
—  
 
  
—  
 
  
—  
  
.8
Exploration expenses
                                               
Dry holes
  
 
.2
 
  
19.8
  
—  
  
—  
  
3.8
 
  
3.8
 
  
—  
  
27.6
Geological and geophysical
  
 
—  
 
  
1.6
  
.1
  
—  
  
2.6
 
  
.5
 
  
—  
  
4.8
Other
  
 
1.1
 
  
.6
  
.3
  
—  
  
1.3
 
  
.3
 
  
—  
  
3.6
    


  
  
  
  

  

  
  
    
 
1.3
 
  
22.0
  
.4
  
—  
  
7.7
 
  
4.6
 
  
—  
  
36.0
Undeveloped lease amortization
  
 
2.1
 
  
3.5
  
—  
  
—  
  
—  
 
  
—  
 
  
—  
  
5.6
    


  
  
  
  

  

  
  
Total exploration expenses
  
 
3.4
 
  
25.5
  
.4
  
—  
  
7.7
 
  
4.6
 
  
—  
  
41.6
    


  
  
  
  

  

  
  
Selling and general expenses
  
 
2.9
 
  
3.0
  
.6
  
.1
  
—  
 
  
1.6
 
  
—  
  
8.2
Income tax provisions (benefits)
  
 
13.0
 
  
15.0
  
12.3
  
—  
  
—  
 
  
(.1
)
  
3.0
  
43.2
    


  
  
  
  

  

  
  
Results of operations (excluding
  corporate overhead and interest)
  
$
24.6
 
  
18.9
  
21.4
  
4.3
  
(7.8
)
  
(5.7
)
  
4.9
  
60.6
    


  
  
  
  

  

  
  
Six Months Ended June 30, 2002
                                               
Oil and gas sales, other operating revenues
  
$
76.4
 
  
259.7
  
84.5
  
13.5
  
—  
 
  
1.1
 
  
42.6
  
477.8
Production expenses
  
 
28.2
 
  
45.5
  
19.8
  
6.4
  
—  
 
  
—  
 
  
24.0
  
123.9
Depreciation, depletion and amortization
  
 
19.8
 
  
84.8
  
17.9
  
2.6
  
.5
 
  
.1
 
  
4.2
  
129.9
Exploration expenses
                                               
Dry holes
  
 
22.5
 
  
13.4
  
—  
  
—  
  
36.9
 
  
—  
 
  
—  
  
72.8
Geological and geophysical
  
 
3.3
 
  
9.1
  
—  
  
—  
  
.6
 
  
—  
 
  
—  
  
13.0
Other
  
 
2.2
 
  
1.0
  
.5
  
—  
  
2.1
 
  
(.1
)
  
—  
  
5.7
    


  
  
  
  

  

  
  
    
 
28.0
 
  
23.5
  
.5
  
—  
  
39.6
 
  
(.1
)
  
—  
  
91.5
Undeveloped lease amortization
  
 
5.2
 
  
7.1
  
—  
  
—  
  
—  
 
  
—  
 
  
—  
  
12.3
    


  
  
  
  

  

  
  
Total exploration expenses
  
 
33.2
 
  
30.6
  
.5
  
—  
  
39.6
 
  
(.1
)
  
—  
  
103.8
    


  
  
  
  

  

  
  
Selling and general expenses
  
 
6.1
 
  
6.9
  
1.6
  
.4
  
—  
 
  
2.6
 
  
.1
  
17.7
Income tax provisions (benefits)
  
 
(4.2
)
  
29.7
  
22.3
  
—  
  
—  
 
  
(.3
)
  
4.7
  
52.2
    


  
  
  
  

  

  
  
Results of operations (excluding
  corporate overhead and interest)
  
$
(6.7
)
  
62.2
  
22.4
  
4.1
  
(40.1
)
  
(1.2
)
  
9.6
  
50.3
    


  
  
  
  

  

  
  
Six Months Ended June 30, 2001
                                               
Oil and gas sales, other operating revenues
  
$
163.5
 
  
199.5
  
101.5
  
20.3
  
—  
 
  
.9
 
  
49.5
  
535.2
Production expenses
  
 
24.8
 
  
36.3
  
14.8
  
8.4
  
—  
 
  
—  
 
  
28.5
  
112.8
Depreciation, depletion and amortization
  
 
20.7
 
  
41.9
  
18.7
  
3.6
  
.2
 
  
.1
 
  
4.2
  
89.4
Goodwill amortization
  
 
—  
 
  
1.6
  
—  
  
—  
  
—  
 
  
—  
 
  
—  
  
1.6
Exploration expenses
                                               
Dry holes
  
 
15.7
 
  
23.2
  
.1
  
—  
  
3.8
 
  
3.8
 
  
—  
  
46.6
Geological and geophysical
  
 
3.7
 
  
9.0
  
.1
  
—  
  
2.9
 
  
.6
 
  
—  
  
16.3
Other
  
 
1.4
 
  
1.3
  
.5
  
—  
  
2.1
 
  
.6
 
  
—  
  
5.9
    


  
  
  
  

  

  
  
    
 
20.8
 
  
33.5
  
.7
  
—  
  
8.8
 
  
5.0
 
  
—  
  
68.8
Undeveloped lease amortization
  
 
4.1
 
  
6.7
  
—  
  
—  
  
—  
 
  
—  
 
  
—  
  
10.8
    


  
  
  
  

  

  
  
Total exploration expenses
  
 
24.9
 
  
40.2
  
.7
  
—  
  
8.8
 
  
5.0
 
  
—  
  
79.6
    


  
  
  
  

  

  
  
Selling and general expenses
  
 
6.7
 
  
5.1
  
1.2
  
.2
  
—  
 
  
3.0
 
  
—  
  
16.2
Income tax provisions (benefits)
  
 
30.7
 
  
32.8
  
24.6
  
—  
  
—  
 
  
(.2
)
  
6.5
  
94.4
    


  
  
  
  

  

  
  
Results of operations (excluding
  corporate overhead and interest)
  
$
55.7
 
  
41.6
  
41.5
  
8.1
  
(9.0
)
  
(7.0
)
  
10.3
  
141.2
    


  
  
  
  

  

  
  
 
 

17


 
PART II—OTHER INFORMATION
 
ITEM 1.    LEGAL PROCEEDINGS
 
In June 2000, the U.S. Government filed a lawsuit against Murphy Oil USA, Inc., the Company’s wholly-owned subsidiary, in federal court in Madison, Wisconsin, alleging violations of environmental laws at the Company’s Superior, Wisconsin refinery. The lawsuit was divided into liability and damage phases, and on August 1, 2001, the court ruled against the Company in the liability phase of the trial. Subsequent to the court ruling, the Company and the U.S. Government reached a tentative agreement that was filed with the federal court in January 2002. The settlement was approved by the court following a 30-day public comment period that expired March 7, 2002. According to the settlement agreement, the Company paid a civil penalty of $5.5 million in April 2002 and must implement specified environmental projects to resolve Clean Air Act violations. The Company had previously recorded a liability of $5.5 million to cover the liability.
 
In December 2000, two of the Company’s Canadian subsidiaries as plaintiffs filed an action in the Court of Queen’s Bench of Alberta seeking a constructive trust over oil and gas leasehold rights to Crown lands in British Columbia. The suit alleges that the defendants acquired the lands after first inappropriately obtaining confidential and proprietary data belonging to the Company and its joint venturer. In January 2001, one of the defendants, representing an undivided 75% interest in the lands in question, settled its portion of the litigation by conveying its interest to the Company and its joint venturer at cost. In 2001, the remaining defendants, representing the remaining undivided 25% of the lands in question, filed a counterclaim against the Company’s two Canadian subsidiaries and one officer individually seeking compensatory damages of C$6.14 billion. The Company believes that the counterclaim is without merit and that the amount of damages sought is frivolous. While the litigation is in its preliminary stages and no assurance can be given about the outcome, the Company does not believe that the ultimate resolution of this suit will have a material adverse effect on its financial condition.
 
On March 5, 2002, two of the Company’s subsidiaries filed suit against Enron Canada Corp. (“Enron”) to collect approximately $2.1 million owed to Murphy under canceled gas sales contracts. On May 1, 2002, Enron counterclaimed for approximately $19.8 million allegedly owed by Murphy under those same agreements. Although the lawsuit, in the Court of Queen’s Bench, Alberta, is in its early stages and no assurance can be given, the Company does not believe that the Enron counterclaim is meritorious and does not believe that the ultimate resolution of this matter will have a material adverse effect on its financial condition.
 
Murphy and its subsidiaries are engaged in a number of other legal proceedings, all of which Murphy considers routine and incidental to its business and none of which is expected to have a material adverse effect on the Company’s financial condition.
 
ITEM 4.    SUBMISSION OF MATTERS TO A VOTE OF SECURITY HOLDERS
 
At the annual meeting of security holders on May 8, 2002, the directors proposed by management were elected with a tabulation of votes to the nearest share as shown below.
 
    
For

  
Withheld

George S. Dembroski
  
41,372,784
  
767,074
Claiborne P. Deming
  
41,581,176
  
558,682
H. Rodes Hart
  
41,432,020
  
707,838
Robert A. Hermes
  
41,584,917
  
554,941
Michael W. Murphy
  
41,475,856
  
664,002
R. Madison Murphy
  
41,580,019
  
559,839
William C. Nolan Jr.
  
41,265,346
  
874,512
William L. Rosoff
  
41,585,410
  
554,448
David J. H. Smith
  
41,644,766
  
495,092
Caroline G. Theus
  
41,474,582
  
665,276
 
The security holders approved the Company’s annual Incentive Compensation Plan and the performance criteria thereof by a vote of 41,414,183 shares in favor, 674,245 shares against and 51,430 shares not voted. Also the performance criteria for the Company’s Long-Term Incentive Plan was approved by a vote of 41,713,854 shares in favor, 309,312 shares against and 116,692 shares not voted. In addition, the earlier appointment by the Board of Directors of KPMG LLP as independent auditors for 2002 was approved, with 41,436,260 shares voted in favor, 661,329 shares voted in opposition and 42,269 shares not voted.

18


 
ITEM 6.    EXHIBITS AND REPORTS ON FORM 8-K
 
(a)
  
The Exhibit Index on page 20 of this Form 10-Q report lists the exhibits that are hereby filed or incorporated by reference.
(b)
  
A report on Form 8-K was filed on April 26, 2002 that included the Company’s News Release, dated April 24, 2002, announcing the Company’s earnings and certain other financial information for the three-month period ended March 31, 2002.
(c)
  
A report on Form 8-K was filed on May 3, 2002 that included the Second Supplemental Indenture, dated May 2, 2002, between the Company and SunTrust Bank as Trustee (“the Trustee”).
 
 
 
 
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 thereunto duly authorized.
 
MURPHY OIL CORPORATION
  (Registrant)
 
By:
 
/s/    JOHN W. ECKART         

   
John W. Eckart, Controller
(Chief Accounting Officer and Duly
Authorized Officer)
 
August 2, 2002
(Date)
 

19


 
EXHIBIT INDEX
 
Exhibit
No.

      
Incorporated by Reference to

  3.1
 
Certificate of Incorporation of Murphy Oil Corporation
as amended, effective May 17, 2001
  
Exhibit 3.1 of Murphy’s Form 10-Q report for the quarterly period ended June 30, 2001
  3.2
 
By-Laws of Murphy Oil Corporation as amended effective May 8, 2002
  
Exhibit 3.2 filed herewith
  4   
 
Instruments Defining the Rights of Security Holders. Murphy is party to several long-term debt instruments in addition to the one in Exhibit 4.1, none of which authorizes securities exceeding 10% of the total consolidated assets of Murphy and its subsidiaries. Pursuant to Regulation S-K, item 601(b), paragraph 4(iii)(A), Murphy agrees to furnish a copy of each such instrument to the Securities and Exchange Commission upon request
    
  4.1
 
Form of Second Supplemental Indenture between Murphy Oil Corporation and SunTrust Bank, as Trustee
  
Exhibit 4.1 of Murphy’s Form 8-K report filed May 3, 2002 under the Securities Exchange Act of 1934
  4.2
 
Form of Indenture and Form of Supplemental Indenture between Murphy Oil Corporation and SunTrust Bank, as Trustee
  
Exhibits 4.1 and 4.2 of Murphy’s Form 8-K report filed April 29, 1999 under the Securities Exchange Act of 1934
  4.3
 
Rights Agreement dated as of December 6, 1989 between Murphy Oil Corporation and Harris Trust Company of New York, as Rights Agent
  
Exhibit 4.3 of Murphy’s Form 10-K report for the year ended December 31, 1999
  4.4
 
Amendment No. 1 dated as of April 6, 1998 to Rights Agreement dated as of December 6, 1989 between Murphy Oil Corporation and Harris Trust Company of New York, as Rights Agent
  
Exhibit 3 of Murphy’s Form 8-A/A, Amendment No. 1, filed April 14, 1998 under the Securities Exchange Act of 1934
  4.5
 
Amendment No. 2 dated as of April 15, 1999 to Rights Agreement dated as of December 6, 1989 between Murphy Oil Corporation and Harris Trust Company of New York, as Rights Agent
  
Exhibit 4 of Murphy’s Form 8-A/A, Amendment No. 2, filed April 19, 1999 under the Securities Exchange Act of 1934
10.1
 
1992 Stock Incentive Plan as amended May 14, 1997
  
Exhibit 10.2 of Murphy’s Form 10-Q report for the quarterly period ended June 30, 1997
10.2
 
Employee Stock Purchase Plan as amended May 10, 2000
  
Exhibit 99.01 of Murphy’s Form S-8 registration statement filed August 4, 2000 under the Securities Act of 1933
99.1
 
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
  
Exhibit 99.1 filed herewith
99.2
 
Certification Pursuant to 18 U.S.C. Section 1350, as Adopted Pursuant to Section 906 of the Sarbanes-Oxley Act of 2002
  
Exhibit 99.2 filed herewith
 
Exhibits other than those listed above have been omitted since they are either not required or not applicable.

20

Exhibit 3.2 BY-LAWS [LOGO OF MURPHY OIL CORPORATION] ARTICLE I. Offices. Section 1. Offices. Murphy Oil Corporation (hereinafter called the Company) may have, in addition to its principal office in Delaware, a principal or other office or offices at such place or places, either within or without the State of Delaware, as the board of directors may from time to time determine or as shall be necessary or appropriate for the conduct of the business of the Company. ARTICLE II. Meetings of Stockholders. Section 1. Place of Meetings. The annual meeting of the stockholders shall be held at the place therein determined by the board of directors and stated in the notice thereof, and other meetings of the stockholders may be held at such place or places, within or without the State of Delaware, as shall be fixed by the board of directors and stated in the notice thereof. Section 2. Annual Meetings. The annual meeting of stockholders for the election of directors and the transaction of such other business as may come before the meeting shall be held in each year on the second Wednesday in May. If this date shall fall upon a legal holiday, the meeting shall be held on the next succeeding business day. At each annual meeting the stockholders entitled to vote shall elect a board of directors and they may transact such other corporate business as shall be stated in the notice of the meeting. Section 3. Special Meetings. Special meetings of the stockholders for any purpose or purposes may be called by the Chairman of the Board or by order of the board of directors and shall be called by the Chairman of the Board or the Secretary upon the written request of stockholders holding of record at least a majority of the outstanding shares of stock of the Company entitled to vote at such meeting. Such written request shall state the purpose or purposes for which such meeting is to be called. Section 4. Notice of Meetings. Except as otherwise expressly required by law, notice of each meeting of stockholders, whether annual or special, shall be given at least 10 days before the date on Ex.3.2-1

which the meeting is to be held to each stockholder of record entitled to vote thereat by delivering a notice thereof to him personally, or by mailing such notice in a postage prepaid envelope directed to him at his address as it appears on the books of the Company, unless he shall have filed with the Secretary of the Company a written request that notices intended for him be directed to another address, in which case such notice shall be directed to him at the address designated in such request. Notice of any meeting of stockholders shall not be required to be given to any stockholder who shall attend such meeting in person or by proxy; and if any stockholder shall in person or by attorney thereunto authorized, in writing or by telegraph, cable, radio or wireless and confirmed in writing, waive notice of any meeting of the stockholders, whether prior to or after such meeting, notice thereof need not be given to him. Notice of any adjourned meeting of the stockholders shall not be required to be given except where expressly required by law. Section 5. Quorum. At each meeting of the stockholders the holders of record of a majority of the issued and outstanding stock of the Company entitled to vote at such meeting, present in person or by proxy, shall constitute a quorum for the transaction of business except where otherwise provided by law, the certificate of incorporation or these by-laws. In the absence of a quorum, any officer entitled to preside at or act as secretary of such meeting shall have the power to adjourn the meeting from time to time until a quorum shall be constituted. At any such adjourned meeting at which a quorum shall be present any business may be transacted which might have been transacted at the meeting as originally called. Section 6. Voting. At every meeting of stockholders each holder of record of the issued and outstanding stock of the Company entitled to vote at such meeting shall be entitled to one vote in person or by proxy, but no proxy shall be voted after three years from its date unless the proxy provides for a longer period, and, except where the transfer books of the Company have been closed or a date has been fixed as the record date for the determination of stockholders entitled to vote, no share of stock shall be voted directly or indirectly. At all meetings of the stockholders, a quorum being present, all matters shall be decided by majority vote of those present in person or by proxy, except as otherwise required by the laws of the State of Delaware or the certificate of incorporation. The vote thereat on any question need not be by ballot unless required by the laws of the State of Delaware. ARTICLE III. Board of Directors. Section 1. General Powers. The property, business and affairs of the Company shall be managed by the board of directors. Section 2. Number and Term of Office. The number of directors shall be ten, but may from time to time be increased or diminished to not less than three by amendment of these by-laws. Directors need not be stockholders. Each director shall hold office until the annual meeting of the stockholders next following his election and until his successor shall have been elected and shall qualify, or until his death, resignation or removal. Ex.3.2-2

Section 3. Quorum and Manner of Acting. Unless otherwise provided by law the presence of six members of the board of directors shall be necessary to constitute a quorum for the transaction of business. In the absence of a quorum, a majority of the directors present may adjourn the meeting from time to time until a quorum shall be present. Notice of any adjourned meeting need not be given. At all meetings of directors, a quorum being present, all matters shall be decided by the affirmative vote of a majority of the directors present, except as otherwise required by the laws of the State of Delaware. Section 4. Place of Meetings, etc. The board of directors may hold its meetings and keep the books and records of the Company at such place or places within or without the State of Delaware as the board may from time to time determine. Section 5. Annual Meeting. Promptly after each annual meeting of stockholders for the election of directors and on the same day the board of directors shall meet for the purpose of organization, the election of officers and the transaction of other business. Notice of such meeting need not be given. Such meeting may be held at any other time or place as shall be specified in a notice given as hereinafter provided for special meetings of the board of directors or in a consent and waiver of notice thereof signed by all the directors. Section 6. Regular Meetings. Regular meetings of the board of directors may be held at such time and place, within or without the State of Delaware, as shall from time to time be determined by the board of directors. After there has been such determination and notice thereof has been once given to each member of the board of directors, regular meetings may be held without further notice being given. Section 7. Special Meetings; Notice. Special meetings of the board of directors shall be held whenever called by the Chairman of the Board or by a majority of the directors. Notice of each such meeting shall be mailed to each director, addressed to him at his residence or usual place of business, at least 10 days before the day on which the meeting is to be held, or shall be sent to him at such place by telegraph, cable, radio or wireless, or be delivered personally or by telephone, not later than the day before the day on which such meeting is to be held. Each such notice shall state the time and place of the meeting but need not state the purposes thereof. Notice of any meeting of the board of directors need not be given to any director, however, if waived by him in writing or by telegraph, cable, radio or wireless and confirmed in writing, whether before or after such meeting, or if he shall be present at such meeting. Any meeting of the board of directors shall be a legal meeting without any notice thereof having been given if all the directors then in office shall be present thereat. Section 8. Resignation. Any director of the Company may resign at any time by giving written notice to the Chairman of the Board or the Secretary of the Company. The resignation of any director shall take effect upon receipt of notice thereof or at such later time as shall be specified in such notice; and, unless otherwise specified therein, the acceptance of such resignation shall not be necessary to make it effective. Section 9. Removal. Any director may be removed at any time, either with or without cause, by the affirmative vote of the holders of record of a majority of the issued and outstanding class of Ex.3.2-3

stock of the Company entitled to vote for the election of such director, given at a special meeting of the stockholders called for that purpose. The vacancy in the board of directors caused by any such removal may be filled by the stockholders at such meeting. Section 10. Vacancies. Any vacancy that shall occur in the board of directors by reason of death, resignation, disqualification or removal or any other cause whatever, unless filled as provided in Section 9 hereof, shall be filled by the majority (even if that be only a single director) of the remaining directors theretofore elected by the holders of the class of capital stock which elected the directors whose office shall have become vacant. If any new directorship is created by increase in the number of directors, a majority of the directors then in office may fill such new directorship. The term of office of any director so chosen to fill a vacancy or a new directorship shall terminate upon the election and qualification of directors at any meeting of stockholders called for the purpose of electing directors. Section 11. Compensation of Directors. Directors may receive a fee, as fixed by the Chairman of the Board, for their services, together with expenses for attendance at regular or special meetings of the board. Members of committees of the board of directors may be allowed compensation for attending committee meetings. Nothing herein contained shall be construed to preclude any director from serving the Company or any subsidiary thereof in any other capacity and receiving compensation therefor. ARTICLE IV. Committees of the Board. Section 1. Executive Committee. The board of directors shall elect from the directors an executive committee. The board of directors shall fill vacancies in the executive committee by election from the directors. The executive committee shall fix its own rules of procedure and shall meet where and as provided by such rules or by resolution of the board of directors, but in every case the presence of at least three members of the committee shall be necessary to constitute a quorum for the transaction of business. In every case the affirmative vote of a majority of all of the members of the committee present at the meeting shall be necessary for the adoption of any resolution. Section 2. Membership and Powers. The executive committee shall consist of such number of members as the board in its discretion shall determine, in addition to the Chairman of the Board, who by virtue of his office shall be a member of the executive committee and chairman thereof. Unless otherwise ordered by the board of directors, each elected member of the executive committee shall continue to be a member thereof until the expiration of his term of office as a director. Ex.3.2-4

The executive committee, subject to any limitations prescribed by the board of directors, shall have special charge of all financial accounting, legal and general administrative affairs of the Company. During the intervals between the meetings of the board of directors the executive committee shall have all the powers of the board in the management of the business and affairs of the Company, including the power to authorize the seal of the Company to be affixed to all papers which require it, except that said committee shall not have the power of the board (i) to fill vacancies in the board, (ii) to amend the by-laws, (iii) to adopt a plan of merger or consolidation, (iv) to recommend to the stockholders the sale, lease, exchange, mortgage, pledge or other disposition of all or substantially all of the property and assets of the Company otherwise than in the usual and regular course of its business, or (v) to recommend to the stockholders a voluntary dissolution of the Company or a revocation thereof. Section 3. Other Committees. The board of directors may, by resolution or resolutions passed by a majority of the whole board, designate one or more other committees, each committee to consist of two or more of the directors of the Company, which, to the extent provided in said resolution or resolutions, shall have and may exercise the powers of the board of directors in the management of the business and affairs of the Company, and may have power to authorize the seal of the Company to be affixed to all papers which may require it. Such committee or committees shall have such name or names as may be determined from time to time by resolution adopted by the board of directors. ARTICLE V. Officers. Section 1. Number. The principal officers of the Company shall be a Chairman of the Board, President, one or more Vice Presidents (which may be designated as Executive or Senior Vice President(s)), a Secretary, a Treasurer, and a Controller. No officers except the Chairman of the Board and President need be directors. One person may hold the offices and perform the duties of any two or more of said offices. Section 2. Election and Term of Office. The principal officers of the Company shall be chosen annually by the board of directors at the annual meeting thereof. Each such officer shall hold office until his successor shall have been chosen and shall qualify, or until his death or until he shall resign or shall have been removed in the manner hereinafter provided. Section 3. Subordinate Officers. In addition to the principal officers enumerated in Section 1 of this Article V, the Company may have one or more Assistant Vice Presidents, one or more Assistant Treasurers, one or more Assistant Secretaries and such other officers, agents and employees as the board of directors may deem necessary, each of whom shall hold office for such period, have such authority, and perform such duties as the board or the President may from time to time determine. The board of directors may delegate to any principal officer the power to appoint and to remove any such subordinate officers, agents or employees. Ex.3.2-5

Section 4. Compensation of Principal Officers. The salaries of the principal officers shall be fixed from time to time either by the board of directors or by a committee of the board to which such power may be delegated. The salaries of any other officers shall be fixed by the President or by a committee or committees to which he may delegate such power. Section 5. Removal. Any officer may be removed, either with or without cause, at any time, by resolution adopted by the board of directors at any regular meeting of the board or at any special meeting of the board called for the purpose at which a quorum is present. Section 6. Vacancies. A vacancy in any office may be filled for the unexpired portion of the term in the manner prescribed in these by-laws for election or appointment to such office for such term. Section 7. Chairman of the Board. The Chairman of the Board shall preside at all meetings of the stockholders and directors at which he may be present. He shall have such other authority and responsibility and perform such other duties as may be determined by the board of directors. Section 8. President. The President shall be the chief executive officer of the Company and as such shall have general supervision and management of the affairs of the Company subject to the control of the board of directors. He may enter into any contract or execute any deeds, mortgages, bonds, contracts or other instruments in the name and on behalf of the Company except in cases in which the authority to enter into such contract or execute and deliver such instrument, as the case may be, shall be otherwise expressly delegated. In general he shall perform all duties incident to the office of President as herein defined and all such other duties as from time to time may be assigned to him by the board of directors. In the absence of the Chairman of the Board, the President shall preside at meetings of the stockholders and directors. Section 9. Vice Presidents. The Vice Presidents, in order of their seniority unless otherwise determined by the board of directors, shall in the absence or disability of the President perform the duties and exercise the powers of such offices. The Vice Presidents shall perform such other duties and have such other powers as the President or the board of directors may from time to time prescribe. Section 10. Secretary. The Secretary shall attend all sessions of the board and all meetings of the stockholders, and record all votes and the minutes of all proceedings in a book to be kept for that purpose, and shall perform like duties for the committees of the board of directors when required. He shall give or cause to be given, notice of all meetings of the stockholders and of special meetings of the board of directors, and shall perform such other duties as may be prescribed by the board of directors, or the President, under whose supervision he shall be. He shall keep in safe custody the seal of the Company and, when authorized by the board of directors, affix the same to any instrument requiring it, and when so affixed it shall be attested by his signature or by the signature of the Treasurer or an Assistant Secretary. Section 11. Treasurer. The Treasurer shall have custody of the corporate funds and securities and shall keep full and accurate accounts of receipts and disbursements in the books belonging to the Ex.3.2-6

Company, and shall deposit all moneys and other valuable effects in the name and to the credit of the Company in such depositories as may be designated from time to time by the Board of Directors. He shall disburse the funds of the Company as may be ordered by the board, taking proper vouchers for such disbursements, and shall render to the President and board of directors at the regular meetings of the board, or whenever they may require it, an account of the financial condition of the Company. If required by the board of directors, he shall give the Company a bond, in such sum and with such surety or sureties as shall be satisfactory to the board, for the faithful performance of the duties of his office, and for the restoration to the Company, in case of his death, resignation, retirement or removal from office, of all books, papers, vouchers, money and other property of whatever kind in his possession or under his control belonging to the Company. Section 12. Controller. The Controller shall be in charge of the accounts of the Company and shall perform such duties as from time to time may be assigned to him by the President or by the board of directors. ARTICLE VI. Shares and Their Transfer. Section 1. Certificates for Stock. Certificates for shares of capital stock of the Company shall be numbered, and shall be entered in the books of the Company, in the order in which they are issued. Section 2. Regulations. The board of directors may make such rules and regulations as it may deem expedient, not inconsistent with the certificate of incorporation or these by-laws, concerning the issue, transfer and registration of certificates for shares of capital stock of the Company. It may appoint, or authorize any principal officer or officers to appoint, one or more transfer clerks or one or more transfer agents and one or more registrars, and may require all such certificates to bear the signature or signatures of any of them. Section 3. Stock Certificate Signature. The certificates for shares of the respective classes of such stock shall be signed by, or in the name of the Company by, the Chairman of the Board, the President or any Vice President and the Treasurer or an Assistant Treasurer, or the Secretary or an Assistant Secretary, and where signed (a) by a transfer agent or an assistant transfer agent or (b) by a transfer clerk acting on behalf of the Company and a registrar, the signature of any such Chairman of the Board, President, Vice President, Treasurer, Assistant Treasurer, Secretary or Assistant Secretary may be facsimile. Each such certificate shall exhibit the name of the holder thereof and number of shares represented thereby and shall not be valid until countersigned by a transfer agent. Ex.3.2-7

The board of directors may, if it so determines, direct that certificates for shares of any class or classes of capital stock of the Company be registered by a registrar, in which case such certificates will not be valid until so registered. In case any officer of the Company who shall have signed, or whose facsimile signature shall have been used on, any certificate for shares of capital stock of the Company shall cease to be such officer, whether because of death, resignation or otherwise, before such certificate shall have been delivered by the Company, such certificate shall nevertheless be deemed to have been adopted by the Company and may be issued and delivered as though the person who signed such certificate or whose facsimile signature shall have been used thereon had not ceased to be such officer. Section 4. Designations, Preferences, etc. on Certificates for Stock. Certificates for shares of capital stock of the Company shall state on the face or back thereof that the Company will furnish without charge to each stockholder who so requests (which request may be addressed to the Secretary of the Company or to a transfer agent) a statement of the designations, preferences and relative, participating, optional or other special rights of each class of stock or series thereof which the Company is authorized to issue and the qualifications, limitations or restrictions of such preferences and/or rights. Section 5. Stock Ledger. A record shall be kept by the Secretary or by any other officer, employee or agent designated by the board of directors of the name of the person, firm, or corporation holding the stock represented by such certificates, the number of shares represented by such certificates, respectively, and the respective dates thereof, and in case of cancellation the respective dates of cancellation. Section 6. Cancellation. Every certificate surrendered to the Company for exchange or transfer shall be canceled, and no new certificate or certificates shall be issued in exchange for any existing certificate until such existing certificate shall have been so canceled. Section 7. Transfers of Stock. Transfers of shares of the capital stock of the Company shall be made only on the books of the Company by the registered holder thereof or by his attorney thereunto authorized on surrender of the certificate or certificates for such shares properly endorsed and the payment of all taxes thereon. The person in whose name shares of stock stand on the books of the Company shall be deemed the owner thereof for all purposes as regards the Company; provided, however, that whenever any transfer of shares shall be made for collateral security, and not absolutely, such fact, if known to the Secretary or the transfer agent making such transfer, shall be so expressed in the entry of transfer. Section 8. Closing of Transfer Books. The board of directors may by resolution direct that the stock transfer books of the Company be closed for a period not exceeding 60 days preceding the date of any meeting of the stockholders, or the date for the payment of any dividend, or the date for the allotment of any rights, or the date when any change or conversion or exchange of capital stock of the Company shall go into effect, or for a period not exceeding 60 days in connection with obtaining the consent of stockholders for any purpose. In lieu of such closing of the stock transfer books, the board may fix in advance a date, not exceeding 60 days preceding the date of any meeting Ex.3.2-8

of stockholders, or the date for the payment of any dividend, or the date for the allotment of rights, or the date when any change or conversion or exchange of capital stock shall go into effect or a date in connection with obtaining such consent, as a record date for the determination of the stockholders entitled to notice of, and to vote at, such meeting, and any adjournment thereof, or to receive payment of any such dividend, or to receive any such allotment of rights, or to exercise the rights in respect of any such change, conversion, or exchange of capital stock or to give such consent, as the case may be, notwithstanding any transfer of any stock on the books of the Company after any record date so fixed. ARTICLE VII. Miscellaneous Provisions. Section 1. Corporate Seal. The board of directors shall provide a corporate seal which shall be in the form of a circle and shall bear the name of the Company and words and figures showing that it was incorporated in the State of Delaware in the year 1964. The Secretary shall be the custodian of the seal. The board of directors may authorize a duplicate seal to be kept and used by any other officer. Section 2. Fiscal Year. The fiscal year of the Company shall be fixed by resolution of the board of directors. Section 3. Voting of Stocks Owned by the Company. The board of directors may authorize any person in behalf of the Company to attend, vote and grant proxies to be used at any meeting of stockholders of any corporation in which the Company may hold stock. Section 4. Dividends. Subject to the provisions of the certificate of incorporation, the board of directors may, out of funds legally available therefor, at any regular or special meeting declare dividends upon the capital stock of the Company as and when they deem expedient. Dividends may be paid in cash, in property, or in shares of capital stock of the Company, subject to the provisions of the certificate of incorporation. Before declaring any dividend there may be set apart out of any funds of the Company available for dividends such sum or sums as the directors from time to time in their discretion deem proper for working capital or as a reserve fund to meet contingencies or for equalizing dividends or for such other purposes as the directors shall deem conducive to the interests of the Company. ARTICLE VIII. Indemnification of Officers, Directors, Employees and Agents; Insurance. Section 1. Indemnification. Ex.3.2-9

(a) The Company may indemnify any person who was or is a party or is threatened to be made a party to any threatened, pending or completed action, suit or proceeding, whether civil, criminal, administrative or investigative (including an action by or in the right of the Company) by reason of the fact that he is or was a director, officer, employee or agent of the Company, or is or was serving at the request of the Company as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise, against expenses (including attorneys' fees) and, except for an action by or in the right of the Company, judgments, fines and amounts paid in settlement, actually and reasonably incurred by him in connection with such action, suit or proceeding, if he acted in good faith and in a manner he reasonably believed to be in or not opposed to the best interests of the Company, and, with respect to any criminal action or proceeding, had no reasonable cause to believe his conduct was unlawful. Except for an action by or in the right of the Company, the termination of any action, suit or proceeding by judgment, order, settlement, conviction, or upon a plea of nolo contendere or its equivalent, shall not, of itself, create a presumption that the person did not act in good faith and in a manner which he reasonably believed to be in or not opposed to the best interests of the Company, and, with respect to any criminal action or proceeding, had reasonable cause to believe that his conduct was unlawful. With respect to an action by or in the right of the Company, no indemnification shall be made in respect of any claim, issue or matter as to which such person shall have been adjudged to be liable for negligence or misconduct in the performance of his duty to the Company unless and only to the extent that the Delaware Court of Chancery or the court in which such action or suit was brought shall determine upon application that, despite the adjudication of liability but in view of all the circumstances of the case, such person is fairly and reasonably entitled to indemnity for such expenses which such court shall deem proper. (b) To the extent that a director, officer, employee or agent of the Company has been successful on the merits or otherwise in defense of any action, suit or proceeding referred to in subsection (a) or in defense of any claim, issue or matter therein, he shall be indemnified against expenses (including attorneys' fees) actually and reasonably incurred by him in connection therewith. (c) Any indemnification under subsection (a) (unless ordered by a court) shall be made by the Company only as authorized in the specific case upon a determination that indemnification of the director, officer, employee or agent is proper in the circumstances because he has met the applicable standard of conduct set forth in subsection (a). Such determination shall be made (i) by the board of directors by a majority vote of a quorum consisting of directors who were not parties to such action, suit or proceeding, or (ii) if such a quorum is not obtainable, or, even if obtainable a quorum of disinterested directors so directs, by independent legal counsel in a written opinion, or (iii) by the stockholders. (d) Expenses incurred in defending a civil or criminal action, suit or proceeding may be paid by the Company in advance of the final disposition of such action, suit or proceeding as authorized by the board of directors in the manner provided in subsection (c) upon receipt of an undertaking by or on behalf of the director, officer, employee or agent to repay such amount unless it shall ultimately be determined that he is entitled to be indemnified by the Company as authorized in this section. Ex.3.2-10

(e) The indemnification provided by this Article shall not be deemed exclusive of any other rights to which those seeking indemnification may be entitled under any agreement, vote of stockholders or disinterested directors or otherwise, both as to action in their official capacities and as to action in other capacities while holding such offices, and shall continue as to a person who has ceased to be a director, officer, employee or agent and shall inure to the benefit of the heirs, executors and administrators of such a person. Section 2. Insurance. The Company may purchase and maintain insurance on behalf of any person who is or was a director, officer, employee or agent of the Company, or is or was serving at the request of the Company as a director, officer, employee or agent of another corporation, partnership, joint venture, trust or other enterprise against any liability asserted against him and incurred by him in any such capacity, or arising out of his status as such, whether or not the Company would have the power to indemnify him against such liability under the provisions of either the General Corporation Law of the State of Delaware or of these by-laws. ARTICLE IX. Amendments. The by-laws of the Company may be altered, amended or repealed either by the affirmative vote of a majority of the stock issued and outstanding and entitled to vote in respect thereof and represented in person or by proxy at any annual or special meeting of the stockholders, or by the affirmative vote of a majority of the directors then in office given at any regular or special meeting of the board of directors. By-laws, whether made or altered by the stockholders or by the board of directors, shall be subject to alteration or repeal by the stockholders as in this Article provided. Ex.3.2-11

EXHIBIT 99.1 CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002 In connection with the Quarterly Report of Murphy Oil Corporation (the "Company") on Form 10-Q for the period ending June 30, 2002 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, Claiborne P. Deming, Principal Executive Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that: (1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and (2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. /s/ Claiborne P. Deming - ----------------------- Claiborne P. Deming Principal Executive Officer August 2, 2002

EXHIBIT 99.2 CERTIFICATION PURSUANT TO 18 U.S.C. SECTION 1350, AS ADOPTED PURSUANT TO SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002 In connection with the Quarterly Report of Murphy Oil Corporation (the "Company") on Form 10-Q for the period ending June 30, 2002 as filed with the Securities and Exchange Commission on the date hereof (the "Report"), I, Steven A. Cosse, Principal Financial Officer of the Company, certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that: (1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and (2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company. /s/ Steven A. Cosse - ---------------------- Steven A. Cosse Principal Financial Officer August 2, 2002