Murphy Oil (MUR) 10-Q 2 Nov 17 2017 Q3 Quarterly report Financial data

Document and Entity Information

Document and Entity Information - shares	9 Months Ended
	Sep. 30, 2017	Oct. 31, 2017
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Sep. 30, 2017
Document Fiscal Year Focus	2,017
Document Fiscal Period Focus	Q3
Trading Symbol	mur
Entity Registrant Name	MURPHY OIL CORP /DE
Entity Central Index Key	717,423
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		172,572,873

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Current assets
Cash and equivalents	$ 997,207	$ 872,797
Canadian government securities with maturities greater than 90 days at the date of acquisition		111,542
Accounts receivable, less allowance for doubtful accounts of $1,605 in 2017 and 2016	267,209	357,099
Inventories, at lower of cost or market	120,066	127,071
Prepaid expenses	39,427	63,604
Assets held for sale	23,248	27,070
Total current assets	1,447,157	1,559,183
Property, plant and equipment, at cost less accumulated depreciation, depletion and amortization of $12,027,902 in 2017 and $12,607,815 in 2016	8,283,738	8,316,188
Deferred income taxes	406,703	365,935
Deferred charges and other assets	55,161	54,554
Total assets	10,192,759	10,295,860
Current liabilities
Current maturities of long-term debt	9,781	569,817
Accounts payable	584,025	784,975
Income taxes payable	57,687	13,920
Other taxes payable	30,160	28,167
Other accrued liabilities	146,607	102,777
Liabilities associated with assets held for sale	3,270	2,776
Total current liabilities	831,530	1,502,432
Long-term debt, including capital lease obligation	2,908,285	2,422,750
Deferred income taxes	108,756	69,081
Asset retirement obligations	747,602	681,528
Deferred credits and other liabilities	616,452	617,490
Liabilities associated with assets held for sale		85,900
Stockholders' equity
Cumulative Preferred Stock, par $100, authorized 400,000 shares, none issued
Common Stock, par $1.00, authorized 450,000,000 shares, issued 195,055,724 shares in 2017 and 2016	195,056	195,056
Capital in excess of par value	910,936	916,799
Retained earnings	5,575,175	5,729,596
Accumulated other comprehensive loss	(425,504)	(628,212)
Treasury stock	(1,275,529)	(1,296,560)
Total stockholders' equity	4,980,134	4,916,679
Total liabilities and stockholders' equity	$ 10,192,759	$ 10,295,860

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	9 Months Ended	12 Months Ended
	Sep. 30, 2017	Dec. 31, 2016
Accounts receivable, allowance for doubtful accounts	$ 1,605	$ 1,605
Property, plant and equipment, accumulated depreciation, depletion and amortization	$ 12,027,902	$ 12,607,815
Cumulative Preferred Stock, par value (per share)	$ 100	$ 100
Cumulative Preferred Stock, authorized shares	400,000	400,000
Cumulative Preferred Stock, shares issued	0	0
Common Stock, par value (per share)	$ 1	$ 1
Common Stock, authorized shares	450,000,000	450,000,000
Common Stock, shares issued	195,055,724	195,055,724
Minimum [Member]
Maturity of Canadian government securities	90 days	90 days

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Revenues
Sales and other operating revenues	$ 498,202	$ 486,276	$ 1,552,473	$ 1,326,587
Gain (loss) on sale of assets	117	(730)	130,765	3,101
Total revenues	498,319	485,546	1,683,238	1,329,688
Costs and expenses
Lease operating expenses	112,751	119,663	346,072	435,296
Severance and ad valorem taxes	10,816	9,592	32,771	35,668
Exploration expenses	28,492	19,866	77,356	83,910
Selling and general expenses	56,672	55,523	168,259	196,143
Depreciation, depletion and amortization	243,636	255,900	714,782	797,288
Accretion of asset retirement obligations	10,654	11,043	31,638	35,514
Impairment of assets				95,088
Other expense (benefit)	2,454	6,486	10,988	(1,446)
Total costs and expenses	465,475	478,073	1,381,866	1,677,461
Operating income (loss) from continuing operations	32,844	7,473	301,372	(347,773)
Other income (loss)
Interest and other income (loss)	(47,721)	14,987	(93,524)	38,602
Interest expense, net	(48,681)	(39,219)	(138,423)	(103,889)
Total other loss	(96,402)	(24,232)	(231,947)	(65,287)
Income (loss) from continuing operations before income taxes	(63,558)	(16,759)	69,425	(413,060)
Income tax expense (benefit)	2,760	(2,176)	95,602	(201,897)
Loss from continuing operations	(66,318)	(14,583)	(26,177)	(211,163)
Income (loss) from discontinued operations, net of income taxes	425	(1,593)	1,177	(885)
NET LOSS	$ (65,893)	$ (16,176)	$ (25,000)	$ (212,048)
INCOME (LOSS) PER COMMON SHARE - BASIC
Continuing operations	$ (0.38)	$ (0.08)	$ (0.15)	$ (1.23)
Discontinued operations		(0.01)	0.01	(0.01)
Net loss	(0.38)	(0.09)	(0.14)	(1.24)
INCOME (LOSS) PER COMMON SHARE - DILUTED
Continuing operations	(0.38)	(0.08)	(0.15)	(1.23)
Discontinued operations		(0.01)	0.01	(0.01)
Net loss	(0.38)	(0.09)	(0.14)	(1.24)
Cash dividends per Common share	$ 0.25	$ 0.25	$ 0.75	$ 0.95
Average Common shares outstanding
Basic	172,572,873	172,199,350	172,509,418	172,164,683
Diluted	172,572,873	172,199,350	172,509,418	172,164,683

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) [Abstract]
Net loss	$ (65,893)	$ (16,176)	$ (25,000)	$ (212,048)
Other comprehensive income (loss), net of tax
Net gain (loss) from foreign currency translation	101,210	(37,369)	194,094	124,522
Retirement and postretirement benefit plans	2,396	2,515	7,169	7,544
Deferred loss on interest rate hedges reclassified to interest expense	482	482	1,445	1,445
Other comprehensive income (loss)	104,088	(34,372)	202,708	133,511
COMPREHENSIVE INCOME (LOSS)	$ 38,195	$ (50,548)	$ 177,708	$ (78,537)

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands		9 Months Ended
		Sep. 30, 2017	Sep. 30, 2016
Operating Activities
Net loss		$ (25,000)	$ (212,048)
Adjustments to reconcile net loss to net cash provided by continuing operations activities:
(Income) loss from discontinued operations		(1,177)	885
Depreciation, depletion and amortization		714,782	797,288
Impairment of assets			95,088
Amortization of deferred major repair costs			3,794
Dry hole costs (credits)		(1,139)	15,226
Amortization of undeveloped leases		40,859	35,828
Accretion of asset retirement obligations		31,638	35,514
Deferred and noncurrent income tax benefit		(3,567)	(345,157)
Pretax gains from disposition of assets		(130,765)	(3,101)
Net (increase) decrease in noncash operating working capital		1,070	(152,618)	[1]
Other operating activities, net		192,867	9,651
Net cash provided by continuing operations activities		819,568	280,350
Investing Activities
Property additions and dry hole costs		(706,417)	(781,668)	[2]
Proceeds from sales of property, plant and equipment		69,146	1,154,623
Purchases of investment securities	[3]	(212,661)	(651,218)
Proceeds from maturity of investment securities	[3]	320,828	712,863
Other investing activities, net			(7,229)
Net cash (required) provided by investing activities		(529,104)	427,371
Financing Activities
Borrowings of debt		541,772	541,444
Repayments of debt		(550,000)	(600,000)
Capital lease obligation payments		(14,687)	(7,808)
Withholding tax on stock-based incentive awards		(7,151)	(1,138)
Issue cost of debt facility			(13,971)
Cash dividends paid		(129,421)	(163,586)
Other financing activities, net			(20)
Net cash required by financing activities		(159,487)	(245,079)
Cash Flows from Discontinued Operations
Operating activities		12,134	2,830
Changes in cash included in current assets held for sale		(12,904)	(2,830)
Net change in cash and cash equivalents of discontinued operations		(770)
Effect of exchange rate changes on cash and cash equivalents		(5,797)	7,268
Net increase in cash and cash equivalents		124,410	469,910
Cash and cash equivalents at beginning of period		872,797	283,183
Cash and cash equivalents at end of period		$ 997,207	$ 753,093
[1]	2016 balance includes payments for deepwater rig contract exit of $266.6 million.
[2]	Includes costs of $206.7 million associated with acquisition of Kaybob Duvernay and Placid Montney.
[3]	Investments are Canadian government securities with maturities greater than 90 days at the date of acquisition.

CONSOLIDATED STATEMENTS OF CAS7

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Millions	3 Months Ended	9 Months Ended		12 Months Ended
	Jun. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Payments for deepwater rig exit costs			$ 266.6
Cost of acquired assets, cash paid	$ 206.7
Minimum [Member]
Maturity of Canadian government securities		90 days	90 days	90 days

CONSOLIDATED STATEMENTS OF STOC

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY - USD ($) $ in Thousands	Cumulative Preferred Stock [Member]	Common Stock [Member]	Capital In Excess Of Par Value [Member]	Retained Earnings [Member]	Accumulated Other Comprehensive Loss [Member]	Treasury Stock [Member]	Total
Balance at beginning of year at Dec. 31, 2015		$ 195,056	$ 910,074	$ 6,212,201	$ (704,542)	$ (1,306,061)
Foreign currency translation gain, net of income taxes					124,522		$ 124,522
Net loss for the period				(212,048)			(212,048)
Restricted stock transactions and other			(10,078)
Cash dividends				(163,586)
Retirement and postretirement benefit plans, net of income taxes					7,544		7,544
Sale of stock under employee stock purchase plan						389
Stock-based compensation			21,918
Other			(239)
Deferred loss on interest rate hedges reclassified to interest expense, net of income taxes					1,445		1,445
Awarded restricted stock, net of forfeitures						8,993
Balance at end of year at Sep. 30, 2016		195,056	921,675	5,836,567	(571,031)	(1,296,679)	5,085,588
Balance at beginning of year at Dec. 31, 2016		195,056	916,799	5,729,596	(628,212)	(1,296,560)	4,916,679
Foreign currency translation gain, net of income taxes					194,094		194,094
Net loss for the period				(25,000)			(25,000)
Restricted stock transactions and other			(26,553)
Cash dividends				(129,421)
Retirement and postretirement benefit plans, net of income taxes					7,169		7,169
Sale of stock under employee stock purchase plan						145
Stock-based compensation			20,767
Other			(77)
Deferred loss on interest rate hedges reclassified to interest expense, net of income taxes					1,445		1,445
Awarded restricted stock, net of forfeitures						20,886
Balance at end of year at Sep. 30, 2017		$ 195,056	$ 910,936	$ 5,575,175	$ (425,504)	$ (1,275,529)	$ 4,980,134

CONSOLIDATED STATEMENTS OF STO9

CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY (Parenthetical) - $ / shares	Sep. 30, 2017	Sep. 30, 2016
CONSOLIDATED STATEMENTS OF STOCKHOLDERS' EQUITY [Abstract]
Cumulative Preferred Stock, par value (per share)	$ 100	$ 100
Cumulative Preferred Stock, authorized shares	400,000	400,000
Cumulative Preferred Stock, shares issued	0	0
Common Stock, par value (per share)	$ 1	$ 1
Common Stock, authorized shares	450,000,000	450,000,000
Common Stock, shares issued	195,055,724	195,055,724
Treasury stock, shares	22,482,851	22,855,649

Nature of Business and Interim

Nature of Business and Interim Financial Statements	9 Months Ended
	Sep. 30, 2017
Nature of Business and Interim Financial Statements [Abstract]
Nature of Business and Interim Financial Statements	Note A – Nature of Business and Interim Financial Statements  NATURE OF BUSINESS – Murphy Oil Corporation is an international oil and gas company that conducts its business through various operating subsidiaries. The Company produces oil and natural gas in the United States, Canada and Malaysia and conducts oil and natural gas exploration activities worldwide.  INTERIM FINANCIAL STATEMENTS – 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 at September 30, 2017 and December 31, 2016, and the results of operations, cash flows and changes in stockholders’ equity for the interim periods ended September 30, 2017 and 2016, in conformity with accounting principles generally accepted in the United States of America (U.S.). In preparing the financial statements of the Company in conformity with accounting principles generally accepted in the U.S., management has made a number of estimates and assumptions related to the reporting of assets, liabilities, revenues, and expenses and the disclosure of contingent assets and liabilities. Actual results may differ from the estimates.  Financial statements and notes to consolidated financial statements included in this Form 10-Q report should be read in conjunction with the Company's 2016 Form 10-K report, as certain notes and other pertinent information have been abbreviated or omitted in this report. Financial results for the three-month and nine-month periods ended September 30, 2017 are not necessarily indicative of future results. Beginning in the period ended September 30, 2017, certain reclassifications in presentation have been made to the Consolidated Statements of Operations. The Company now presents a separate “Operating income (loss) from continuing operations” subtotal on the Consolidated Statements of Operations. Additionally, “Interest and other income (loss) , ” which includes foreign exchange gains and losses, has been reclassified from a component of total revenues and is now presented below Operating income (loss) from continuing operations. “Interest expense” and “Capitalized interest” have also been combined into the “Interest expense, net” line item and is now presented below Operating income (loss) from continuing operations. Previously reported periods have been changed to conform to the current period presentation. These reclassifications did not impact previously reported Income (loss) from continuing operations before income taxes, L oss from continuing operations, or Net Loss. 

Property, Plant and Equipment

Property, Plant and Equipment	9 Months Ended
	Sep. 30, 2017
Property, Plant And Equipment [Abstract]
Property, Plant and Equipment	Note B – Property, Plant and Equipment   Exploratory Wells  Under Financial Accounting Standards Board (FASB) guidance exploratory well costs should continue to be capitalized when the well has found a sufficient quantity of reserves to justify its completion as a producing well and the Company is making sufficient progress assessing the reserves and the economic and operating viability of the project.  At September 30, 2017, the Company had total capitalized exploratory well costs pending the determination of proved reserves of $178.4 million. The following table reflects the net changes in capitalized exploratory well costs during the nine-month periods ended September 30, 2017 and 2016.      (Thousands of dollars) 2017 2016  Beginning balance at January 1 $ 148,500 130,514  Additions pending the determination of proved reserves 51,614 847  Reclassifications to proved properties based on the determination of proved reserves (13,370) –  Capitalized exploratory well costs charged to expense (8,360) –  Other adjustments – (3,205)  Balance at September 30 $ 178,384 128,156   The capitalized well costs charged to expense during the first nine months of 2017 included the Marakas-01 well in Block SK314A, offshore Malaysia in which development of the well could not be justified due to noncommercial hydrocarbon quantities found and cha nge in development plan due to commodity prices. Note B – Property, Plant and Equipment (Contd.)  The following table provides an aging of capitalized exploratory well costs based on the date the drilling was completed for each individual well and the number of projects for which exploratory well costs have been capitalized. The projects are aged based on the last well drilled in the project.     September 30,  2017 2016  (Thousands of dollars) Amount No. of Wells No. of Projects Amount No. of Wells No. of Projects  Aging of capitalized well costs:  Zero to one year $ 41,609 3 2 $ 10,563 2 2  One to two years 8,430 2 2 53,101 3 3  Two to three years 43,197 1 1 31,627 2 –  Three years or more 85,148 7 1 32,865 4 –  $ 178,384 13 6 $ 128,156 11 5  Of the $136.8 million of exploratory well costs capitalized more than one year at September 30, 2017, $70.4 million is in Brunei, $43.2 million is in Vietnam and $23.2 million is in Malaysia. In all geographical areas, either further appraisal or development drilling is planned and/or development studies/plans are in various stages of completion.  Divestments  In January 2017, a Canadian subsidiary of the Company completed its disposition of the Seal field in Western Canada. Total cash consideration to Murphy upon closing of the transaction was approximately $49.0 million. Additionally, the buyer assumed the asset retirement obligation of approximately $85.9 million. A $132.4 million pretax gain was reported in the first quarter of 2017 related to the sale. Also, in 2017, a U.S. subsidiary of the Company completed its disposition of certain non-core properties in the Eagle Ford Shale area . Total cash consideration to Murphy upon closing of the transaction was approximately $19.4 million. There were no gain s or loss es recorded related to these sale s .  During the second quarter 2016, a Canadian subsidiary of the Company completed the sale of its five percent, non-operated working interest in Syncrude Canada Ltd. (“Syncrude”) asset to Suncor Energy Inc. (“Suncor”). The Company received net cash proceeds of $739.1 million and recorded an after-tax gain of $71.7 million in the nine-month period ended September 30, 2016 associated with the Syncrude divestiture.  During the second quarter 2016, a Canadian subsidiary of the Company completed a divestiture of natural gas processing and sales pipeline assets that support Murphy’s Montney natural gas fields in the Tupper area of northeastern British Columbia. A gain on sale of approximately $187.0 million was deferred and is being recognized over the next 19 years in the Canadian operating segment. The Company amortized approximately $5.3 million and $3.4 million of the deferred gain during the nine-month period s ended September 30, 2017 and 2016, respectively . The remaining deferred gain of $185.0 million was included as a component of deferred credits and other liabilities in the Compa ny’s Consolidated Balance Sheet as of September 30, 2017 .  Acquisitions  During the second quarter 2016, a Canadian subsidiary acquired a 70 percent operated working interest (WI) of Athabasca Oil Corporation’s (Athabasca) production, acreage, infrastructure and facilities in the Kaybob Duvernay lands, and a 30 percent non-operated WI of Athabasca’s production, acreage, infrastructure and facilities in the liquids rich Placid Montney lands in Alberta, the majority of which was unproved. Under the terms of the joint venture, the total consideration amounts to approximately $375.0 million of which Murphy paid $206.7 million in cash at closing, subject to normal closing adjustments, and an additional $168.0 million in the form of a carried interest on the Kaybob Duvernay property . As of September 30, 2017, $32.0 million of the carried interest had been paid . The carry is to be paid over a period of up to five years from 2016. Note B – Property, Plant and Equipment (Contd.)  Impairments  D eclines in future oil and gas prices in early 2016 led to impairments in certain of the Company’s producing properties and the nine-month period in 2016 included pretax non - cash impairment charges of $95.1 million to reduce the carrying values to their estimated fair values for the Terra Nova field offshore Canada and the Western Canada onshore heavy oil producing properties at Seal. The fair values were determined by internal discounted cash flow models using estimates of future production, prices from futures exchanges, costs, and a discount rate believed to be consistent with those used by principal market participants in the applicable region. See also Note J.  Other  The Company has an interest in the Kakap field in Block K Malaysia. The Kakap field is operated by another company and was jointly developed with the Gumusut field owned by others. As required by the agreements governing the field, a redetermination (unitization) review was required in 2016. In the fourth quarter 2016, the Company recorded $39.1 million in redetermination expense related to an expected reduction in the Company’s working interest covering the period from inception through year-end 2016 at Kakap. In February 2017, PETRONAS officially approved the redetermination that reduce d the Company’s working interest from 8.6% to approximately 6.7% effective April 1, 2017. The Company partially settled $21.8 million of the redetermination expense in cash in the second quarter of 2017. The Company currently expects to settle the remainder of the redetermination costs in future periods. It is possible that the final adjustment amount could be different than the current estimate. D ue to the change in working interest, the future payments under a capital lease of a floating, production and storage facility in the Kakap field are lower and the Company reduced the total debt recorded on the Consolidated Balance Sheet in the second quarter 2017 by approximately $56.7 million, with a similar reduction to Property, plant and equipment.

Discontinued Operations and Ass

Discontinued Operations and Assets Held for Sale	9 Months Ended
	Sep. 30, 2017
Discontinued Operations and Assets Held for Sale [Abstract]
Discontinued Operations and Assets Held for Sale	Note C – Discontinued Operations and Assets Held for Sale  The Company has accounted for its former U.K. and U.S. refining and marketing operations as discontinued operations for all periods presented. The results of operations associated with discontinued operations for the three-month and nine-month periods ended September 30, 2017 and 2016 were as follows:     Three Months Nine Months  Ended September 30, Ended September 30,  (Thousands of dollars) 2017 2016 2017 2016  Revenues (costs) $ 598 5 853 1,454  Income (loss) before income taxes 425 (1,593) 1,177 (885)  Income tax benefit – – – –  Income (loss) from discontinued operations $ 425 (1,593) 1,177 (885)  Certain reclassifications have been made to 2016 Revenues to align with current period presentation (see Note A).  The following table presents the carrying value of the major categories of assets and liabilities of U.K. refining and marketing operations and Seal operations in Canada reflected as held for sale on the company’s Consolidated Balance Sheets at September 30, 2017 and December 31, 2016.    September 30, December 31,  (Thousands of dollars) 2017 2016  Current assets  Cash $ 17,030 4,126  Accounts receivable 6,218 22,944  Total current assets held for sale $ 23,248 27,070  Current liabilities  Accounts payable $ 605 270  Refinery decommissioning cost 2,665 2,506  Total current liabilities associated with assets held for sale $ 3,270 2,776  Non-current liabilities  Asset retirement obligation - Seal asset $ – 85,900    Note C – Discontinued Operations and Assets Held for Sale ( Contd. )  The asset retirement obligation at December 31, 2016 relates to well and facility abandonment obligations at the Seal field in Canada which were assumed by the purchasing company upon the sale in January 2017.

Financing Arrangements and Debt

Financing Arrangements and Debt	9 Months Ended
	Sep. 30, 2017
Financing Arrangements and Debt [Abstract]
Financing Arrangements and Debt	 Note D – Financing Arrangements and Debt  At September 30, 2017, the Company has a $1.1 billion senior unsecured guaranteed credit facility (2016 facility) with a major banking consortium, which expires in August 2019 . At September 30, 2017, the Company had no outstanding borrowings under the 2016 facility , however, there were $84.8 million of outstanding letters of credit , which reduce the borrowing capacity of the 2016 facility . Advances under the 2016 facility will accrue interest based, at the Company’s option, on either the London Interbank Offered rate plus an applicable margin (Eurodollar rate) or the alternate base rate (as defined in the 2016 facility agreement) plus an applicable margin. Had there been any amounts borrowed under the 2016 facility at September 30, 2017, the applicable base interest rate would have been 4.50% . At September 30, 2017, the Company was in compliance with all covenants related to the 2016 facility.  The Company also has a shelf registration statement on file with the U.S. Securities and Exchange Commission that permits the offer and sale of debt and/or equity securities through October 2018.  In August 2017, the Company sold $550 million of new notes that bear interest at the rate of 5.75% and mature on August 15, 2025 . The Company incurred transaction costs of $8.2 million on the issue of these new notes. The new notes pay interest semi-annually on February 15 and August 15 of each year. The initial interest payment will be paid on February 15, 2018. The proceeds of the $550 million notes were used to redeem the Company’s 2.50% n otes in September 2017 . The 2.50% n otes had an original maturity of December 2017.  In August 2016, the Company reduced its then existing $2.0 billion unsecured revolving credit facility (2011 facility) to $630 million (facility has since expired) and entered into a separate $1.2 billion senior unsecured guaranteed credit facility (2016 facility , subsequently reduced to $1.1 billion ) , with a major banking consortium that expires in August 2019. The Company incurred transaction costs of approximately $14.0 million to place the 2016 facility which were included in financing activities in the Consolidated Statement of Cash Flows. Also in August 2016, the Company sold $550 million of notes that bear interest at the rate of 6.875% and mature on August 15, 2024 . The proceeds of the $550 million notes were used for general corporate purposes.  The Company and its partners are parties to a 25 -year lease of production equipment at the Kakap field offshore Malaysia. The lease has been accounted for as a capital lease, and payments under the agreement are to be made over a 15 -year period through March 2029 . Current maturities of long-term debt and long-term debt on the Consolidated Balance Sheet include d $9.8 million and $136.5 million, respectively, associated with this lease at September 30, 2017.

Other Financial Information

Other Financial Information	9 Months Ended
	Sep. 30, 2017
Other Financial Information [Abstract]
Other Financial Information	Note E – Other Financial Information  Additional disclosures regarding cash flow activities are provided below.    Nine Months Ended September 30,  (Thousands of dollars) 2017 2016  Net (increase) decrease in operating working capital other than cash and cash equivalents:  Decrease in accounts receivable $ 90,614 75,841  Decrease (increase) in inventories 5,869 (15,768)  Decrease in prepaid expenses 25,285 122,399  Decrease in other – 720  Decrease in accounts payable and accrued liabilities (115,977) (376,310) *  (Decrease) increase in current income tax liabilities (4,721) 40,500  Net (increase) decrease in noncash operating working capital $ 1,070 (152,618)  Supplementary disclosures:  Cash income taxes paid, net of refunds $ 25,118 (3,911)  Interest paid, net of amounts capitalized of $3,338 in 2017 and $3,318 in 2016 95,899 52,287   Non-cash investing activities:  Asset retirement costs capitalized $ 38,992 13,959  Decrease in capital expenditure accrual 42,403 179,203   * 2016 balance included payments for deepwater rig contract exit of $266.6 million.

Employee and Retiree Benefit Pl

Employee and Retiree Benefit Plans	9 Months Ended
	Sep. 30, 2017
Employee and Retiree Benefit Plans [Abstract]
Employee and Retiree Benefit Plans	 Note F – Employee and Retiree Benefit Plans  The Company has defined benefit pension plans that are principally noncontributory and cover most North American full-time employees. All pension plans are funded except for the U.S. nonqualified supplemental plan. All U.S. tax qualified plans meet the funding requirements of federal laws and regulations. Contributions to foreign plans are based on local laws and tax regulations. The Company also sponsors health care and life insurance benefit plans, which are not funded, that cover most active and retired U.S. employees. The health care benefits are contributory; the life insurance benefits are noncontributory.  The table that follows provides the components of net periodic benefit expense for the three-month and nine-month periods ended September 30, 2017 and 2016.      Three Months Ended September 30,  Pension Benefits Other Postretirement Benefits  (Thousands of dollars) 2017 2016 2017 2016  Service cost $ 2,037 2,610 427 674  Interest cost 7,261 5,913 966 1,109  Expected return on plan assets (8,070) (6,626) – –  Amortization of prior service cost (credit) 259 323 (18) (21)  Amortization of transitional asset – – – 2  Recognized actuarial loss 3,610 3,617 – 38  Net periodic benefit expense $ 5,097 5,837 1,375 1,802   Nine Months Ended September 30,  Pension Benefits Other Postretirement Benefits  (Thousands of dollars) 2017 2016 2017 2016  Service cost $ 6,099 8,533 1,276 2,022  Interest cost 20,267 20,386 2,899 3,324  Expected return on plan assets (21,730) (21,709) – –  Amortization of prior service cost (credit) 767 963 (55) (62)  Amortization of transitional asset – – – 4  Recognized actuarial loss 10,673 10,864 – 113  Curtailments – 822 – (19)  Net periodic benefit expense $ 16,076 19,859 4,120 5,382  Curtailment expense for the nine months ended September 30, 2016, shown in the table above, relates to restructuring activities in the U.S. undertaken by the Company in the first quarter of 2016.  During the nine-month period ended September 30, 2017, the Company made contributions of $24.0 million to its defined benefit pension and postretirement benefit plans. Remaining required funding in 2017 for the Company’s defined benefit pension and postretirement plans is anticipated to be $6.8 million.

Incentive Plans

Incentive Plans	9 Months Ended
	Sep. 30, 2017
Incentive Plans [Abstract]
Incentive Plans	Note G – Incentive Plans  The costs resulting from all share-based and cash-based incentive plans payment transactions are recognized as an expense in the Consolidated Statements of Operations using a fair value-based measurement method over the periods that the awards vest.  The 2012 Annual Incentive Plan (2012 Annual Plan) authorizes the Executive Compensation Committee (the Committee) to establish specific performance goals associated with annual cash awards that may be earned by officers, executives and certain other employees. Cash awards under the 2012 Annual Plan are determined based on the Company’s actual financial and operating results as measured against the performance goals established by the Committee. The 2012 Long-Term Incentive Plan (2012 Long-Term Plan) authorizes the Committee to make grants of the Company’s Common Stock to employees. These grants may be in the form of stock options (nonqualified or incentive), stock appreciation rights (SAR), restricted stock, restricted stock units (RSU), performance units, performance shares, dividend equivalents and other stock-based incentives. The 2012 Long-Term Plan expires in 2022 . A total of 8,700,000 shares are issuable during the life of the 2012 Long-Term Plan, with annual grants limited to 1% of Common shares outstanding; allowed shares not granted in an earlier year may be granted in future years. The Company also has a 2013 Stock Plan for Non-Employee Directors (Director Plan) that permits the issuance of restricted stock, restricted stock units and stock options or a combination thereof to the Company’s Non-Employee Directors.  The Company had an Employee Stock Purchase Plan (ESPP) that permitted the issuance of Company shares during 2016 and the first six months of 2017. The ESPP terminated on June 30, 2017 and was not renewed by the Company.  In February 2017, the Committee granted stock options for 599,000 shares at an exercise price of $ 28.505 per share. The Black-Scholes valuation for these awards was $7.96 per option. The Committee also granted 556,000 performance-based RSU and 282,000 time-based RSU in February 2017. The fair value of the performance-based RSU, using a Monte Carlo valuation model , ranged from $24.10 to $28.28 per unit. The fair value of time-based RSU was estimated based on the fair market value of the Company’s stock on the date of grant, which was $28.505 per share. Additionally, the Committee granted 329,400 SAR and 154,150 units of cash-settled RSU (RSUC) to certain employees. The SAR and RSUC are to be settled in cash, net of applicable income taxes, and are accounted for as liability-type awards. The initial fair value of these SAR was equivalent to the stock options granted, while the initial value of RSUC was equivalent to equity-settled restricted stock units granted. Also in February, the Committee granted 83,220 shares of time-based RSU to the Company’s Directors under the Non-Employee Director Plan. These shares vest on the third anniversary of the date of grant. The estimated fair value of these awards was $28.84 per unit on date of grant.  For all periods presented, the Company had no stock options exercised.  Amounts recognized in the financial statements with respect to share-based plans are shown in the following table:      Nine Months Ended  September 30,  (Thousands of dollars) 2017 2016  Compensation charged against income (loss) before tax benefit $ 28,264 35,948  Related income tax benefit recognized in income 8,695 11,796 

Earnings per Share

Earnings per Share	9 Months Ended
	Sep. 30, 2017
Earnings per Share [Abstract]
Earnings per Share	Note H – Earnings per Share  Net loss was used as the numerator in computing both basic and diluted income per Common share for the three-month and nine-month periods ended September 30, 2017 and 2016. The following table reconciles the weighted-average shares outstanding used for these computations.     Three Months Ended Nine Months Ended  September 30, September 30,  (Weighted-average shares) 2017 2016 2017 2016  Basic method 172,572,873 172,199,350 172,509,418 172,164,683  Dilutive stock options and restricted stock units* – – – –  Diluted method 172,572,873 172,199,350 172,509,418 172,164,683   * Due to net losses recognized by the Company for all periods presented, no unvested stock awards were included in the computation of diluted earnings per share because the effect would have been anti-dilutive.     Three Months Ended Nine Months Ended  September 30, September 30,  2017 2016 2017 2016  Antidilutive stock options excluded from diluted shares 5,257,718 5,884,201 5,578,495 5,822,036  Weighted average price of these options $ 46.46 $ 49.00 $ 46.86 $ 49.82 

Income Taxes

Income Taxes	9 Months Ended
	Sep. 30, 2017
Income Taxes [Abstract]
Income Taxes	Note I – Income Taxes  The Company’s effective income tax rate is calculated as the amount of income tax expense (benefit) divided by income (loss) before income tax expense. For the three-month and nine-month periods ended September 30, 2017 and 2016, the Company’s effective income tax rates were as follows:     2017 2016  Three months ended September 30 (4.3%) 13.0%  Nine months ended September 30 137.7% 48.9%  The effective tax rates for most periods where earnings are generated, generally exceed the U.S. statutory tax rate of 35% due to several factors, including: the effects of income generated in foreign tax jurisdictions, certain of which have income tax rates that are higher than the U.S. Federal rate; U.S. state tax expense; and certain expenses, including exploration and other expenses in certain foreign jurisdictions, for which no income tax benefits are available or are not presently being recorded due to a lack of reasonable certainty of adequate future revenue against which to utilize these expenses as deductions. Conversely, the effective tax rates for most periods where losses are incurred generally are lower than U.S. statutory tax rate of 35% due to similar reasons.  The effective tax rate for the three-month period ended September 30, 2017 was below the U.S. statutory tax rate of 35% primarily due to the tax effect of expenses in foreign jurisdictions not fully deductible from losses at the U.S. statutory tax rate , an estimated U.S. tax charge for undistributed foreign earnings and Canadian foreign exchange losses not fully deductible at 35%. These impacts were partially offset by the U.S. tax benefit recognized from the reversal of an uncertain tax position for federal tax years 2011-2013.  The effective tax rate for the nine-month period ended September 30, 2017 was above the U.S. statutory tax rate of 35% primarily due to an estimated U.S. tax charge for undistributed foreign earnings and Canadian foreign exchange losses. These impacts were partially offset by the U.S. tax benefit recognized from the reversal of an uncertain tax position for federal tax years 2011-2013 and other items. During the first nine-months of 2017, the Company determined that prospective earnings from its Malaysian and Canadian subsidiaries will not be considered reinvested into local operations. Due to this change in assertion, the Company recorded a deferred tax charge of $65.2 million in the nine-month period 2017 associated with the estimated tax consequence of the future repatriation of these subsidiaries earnings during the first nine months 2017. This decision provides greater financial flexibility as it considers future domestic investment opportunities. The Company expects to incur further tax charges in the fourth quarter 2017 for additional 2017 foreign earnings as they arise.     Note I – Income Taxes ( Contd.)  The effective tax rate for the three-month period ended September 30, 2016 was less than the U.S. statutory tax rate primarily due to expenses in foreign jurisdictions for which no tax benefits were recognized. The effective tax rate for the nine-month period ended September 30, 2016 was above the U.S. statutory tax rate primarily due to deferred tax benefits recognized related to the Canadian asset dispositions and income tax benefits on investments in foreign areas.  The Company’s tax returns in multiple jurisdictions are subject to audit by taxing authorities. These audits often take years to complete and settle. Although the Company believes that recorded liabilities for unsettled issues are adequate, additional gains or losses could occur in future years from resolution of outstanding unsettled matters. As of September 30, 2017 , the earliest years remaining open for audit and/or settlement in our major taxing jurisdictions are as follows: United States – 2014 ; Canada – 2012 ; Malaysia – 20 10 ; and United Kingdom – 2015 .

Financial Instruments and Risk

Financial Instruments and Risk Management	9 Months Ended
	Sep. 30, 2017
Financial Instruments and Risk Management [Abstract]
Financial Instruments and Risk Management	Note J – Financial Instruments and Risk Management  Murphy often uses derivative instruments to manage certain risks related to commodity prices, foreign currency exchange rates and interest 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 speculative 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, such as the New York Mercantile Exchange (NYMEX). The Company has a risk management control system to monitor commodity price risks and any derivatives obtained to manage a portion of such risks. For accounting purposes, the Company has not designated commodity and foreign currency derivative contracts as hedges, and therefore, it recognizes all gains and losses on these derivative contracts in its Consolidated Statements of Operations. Certain interest rate derivative contracts were accounted for as hedges and the gain or loss associated with recording the fair value of these contracts was deferred in Accumulated Other Comprehensive Loss until the anticipated transactions occur. This deferred cost is being reclassified to Interest e xpense , net in the Consolidated Statements of Operations over the period until the associated notes mature in 2022.  Commodity Purchase Price Risks  The Company is subject to commodity price risk related to crude oil it produces and sells. During the first nine months 2017 and 2016, the Company had West Texas Intermediate (WTI) crude oil swap financial contracts to economically hedge a portion of its United States production. Under these contracts, which matured monthly, the Company paid the average monthly price in effect and received the fixed contract prices. At September 30, 2017, the Company had 22,000 barrels per day in WTI crude oil swap financial contracts maturing ratably during the remainder of 2017 at an average price of $50.41 and 6,000 barrels per day in WTI crude oil swap financial contracts maturing ratably during 2018 at an average price of $51.83 . At September 30, 2017, the fair value of WTI contracts of $3.2 million was included in Accounts Payable. The impact of marking to market these commodity derivative contracts increased the loss before income taxes by $3 .2 million for the nine-month period ended September 30, 2017.  At September 30, 2016, the Company had 25,000 barrels per day in WTI crude oil swap financial contracts maturing ratably during 2016. At September 30, 2016, the fair value of WTI contracts of $0.2 million was included in Accounts Receivable. The impact of marking to market these 2016 commodity derivative contracts decreased the loss before income taxes by $3.9 million for the nine-month period ended September 30, 2016. Note J – Financial Instruments and Risk Management (Contd.)  Foreign Currency Exchange Risks  The Company is subject to foreign currency exchange risk associated with operations in countries outside the U.S. The Company had no foreign currency exchange short-term derivatives outstanding at September 30, 2017.  At September 30, 2016, short-term derivative instruments were outstanding in Canada for approximately $25.2 million, to manage the currency risks of certain U.S. dollar accounts receivable associated with sale of Canadian crude oil. The fair values of open foreign currency derivative contracts were assets of $0.1 million at September 30, 2016.  At September 30, 2017 and December 31, 2016, the fair value of derivative instruments not designated as hedging instruments are presented in the following table.      September 30, 2017 December 31, 2016  (Thousands of dollars) Asset (Liability) Derivatives Asset (Liability) Derivatives  Type of Derivative Contract Balance Sheet Location Fair Value Balance Sheet Location Fair Value  Commodity Accounts payable $ (3,226) Accounts payable $ (48,864)  Foreign exchange Accounts receivable – Accounts payable (73)  For the three-month and nine-month periods ended September 30, 2017 and 2016, the gains and losses recognized in the Consolidated Statements of Operations for derivative instruments not designated as hedging instruments are presented in the following table.      Gain (Loss)  Three Months Ended Nine Months Ended  (Thousands of dollars) September 30, September 30,  Type of Derivative Contract Statement of Operations Location 2017 2016 2017 2016  Commodity Sales and other operating revenues $ (13,573) 11,871 50,365 (22,678)  Foreign exchange Interest and other income (loss) – 143 73 26,929  $ (13,573) 12,014 50,438 4,251 Interest Rate Risks  Under hedge accounting rules, the Company deferred the net cost associated with derivative contracts purchased to manage interest rate risk associated with 10-year notes sold in May 2012 to match the payment of interest on these notes through 2022. During each of the nine-month periods ended September 30, 2017 and 2016, $2.2 million of the deferred loss on the interest rate swaps was charged to Interest expense in the Consolidated Statement of Operations. The remaining loss deferred on these matured contracts at September 30, 2017 was $8 .9 million, which is recorded, net of income taxes of $4.8 million, in Accumulated other comprehensive loss in the Consolidated Balance Sheet. The Company expects to charge approximately $0.7 million of this deferred loss to Interest expense , net in the Consolidated Statement of Operations during the remaining three months of 2017.  Note J – Financial Instruments and Risk Management (Contd.)  Fair Values – Recurring  The Company carries certain assets and liabilities at fair value in its Consolidated Balance Sheets. The fair value hierarchy is based on the quality of inputs used to measure fair value, with Level 1 being the highest quality and Level 3 being the lowest quality. Level 1 inputs are quoted prices in active markets for identical assets or liabilities. Level 2 inputs are observable inputs other than quoted prices included within Level 1. Level 3 inputs are unobservable inputs which reflect assumptions about pricing by market participants.  The carrying value of assets and liabilities recorded at fair value on a recurring basis at September 30, 2017 and December 31, 2016 are presented in the following table.      September 30, 2017 December 31, 2016  (Thousands of dollars) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total  Liabilities:  Nonqualified employee savings plans $ 15,161 – – 15,161 13,904 – – 13,904  Commodity derivative contracts – 3,226 – 3,226 – 48,864 – 48,864  Foreign currency exchange derivative contracts – – – – – 73 – 73  $ 15,161 3,226 – 18,387 13,904 48,937 – 62,841    The fair value of WTI crude oil derivative contracts in 2017 and 2016 was based on active market quotes for WTI crude oil. The fair value of foreign exchange derivative contracts in each year was based on market quotes for similar contracts at the balance sheet dates. The income effect of changes in the fair value of crude oil derivative contracts is recorded in Sales and other operating revenues in the Consolidated Statements of Operations, while the effects of changes in fair value of foreign exchange derivative contracts is recorded in Interest and other income. The nonqualified employee savings plan is an unfunded savings plan through which participants seek a return via phantom investments in equity securities and/or mutual funds. The fair value of this liability was based on quoted prices for these equity securities and mutual funds. The income effect of changes in the fair value of the nonqualified employee savings plan is recorded in Selling and general expenses in the Consolidated Statements of Operations.  The Company offsets certain assets and liabilities related to derivative contracts when the legal right of offset exists. There were no offsetting positions recorded at September 30, 2017 and December 31, 2016. Note J – Financial Instruments and Risk Management (Contd.)  Fair Values – Nonrecurring  As a result of the fall in forward commodity prices during the first nine-month period ended September 30, 2016, the Company recognized approximately $95.1 million in pretax non - cash impairment charges related to producing properties. The fair value information associated with these impaired properties is presented in the following table.     Nine-months ended September 30, 2016  Total  Net Book Pretax  Value (Noncash)  Fair Value Prior to Impairment  Level 1 Level 2 Level 3 Impairment Expense  (Thousands of dollars)  Assets:  Impaired proved properties  Canada $ – – 71,967 167,055 95,088  The fair values were determined by internal discounted cash flow models using estimates of future production, prices from futures exchanges, costs and a discount rate believed to be consistent with those used by principal market participants in the applicable region.

Accumulated Other Comprehensive

Accumulated Other Comprehensive Loss	9 Months Ended
	Sep. 30, 2017
Accumulated Other Comprehensive Loss [Abstract]
Accumulated Other Comprehensive Loss	Note K – Accumulated Other Comprehensive Loss  The components of Accumulated Other Comprehensive Loss on the Consolidated Balance Sheets at December 31, 2016 and September 30, 2017 and the changes during the nine-month period ended September 30, 2017 are presented net of taxes in the following table.    Deferred  Loss on  Foreign Retirement and Interest  Currency Postretirement Rate  Translation Benefit Plan Derivative  (Thousands of dollars) Gains (Losses) Adjustments Hedges Total  Balance at December 31, 2016 $ (446,555) (171,305) (10,352) (628,212)  2017 components of other comprehensive income (loss):  Before reclassifications to income 194,094 3 – 194,097  Reclassifications to income – 7,166 1 1,445 2 8,611  Net other comprehensive income 194,094 7,169 1,445 202,708  Balance at September 30, 2017 $ (252,461) (164,136) (8,907) (425,504)  1 Reclassifications before taxes of $11,039 for the nine-month period ended September 30, 2017 are inc luded in the computation of net periodic benefit expense. See Note G for additional information. Related income taxes of $3,873 for the nine-month period ended September 30, 2017 are included in Income tax expense. 2 Reclassifications before taxes of $2,222 for the nine-month period ended September 30, 2017 are included in Interest expense , net . Related income taxes of $777 for the nine-month period ended September 30, 2017 are included in Income tax expense .

Environmental and Other Conting

Environmental and Other Contingencies	9 Months Ended
	Sep. 30, 2017
Environmental and Other Contingencies [Abstract]
Environmental and Other Contingencies	Note L – Environmental and Other Contingencies  The Company’s operations and earnings have been and may be affected by various 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, tax rate changes and retroactive tax claims; royalty and revenue sharing changes; 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 and the protection and/or remediation of the environment; governmental support for other forms of energy; and laws and regulations affecting the Company’s relationships with employees, suppliers, customers, stockholders and others. 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. Note L – Environmental and Other Contingencies ( Contd .)  Murphy and other companies in the oil and gas industry are subject to numerous federal, state, local and foreign laws and regulations dealing with the environment. Violation of federal or state environmental laws, regulations and permits can result in the imposition of significant civil and criminal penalties, injunctions and construction bans or delays. A discharge of hazardous substances into the environment could, to the extent such event is not insured, subject the Company to substantial expense, including both the cost to comply with applicable regulations and claims by neighboring landowners and other third parties for any personal injury and property damage that might result.  The Company currently owns or leases, and has in the past owned or leased, properties at which hazardous substances have been or are being handled. Although the Company has used operating and disposal practices that were standard in the industry at the time, hazardous substances may have been disposed of or released on or under the properties owned or leased by the Company or on or under other locations where these wastes have been taken for disposal. In addition, many of these properties have been operated by third parties whose treatment and disposal or release of hydrocarbons or other wastes were not under Murphy’s control. Under existing laws the Company could be required to remove or remediate previously disposed wastes (including wastes disposed of or released by prior owners or operators), to clean up contaminated property (including contaminated groundwater) or to perform remedial plugging operations to prevent future contamination. Certain of these historical properties are in various stages of negotiation, investigation, and/or cleanup and the Company is investigating the extent of any such liability and the availability of applicable defenses. The Company has retained certain liabilities related to environmental matters at formerly owned U.S. refineries that were sold in 2011. The Company also obtained insurance covering certain levels of environmental exposures related to past operations of these refineries. The Company has not retained any environmental exposure associated with Murphy’s former U.S. marketing operations. The Company believes costs related to these sites will not have a material adverse effect on Murphy’s net income, financial condition or liquidity in a future period.  During 2015, the Company’s subsidiary in Canada identified a leak or leaks at an infield condensate transfer pipeline at the Seal field in a remote area of Alberta. The pipeline was immediately shut down and the Company’s emergency response plan was activated. In cooperation with local governmental regulators, and with the assistance of qualified consultants, an investigation and remediation plan is progressing as planned and the Company’s insurers were notified. Based on the assessments done, the Company recorded $43.9 million in Other expense during 2015 associated with the estimated costs of remediating the site . As of September 30, 2017, the Company has a remaining accrued liability of $5.8 million associated with this event. During the first nine months of 2017, the Company’s Canadian subsidiary paid approximately $130 thousand as the complete and final resolution of administrative penalties assessed by the Alberta Energy Regulator regarding this matter. Further refinements in the estimated total cost to remediate the site are anticipated in future periods including possible insurance recoveries. It is possible that the ultimate net remediation costs to the Company associated with the condensate leak or leaks will exceed the amount of liability recorded. The Company retained the responsibility for this remediation upon sale of the Seal field in the first quarter of 2017.  There is the possibility that environmental expenditures could be required at currently unidentified sites, and new or revised regulations could require additional expenditures at known sites. However, based on information currently available to the Company, the amount of future remediation costs incurred at known or currently unidentified sites is not expected to have a material adverse effect on the Company’s future net income, cash flows or liquidity.  Murphy and its subsidiaries are engaged in a number of other legal proceedings, all of which Murphy considers routine and incidental to its business. Based on information currently available to the Company, the ultimate resolution of environmental and legal matters referred to in this note is not expected to have a material adverse effect on the Company’s net income, financial condition or liquidity in a future period. 

Commitments

Commitments	9 Months Ended
	Sep. 30, 2017
Commitments [Abstract]
Commitments	Note M – Commitments  The Company has entered into forward sales contracts to mitigate the price risk for a portion of its 2017 to 2020 natural gas sales volumes in Western Canada. During the period from October to December 2017 the natural gas sales contracts call for deliveries of 124 million cubic feet per day at Cdn $2.97 per MCF. During the period from January 2018 through December 2020 the natural gas sales contracts call for deliveries of 59 million cubic feet per day at Cdn $2.81 per MCF. During the period from November 2017 through March 2018 the natural gas sales contracts call for deliveries of 20 million cubic feet per day at US $3.51 per MCF.  These natural gas contracts have been accounted for as normal sales for accounting purposes.

Business Segments

Business Segments	9 Months Ended
	Sep. 30, 2017
Business Segments [Abstract]
Business Segments	Note N – Business Segments  Information about business segments and geographic operations is reported in the following tables. For geographic purposes, revenues are attributed to the country in which the sale occurs. Corporate, including interest income, miscellaneous gains and losses (including foreign exchange gains and losses), interest expense and unallocated overhead, is shown in the tables to reconcile the business segments to consolidated totals. Certain reclassifications have been made to 2016 Corporate External Revenue to align with current period presentation (see Note A) .    Three Months Ended Three Months Ended  Total Assets September 30, 2017 September 30, 2016  at September 30, External Income External Income  (Millions of dollars) 2017 Revenues (Loss) Revenues (Loss)  Exploration and production*  United States $ 5,439.1 195.9 (19.9) 201.8 (27.1)  Canada 1,711.1 81.9 (3.2) 80.9 (4.8)  Malaysia 1,755.3 220.5 67.7 202.7 65.0  Other 139.9 – (11.0) 0.2 (8.1)  Total exploration and production 9,045.4 498.3 33.6 485.6 25.0  Corporate 1,124.2 – (99.9) (0.1) (39.6)  Assets/revenue/loss from continuing operations 10,169.6 498.3 (66.3) 485.5 (14.6)  Discontinued operations, net of tax 23.2 – 0.4 – (1.6)  Total $ 10,192.8 498.3 (65.9) 485.5 (16.2)   Nine Months Ended Nine Months Ended  September 30, 2017 September 30, 2016  External Income External Income  (Millions of dollars) Revenues (Loss) Revenues (Loss)  Exploration and production*  United States $ 696.7 11.0 520.2 (158.5)  Canada 388.1 102.6 264.4 (36.9)  Malaysia 594.4 173.9 541.4 135.1  Other – (10.9) 0.2 (39.2)  Total exploration and production 1,679.2 276.6 1,326.2 (99.5)  Corporate 4.0 (302.8) 3.5 (111.7)  Revenue/loss from continuing operations 1,683.2 (26.2) 1,329.7 (211.2)  Discontinued operations, net of tax – 1.2 – (0.8)  Total $ 1,683.2 (25.0) 1,329.7 (212.0)  * Additional details about results of oil and gas operations are presented in the tables on pages 29 and 30 .

New Accounting Principles Adopt

New Accounting Principles Adopted	9 Months Ended
	Sep. 30, 2017
New Accounting Principles Adopted and Recent Accounting Pronouncements [Abstract]
New Accounting Principles	 Note O – New Accounting Principles Adopted  Business Combinations  In January 2017, the Financial Accounting Standards Board (FASB) issued an Accounting Standards Update (ASU) to clarify the definition of a business to assist entities in evaluating whether transactions should be accounted for as acquisitions (or disposals) of assets or businesses. The standard is intended to narrow the definition of a business by specifying the minimum inputs and processes and by narrowing the definition of outputs. The update is effective for annual periods beginning after December 15, 2017, including interim periods within those periods. The prospective approach is required for adoption and early adoption is permitted for transactions not previously reported in issued financial statements. The Company adopted this guidance in 2017 and it did not have a material impact on its consolidated financial statements and footnote disclosures . Note O – New Accounting Principles Adopted ( Contd .)  Compensation – Stock Compensation  In March 2016, the FASB issued an ASU intended to simplify the accounting for share-based payment transactions, including the income tax consequences, classification of awards as either equity or liabilities, and classification within the statement of cash flows. The amendments in this ASU were effective for annual periods beginning after December 15, 2016, and interim periods within those annual periods. The Company adopted this guidance in 2017 and it did not have a material impact on its consolidated financial statements and footnote disclosures as there were no exercises of Company options during the period. 

Recent Accounting Pronouncement

Recent Accounting Pronouncements	9 Months Ended
	Sep. 30, 2017
New Accounting Principles Adopted and Recent Accounting Pronouncements [Abstract]
Recent Accounting Pronouncements	Note P – Recent Accounting Pronouncements  Compensation – Stock Compensation  In May 2017, FASB issued an ASU which amends the scope of modification accounting for share-based payment arrangements and provides guidance on the type of changes to the terms and conditions of share-based payment awards to which an entity would be required to apply modification accounting. The update is effective for annual periods beginning after December 15, 2017 and interim periods within the annual period. Early adoption is permitted. The Company does not believe the application of this accounting standard will have a material impact on its consolidated financial statements.  Compensation – Retirement Benefits  In March 2017, the FASB issued an ASU requiring that the service cost component of pension and postretirement benefit costs be presented in the same line item as other current employee compensation costs and other components of those benefit costs be presented separately from the service cost component and outside a subtotal of income from operations, if presented. The update also requires that only the service cost component of pension and postretirement benefit cost is eligible for capitalization. The update is effective for annual periods beginning after December 15, 2017 and interim periods within the annual period. Application is retrospective for the presentation of the components of these benefit costs and prospective for the capitalization of only service costs. Early adoption is permitted. The Company does not believe the application of this accounting standard will have a material impact on its consolidated financial statements.  Revenue from Contracts with Customers  In May 2014, the FASB issued an ASU to establish a comprehensive new revenue recognition standard for contracts with customers that will supersede most current revenue recognition requirements and industry-specific guidance. The codification was amended through additional ASU’s and, as amended, requires an entity to recognize revenue when it transfers promised goods or services to customers in an amount that reflects the consideration the entity expects to be entitled to in exchange for those goods or services. Additional disclosures will be required to describe the nature, amount, timing and uncertainly of revenue and cash flows from contracts with customers. The Company is required to adopt the new standard in the first quarter of 2018 using either the modified retrospective or cumulative effect transition method. The Company has performed a review of contracts in each of its revenue streams and is developing accounting policies and applicable disclosures to address the provisions of the ASU . While the Company does not currently expect net earnings to be materially impacted, the Company is analyzing whether total revenues and expenses will be significantly impacted. The Company continues to evaluate the impact of this and other provisions of these ASU’s on its accounting policies, internal controls, and consolidated financial statements and related disclosures, and has not finalized any estimates of the potential impacts. The Company will adopt the new standard on January 1, 2018, using the modified retrospective method with a cumulative adjustment to retained earnings as necessary.  Leases  In February 2016, FASB issued an ASU to increase transparency and comparability among companies by recognizing lease assets and lease liabilities on the balance sheet and disclosing key information about leasing arrangements. The main difference between previous Generally Accepted Accounting Principles (GAAP) and this ASU is the recognition of right-of-use assets and lease liabilities by lessees for those leases classified as operating leases under previous GAAP. The new standard is effective for financial statements issued for annual periods beginning after December 15, 2018 and interim periods within those annual periods. Early adoption is permitted for all entities. The Company anticipates adopting this guidance in the first quarter of 2019 and is currently analyzing its portfolio of contracts to assess the impact future adoption of this ASU may have on its consolidated financial statements. Note P – Recent Accounting Pronouncements ( Contd .)  Statement of Cash Flows  In August 2016, the FASB issued an ASU to reduce diversity in practice in how certain transactions are classified in the statement of cash flows. The amendment provides guidance on specific cash flow issues including debt prepayment or debt extinguishment costs, settlement of zero-coupon debt instruments or other debt instrument with coupon interest rates that are insignificant in relation to the effective interest rate of the borrowing, contingent consideration payments made after a business combination, proceeds from the settlement of insurance claims, proceeds from the settlement of corporate-owned life insurance policies, and distributions received from equity method investees. The ASU is effective for annual and interim periods beginning after December 15, 2017. The Company is currently assessing the potential impact of this ASU on its consolidated financial statements.

Nature of Business and Interi26

Nature of Business and Interim Financial Statements (Policies)	9 Months Ended
	Sep. 30, 2017
Nature of Business and Interim Financial Statements [Abstract]
Nature of Business	NATURE OF BUSINESS – Murphy Oil Corporation is an international oil and gas company that conducts its business through various operating subsidiaries. The Company produces oil and natural gas in the United States, Canada and Malaysia and conducts oil and natural gas exploration activities worldwide.

Property, Plant and Equipment (

Property, Plant and Equipment (Tables)	9 Months Ended
	Sep. 30, 2017
Property, Plant And Equipment [Abstract]
Net Changes in Capitalized Exploratory Well Costs	   (Thousands of dollars) 2017 2016  Beginning balance at January 1 $ 148,500 130,514  Additions pending the determination of proved reserves 51,614 847  Reclassifications to proved properties based on the determination of proved reserves (13,370) –  Capitalized exploratory well costs charged to expense (8,360) –  Other adjustments – (3,205)  Balance at September 30 $ 178,384 128,156 
Aging of Capitalized Exploratory Well Costs	   September 30,  2017 2016  (Thousands of dollars) Amount No. of Wells No. of Projects Amount No. of Wells No. of Projects  Aging of capitalized well costs:  Zero to one year $ 41,609 3 2 $ 10,563 2 2  One to two years 8,430 2 2 53,101 3 3  Two to three years 43,197 1 1 31,627 2 –  Three years or more 85,148 7 1 32,865 4 –  $ 178,384 13 6 $ 128,156 11 5 

Discontinued Operations and A28

Discontinued Operations and Assets Held for Sale (Tables)	9 Months Ended
	Sep. 30, 2017
Discontinued Operations and Assets Held for Sale [Abstract]
Results of Operations Associated with Discontinued Operations	  Three Months Nine Months  Ended September 30, Ended September 30,  (Thousands of dollars) 2017 2016 2017 2016  Revenues (costs) $ 598 5 853 1,454  Income (loss) before income taxes 425 (1,593) 1,177 (885)  Income tax benefit – – – –  Income (loss) from discontinued operations $ 425 (1,593) 1,177 (885) 
Major Categories of Assets and Liabilities Reflected as Held for Sale	   September 30, December 31,  (Thousands of dollars) 2017 2016  Current assets  Cash $ 17,030 4,126  Accounts receivable 6,218 22,944  Total current assets held for sale $ 23,248 27,070  Current liabilities  Accounts payable $ 605 270  Refinery decommissioning cost 2,665 2,506  Total current liabilities associated with assets held for sale $ 3,270 2,776  Non-current liabilities  Asset retirement obligation - Seal asset $ – 85,900 

Other Financial Information (Ta

Other Financial Information (Tables)	9 Months Ended
	Sep. 30, 2017
Other Financial Information [Abstract]
Noncash Operating Working Capital (Increase) Decrease	  Nine Months Ended September 30,  (Thousands of dollars) 2017 2016  Net (increase) decrease in operating working capital other than cash and cash equivalents:  Decrease in accounts receivable $ 90,614 75,841  Decrease (increase) in inventories 5,869 (15,768)  Decrease in prepaid expenses 25,285 122,399  Decrease in other – 720  Decrease in accounts payable and accrued liabilities (115,977) (376,310) *  (Decrease) increase in current income tax liabilities (4,721) 40,500  Net (increase) decrease in noncash operating working capital $ 1,070 (152,618)  Supplementary disclosures:  Cash income taxes paid, net of refunds $ 25,118 (3,911)  Interest paid, net of amounts capitalized of $3,338 in 2017 and $3,318 in 2016 95,899 52,287   Non-cash investing activities:  Asset retirement costs capitalized $ 38,992 13,959  Decrease in capital expenditure accrual 42,403 179,203   * 2016 balance included payments for deepwater rig contract exit of $266.6 million.

Employee and Retiree Benefit 30

Employee and Retiree Benefit Plans (Tables)	9 Months Ended
	Sep. 30, 2017
Employee and Retiree Benefit Plans [Abstract]
Components of Net Periodic Benefit Expense	   Three Months Ended September 30,  Pension Benefits Other Postretirement Benefits  (Thousands of dollars) 2017 2016 2017 2016  Service cost $ 2,037 2,610 427 674  Interest cost 7,261 5,913 966 1,109  Expected return on plan assets (8,070) (6,626) – –  Amortization of prior service cost (credit) 259 323 (18) (21)  Amortization of transitional asset – – – 2  Recognized actuarial loss 3,610 3,617 – 38  Net periodic benefit expense $ 5,097 5,837 1,375 1,802   Nine Months Ended September 30,  Pension Benefits Other Postretirement Benefits  (Thousands of dollars) 2017 2016 2017 2016  Service cost $ 6,099 8,533 1,276 2,022  Interest cost 20,267 20,386 2,899 3,324  Expected return on plan assets (21,730) (21,709) – –  Amortization of prior service cost (credit) 767 963 (55) (62)  Amortization of transitional asset – – – 4  Recognized actuarial loss 10,673 10,864 – 113  Curtailments – 822 – (19)  Net periodic benefit expense $ 16,076 19,859 4,120 5,382 

Incentive Plans (Tables)

Incentive Plans (Tables)	9 Months Ended
	Sep. 30, 2017
Incentive Plans [Abstract]
Share-Based Plans, Amounts Recognized	   Nine Months Ended  September 30,  (Thousands of dollars) 2017 2016  Compensation charged against income (loss) before tax benefit $ 28,264 35,948  Related income tax benefit recognized in income 8,695 11,796 

Earnings per Share (Tables)

Earnings per Share (Tables)	9 Months Ended
	Sep. 30, 2017
Earnings per Share [Abstract]
Weighted-Average Shares Outstanding for Computation of Basic and Diluted Income per Common Share	   Three Months Ended Nine Months Ended  September 30, September 30,  (Weighted-average shares) 2017 2016 2017 2016  Basic method 172,572,873 172,199,350 172,509,418 172,164,683  Dilutive stock options and restricted stock units* – – – –  Diluted method 172,572,873 172,199,350 172,509,418 172,164,683   * Due to net losses recognized by the Company for all periods presented, no unvested stock awards were included in the computation of diluted earnings per share because the effect would have been anti-dilutive.
Anti Dilutive Securities Not Included in Computation of Diluted EPS	   Three Months Ended Nine Months Ended  September 30, September 30,  2017 2016 2017 2016  Antidilutive stock options excluded from diluted shares 5,257,718 5,884,201 5,578,495 5,822,036  Weighted average price of these options $ 46.46 $ 49.00 $ 46.86 $ 49.82 

Income Taxes (Tables)

Income Taxes (Tables)	9 Months Ended
	Sep. 30, 2017
Income Taxes [Abstract]
Effective Income Tax Rates	   2017 2016  Three months ended September 30 (4.3%) 13.0%  Nine months ended September 30 137.7% 48.9% 

Financial Instruments and Ris34

Financial Instruments and Risk Management (Tables)	9 Months Ended
	Sep. 30, 2017
Financial Instruments and Risk Management [Abstract]
Fair Value of Derivative Instruments Not Designated as Hedging Instruments	   September 30, 2017 December 31, 2016  (Thousands of dollars) Asset (Liability) Derivatives Asset (Liability) Derivatives  Type of Derivative Contract Balance Sheet Location Fair Value Balance Sheet Location Fair Value  Commodity Accounts payable $ (3,226) Accounts payable $ (48,864)  Foreign exchange Accounts receivable – Accounts payable (73) 
Recognized Gains and Losses for Derivative Instruments Not Designated as Hedging Instruments	   Gain (Loss)  Three Months Ended Nine Months Ended  (Thousands of dollars) September 30, September 30,  Type of Derivative Contract Statement of Operations Location 2017 2016 2017 2016  Commodity Sales and other operating revenues $ (13,573) 11,871 50,365 (22,678)  Foreign exchange Interest and other income (loss) – 143 73 26,929  $ (13,573) 12,014 50,438 4,251 
Carrying Value of Assets and Liabilities Recorded at Fair Value on Recurring Basis	   September 30, 2017 December 31, 2016  (Thousands of dollars) Level 1 Level 2 Level 3 Total Level 1 Level 2 Level 3 Total  Liabilities:  Nonqualified employee savings plans $ 15,161 – – 15,161 13,904 – – 13,904  Commodity derivative contracts – 3,226 – 3,226 – 48,864 – 48,864  Foreign currency exchange derivative contracts – – – – – 73 – 73  $ 15,161 3,226 – 18,387 13,904 48,937 – 62,841 
Nonrecurring Fair Value Measurements	  Nine-months ended September 30, 2016  Total  Net Book Pretax  Value (Noncash)  Fair Value Prior to Impairment  Level 1 Level 2 Level 3 Impairment Expense  (Thousands of dollars)  Assets:  Impaired proved properties  Canada $ – – 71,967 167,055 95,088 

Accumulated Other Comprehensi35

Accumulated Other Comprehensive Loss (Tables)	9 Months Ended
	Sep. 30, 2017
Accumulated Other Comprehensive Loss [Abstract]
Components of Accumulated Other Comprehensive Loss	   Deferred  Loss on  Foreign Retirement and Interest  Currency Postretirement Rate  Translation Benefit Plan Derivative  (Thousands of dollars) Gains (Losses) Adjustments Hedges Total  Balance at December 31, 2016 $ (446,555) (171,305) (10,352) (628,212)  2017 components of other comprehensive income (loss):  Before reclassifications to income 194,094 3 – 194,097  Reclassifications to income – 7,166 1 1,445 2 8,611  Net other comprehensive income 194,094 7,169 1,445 202,708  Balance at September 30, 2017 $ (252,461) (164,136) (8,907) (425,504)  1 Reclassifications before taxes of $11,039 for the nine-month period ended September 30, 2017 are inc luded in the computation of net periodic benefit expense. See Note G for additional information. Related income taxes of $3,873 for the nine-month period ended September 30, 2017 are included in Income tax expense. 2 Reclassifications before taxes of $2,222 for the nine-month period ended September 30, 2017 are included in Interest expense , net . Related income taxes of $777 for the nine-month period ended September 30, 2017 are included in Income tax expense .

Business Segments (Tables)

Business Segments (Tables)	9 Months Ended
	Sep. 30, 2017
Business Segments [Abstract]
Segment Information	  Three Months Ended Three Months Ended  Total Assets September 30, 2017 September 30, 2016  at September 30, External Income External Income  (Millions of dollars) 2017 Revenues (Loss) Revenues (Loss)  Exploration and production*  United States $ 5,439.1 195.9 (19.9) 201.8 (27.1)  Canada 1,711.1 81.9 (3.2) 80.9 (4.8)  Malaysia 1,755.3 220.5 67.7 202.7 65.0  Other 139.9 – (11.0) 0.2 (8.1)  Total exploration and production 9,045.4 498.3 33.6 485.6 25.0  Corporate 1,124.2 – (99.9) (0.1) (39.6)  Assets/revenue/loss from continuing operations 10,169.6 498.3 (66.3) 485.5 (14.6)  Discontinued operations, net of tax 23.2 – 0.4 – (1.6)  Total $ 10,192.8 498.3 (65.9) 485.5 (16.2)   Nine Months Ended Nine Months Ended  September 30, 2017 September 30, 2016  External Income External Income  (Millions of dollars) Revenues (Loss) Revenues (Loss)  Exploration and production*  United States $ 696.7 11.0 520.2 (158.5)  Canada 388.1 102.6 264.4 (36.9)  Malaysia 594.4 173.9 541.4 135.1  Other – (10.9) 0.2 (39.2)  Total exploration and production 1,679.2 276.6 1,326.2 (99.5)  Corporate 4.0 (302.8) 3.5 (111.7)  Revenue/loss from continuing operations 1,683.2 (26.2) 1,329.7 (211.2)  Discontinued operations, net of tax – 1.2 – (0.8)  Total $ 1,683.2 (25.0) 1,329.7 (212.0)  * Additional details about results of oil and gas operations are presented in the tables on pages 29 and 30 .

Property, Plant and Equipment37

Property, Plant and Equipment (Narrative) (Details) - USD ($) $ in Thousands	1 Months Ended	3 Months Ended					9 Months Ended
	Jan. 31, 2017	Sep. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Apr. 01, 2017	Dec. 31, 2015
Property Plant And Equipment [Line Items]
Total capitalized exploratory well costs		$ 178,384		$ 148,500	$ 128,156		$ 178,384	$ 128,156		$ 130,514
Exploratory well costs capitalized more than one year		136,800					136,800
Proceeds from sales of property, plant and equipment							69,146	1,154,623
Gain (loss) on sale of assets		117			$ (730)		$ 130,765	3,101
Impairment of assets								95,088
Cost of acquired assets, cash paid						$ 206,700
Athabasca Oil Corporation [Member]
Property Plant And Equipment [Line Items]
Cost of acquired assets, carried interest						$ 168,000
Cost of acquired assets, interest carry period							5 years
Western Canada [Member]
Property Plant And Equipment [Line Items]
Proceeds from sales of property, plant and equipment	$ 49,000
Asset retirement obligation settled	$ 85,900
Gain (loss) on sale of assets			$ 132,400
Syncrude [Member]
Property Plant And Equipment [Line Items]
Gain (loss) on sale of assets								71,700
Percentage of interest in oil and gas property sold during period						5.00%
Eagle Ford Shale [Member]
Property Plant And Equipment [Line Items]
Proceeds from sales of property, plant and equipment							$ 19,400
Gain (loss) on sale of assets							0
Montney Natural Gas Fields [Member]
Property Plant And Equipment [Line Items]
Deferred gain on sale of property		185,000				$ 187,000	185,000
Amortization of deferred gain on sale of property							$ 5,300	$ 3,400
Deferred gain, period of recognition							19 years
Murphy Oil Corp [Member] | Syncrude [Member]
Property Plant And Equipment [Line Items]
Proceeds from sales of property, plant and equipment						739,100
Canadian Subsidiary [Member] | Athabasca Oil Corporation [Member]
Property Plant And Equipment [Line Items]
Cost of acquired assets						$ 375,000
Brunei [Member]
Property Plant And Equipment [Line Items]
Exploratory well costs capitalized more than one year		70,400					$ 70,400
Vietnam [Member]
Property Plant And Equipment [Line Items]
Exploratory well costs capitalized more than one year		43,200					43,200
Malaysia [Member]
Property Plant And Equipment [Line Items]
Exploratory well costs capitalized more than one year		23,200					23,200
Redetermination expense				$ 39,100
Reduction in capital lease obligations		56,700					$ 56,700
Kaybob Duvernay Lands, Alberta [Member]
Property Plant And Equipment [Line Items]
Redetermination expense paid		$ 21,800
Interest in assets acquired						70.00%
Working interest			8.60%						6.70%
Montney Lands, Alberta [Member]
Property Plant And Equipment [Line Items]
Interest in assets acquired						30.00%

Property, Plant And Equipment38

Property, Plant And Equipment (Net Changes in Capitalized Exploratory Well Costs) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Property, Plant And Equipment [Abstract]
Beginning balance at January 1	$ 148,500	$ 130,514
Additions pending the determination of proved reserves	51,614	847
Reclassifications to proved properties based on the determination of proved reserves	(13,370)
Capitalized exploratory well costs charged to expense	(8,360)
Other adjustments		(3,205)
Balance at September 30	$ 178,384	$ 128,156

Property, Plant And Equipment39

Property, Plant And Equipment (Aging of Capitalized Exploratory Well Costs) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2017USD ($)item	Sep. 30, 2016USD ($)item	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 178,384	$ 128,156	$ 148,500	$ 130,514
No. of Wells	13	11
No. of Projects	6	5
Zero to One Year [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 41,609	$ 10,563
No. of Wells	3	2
No. of Projects	2	2
One to Two Years [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 8,430	$ 53,101
No. of Wells	2	3
No. of Projects	2	3
Two to Three Years [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 43,197	$ 31,627
No. of Wells	1	2
No. of Projects	1
Three Years or More [Member]
Projects with Exploratory Well Costs Capitalized for More than One Year [Line Items]
Amount | $	$ 85,148	$ 32,865
No. of Wells	7	4
No. of Projects	1

Discontinued Operations and A40

Discontinued Operations and Assets Held for Sale (Results of Operations Associated with Discontinued Operations) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Discontinued Operations and Assets Held for Sale [Abstract]
Revenues (costs)	$ 598	$ 5	$ 853	$ 1,454
Income (loss) before income taxes	425	(1,593)	1,177	(885)
Income (loss) from discontinued operations	$ 425	$ (1,593)	$ 1,177	$ (885)

Discontinued Operations and A41

Discontinued Operations and Assets Held for Sale (Major Categories of Assets and Liabilities Reflected as Held for Sale) (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Accounts receivable	$ 267,209	$ 357,099
Total current assets held for sale	23,248	27,070
Accounts payable	584,025	784,975
Total current liabilities associated with assets held for sale	3,270	2,776
Asset retirement obligation - Seal asset	747,602	681,528
Total non-current liabilities associated with assets held for sale		85,900
UK Refining And Marketing Operations [Member]
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Cash	17,030	4,126
Accounts receivable	6,218	22,944
Total current assets held for sale	23,248	27,070
Accounts payable	605	270
Refinery decommissioning cost	2,665	2,506
Total current liabilities associated with assets held for sale	$ 3,270	2,776
Asset retirement obligation - Seal asset		$ 85,900

Financing Arrangements and De42

Financing Arrangements and Debt (Narrative) (Details) - USD ($)	9 Months Ended
	Sep. 30, 2017	Aug. 31, 2017	Aug. 31, 2016
Line of Credit Facility [Line Items]
Capital Lease Duration	25 years
Capital lease payment duration	15 years
Capital lease expiration date	Mar. 31, 2029
Capital lease obligations, current	$ 9,800,000
Capital lease obligations, noncurrent	$ 136,500,000
5.75% Notes, Due August 15, 2025 [Member]
Line of Credit Facility [Line Items]
Face amount of notes		$ 550,000,000
Notes payable, stated interest rate		5.75%
Maturity date	Aug. 15, 2025
Transaction costs		$ 8,200,000
2.50% Notes, Due December 2017 [Member]
Line of Credit Facility [Line Items]
Notes payable, stated interest rate		2.50%
6.875 Notes, Due August 15, 2024 [Member]
Line of Credit Facility [Line Items]
Face amount of notes			$ 550,000,000
Notes payable, stated interest rate			6.875%
Maturity date	Aug. 15, 2024
2016 Senior Unsecured Guaranteed Credity Facility [Member]
Line of Credit Facility [Line Items]
Credit facility maximum borrowing capacity	$ 1,100,000,000		$ 1,200,000,000
Credit facility, expiration date	Aug. 1, 2019
Amount outstanding	$ 0
Transaction costs			14,000,000
2016 Senior Unsecured Guaranteed Credity Facility [Member] | Eurodollar [Member]
Line of Credit Facility [Line Items]
Interest rate	4.50%
2016 Senior Unsecured Guaranteed Credity Facility [Member] | Letter of Credit [Member]
Line of Credit Facility [Line Items]
Amount outstanding	$ 84,800,000
2011 Unscured Revolving Credit Facility [Member]
Line of Credit Facility [Line Items]
Credit facility maximum borrowing capacity	$ 630,000,000		$ 2,000,000,000

Other Financial Information (No

Other Financial Information (Noncash Opearting Working Capital Increase (Decrease)) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Other Financial Information [Abstract]
Decrease in accounts receivable	$ 90,614	$ 75,841
Decrease (increase) in inventories	5,869	(15,768)
Decrease in prepaid expenses	25,285	122,399
Decrease in other		720
Decrease in accounts payable and accrued liabilities	(115,977)	(376,310)	[1]
(Decrease) increase in current income tax liabilities	(4,721)	40,500
Net (increase) decrease in noncash operating working capital	1,070	(152,618)	[1]
Cash income taxes paid, net of refunds	25,118	(3,911)
Interest paid, net of amounts capitalized of $3,338 in 2017 and $3,318 in 2016	95,899	52,287
Asset retirement costs capitalized	38,992	13,959
Decrease in capital expenditure accrual	42,403	179,203
Payments for deepwater rig exit costs		266,600
Interest paid, amounts capitalized	$ 3,338	$ 3,318
[1]	2016 balance includes payments for deepwater rig contract exit of $266.6 million.

Employee and Retiree Benefit 44

Employee and Retiree Benefit Plans (Narrative) (Details) $ in Millions	9 Months Ended
	Sep. 30, 2017USD ($)
Employee and Retiree Benefit Plans [Abstract]
Contributions to benefit plans	$ 24
Expected benefit plan contributions to be made during the year	$ 6.8

Employee and Retiree Benefit 45

Employee and Retiree Benefit Plans (Components of Net Periodic Benefit Expense) (Details) - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Pension Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	$ 2,037	$ 2,610	$ 6,099	$ 8,533
Interest cost	7,261	5,913	20,267	20,386
Expected return on plan assets	(8,070)	(6,626)	(21,730)	(21,709)
Amortization of prior service cost (credit)	259	323	767	963
Recognized actuarial loss	3,610	3,617	10,673	10,864
Curtailments				822
Net periodic benefit expense	5,097	5,837	16,076	19,859
Other Postretirement Benefits [Member]
Defined Benefit Plan Disclosure [Line Items]
Service cost	427	674	1,276	2,022
Interest cost	966	1,109	2,899	3,324
Amortization of prior service cost (credit)	(18)	(21)	(55)	(62)
Amortization of transitional asset		2		4
Recognized actuarial loss		38		113
Curtailments				(19)
Net periodic benefit expense	$ 1,375	$ 1,802	$ 4,120	$ 5,382

Incentive Plans (Narrative) (De

Incentive Plans (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	1 Months Ended	9 Months Ended
	Feb. 28, 2017	Sep. 30, 2017	Sep. 30, 2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock options exercised		0	0
Related income tax benefit recognized in income		$ 8,695	$ 11,796
2012 Long-Term Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Long term plan expiration year		2,022
Maximum number of shares available for issuance		8,700,000
Maximum number of shares available for issuance, annual rate		1.00%
Stock Options [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options granted	599,000
Exercise price of options granted	$ 28.505
Granted stock options, valuation per option	$ 7.96
Stock-based compensation, fair value assumption model		Black-Scholes valuation model
Performance Based Restricted Share Awards [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	556,000
Stock-based compensation, fair value assumption model		Monte Carlo valuation model
Performance Based Restricted Share Awards [Member] | Minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair value per share at grant date	$ 24.10
Performance Based Restricted Share Awards [Member] | Maximum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair value per share at grant date	$ 28.28
Time Based Restricted Stock Units [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	282,000
Fair value per share at grant date	$ 28.505
Time Based Restricted Stock Units [Member] | Non-Employee Director Plan [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	83,220
Vesting scheme		These shares vest on the third anniversary of the date of grant.
Time Based Restricted Stock Units [Member] | Non-Employee Director Plan [Member] | Minimum [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Fair value per share at grant date	$ 28.84
SAR [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	329,400
Cash-Settled RSU (RSU-C) [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Granted	154,150

Incentive Plans (Share-Based Pl

Incentive Plans (Share-Based Plans, Amounts Recognized) (Details) - USD ($) $ in Thousands	9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016
Incentive Plans [Abstract]
Compensation charged against income (loss) before tax benefit	$ 28,264	$ 35,948
Related income tax benefit recognized in income	$ 8,695	$ 11,796

Earnings per Share (Weighted-Av

Earnings per Share (Weighted-Average Shares Outstanding for Computation of Basic and Diluted Income per Common Share) (Details) - shares		3 Months Ended		9 Months Ended
		Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Earnings per Share [Abstract]
Basic method		172,572,873	172,199,350	172,509,418	172,164,683
Dilutive stock options and restricted stock units	[1]	0	0	0	0
Diluted method		172,572,873	172,199,350	172,509,418	172,164,683
[1]	Due to net losses recognized by the Company for all periods presented, no unvested stock awards were included in the computation of diluted earnings per share because the effect would have been anti-dilutive.

Earnings per Share (Anti Diluti

Earnings per Share (Anti Dilutive Securities Not Included in Computation of Diluted EPS) (Details) - $ / shares	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Earnings per Share [Abstract]
Antidilutive stock options excluded from diluted shares (in shares)	5,257,718	5,884,201	5,578,495	5,822,036
Weighted average price of these options (per share)	$ 46.46	$ 49	$ 46.86	$ 49.82

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Millions	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Tax Examination [Line Items]
Deferred tax expense, undistributed foreign earnings			$ 65.2
U.S. statutory rate	35.00%	35.00%	35.00%	35.00%
United States [Member]
Income Tax Examination [Line Items]
Earliest year remaining open for audit and/or settlement in major taxing jurisdictions			2,014
Canada [Member]
Income Tax Examination [Line Items]
Earliest year remaining open for audit and/or settlement in major taxing jurisdictions			2,012
Malaysia [Member]
Income Tax Examination [Line Items]
Earliest year remaining open for audit and/or settlement in major taxing jurisdictions			2,010
United Kingdom [Member]
Income Tax Examination [Line Items]
Earliest year remaining open for audit and/or settlement in major taxing jurisdictions			2,015

Income Taxes (Effective Income

Income Taxes (Effective Income Tax Rates) (Details)	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Income Taxes [Abstract]
Effective income tax rate	(4.30%)	13.00%	137.70%	48.90%

Financial Instruments and Ris52

Financial Instruments and Risk Management (Narrative) (Details) bbl / d in Thousands, $ in Thousands	3 Months Ended	9 Months Ended		12 Months Ended
	Dec. 31, 2017USD ($)	Sep. 30, 2017USD ($)bbl / dcontractitem$ / bbl	Sep. 30, 2016USD ($)bbl / d	Dec. 31, 2018bbl / d$ / bbl	Dec. 31, 2016item
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Number of open contracts | contract		0
Impairment of assets			$ 95,088
Amount of loss reclassified to interest expense		$ 2,200	$ 2,200
Derivative loss		$ 2,222
Number of offsetting positions | item		0			0
Scenario, Forecast [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Derivative loss	$ 700
Commodity Derivative Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Daily production commitment (barrels per day) | bbl / d		22	25
Average price | $ / bbl		50.41
Fair value of derivative contract liability		$ 3,200
Fair value of derivative contract asset			$ 200
Increase (decrease) of income before taxes due to the impact of marking to market of derivative contracts		(3,200)	3,900
Commodity Derivative Contracts [Member] | Scenario, Forecast [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Daily production commitment (barrels per day) | bbl / d				6
Average price | $ / bbl				51.83
Foreign Exchange Derivative Contracts [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Fair value of foreign derivative contracts			100
Foreign Exchange Derivative Contracts [Member] | Currency, U.S. Dollar [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Short-term derivative instruments			$ 25,200
Interest Rate Swap [Member]
Derivative Instruments and Hedging Activities Disclosures [Line Items]
Loss deferred for fair value of interest rate derivative contracts, net of tax		8,900
Income taxes on deferred loss on fair value of interest rate derivative contracts		$ 4,800

Financial Instruments and Ris53

Financial Instruments and Risk Management (Fair Value of Derivative Instruments Not Designated as Hedging Instruments) (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016	Sep. 30, 2016
Commodity Derivative Contracts [Member]
Derivatives, Fair Value [Line Items]
Asset Derivatives			$ 200
Foreign Exchange Derivative Contracts [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives			$ (100)
Nondesignated [Member] | Commodity Derivative Contracts [Member] | Accounts Payable [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives	$ (3,226)	$ (48,864)
Nondesignated [Member] | Foreign Exchange Derivative Contracts [Member] | Accounts Payable [Member]
Derivatives, Fair Value [Line Items]
Liability Derivatives		$ (73)

Financial Instruments and Ris54

Financial Instruments and Risk Management (Recognized Gains and Losses for Derivative Instruments Not Designated as Hedging Instruments) (Details) - Nondesignated [Member] - USD ($) $ in Thousands	3 Months Ended		9 Months Ended
	Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)	$ (13,573)	$ 12,014	$ 50,438	$ 4,251
Commodity Derivative Contracts [Member] | Sales And Other Operating Revenues [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)	$ (13,573)	11,871	50,365	(22,678)
Foreign Exchange Derivative Contracts [Member] | Interest And Other Income (Loss) [Member]
Derivative Instruments, Gain (Loss) [Line Items]
Gain (Loss)		$ 143	$ 73	$ 26,929

Financial Instruments and Ris55

Financial Instruments and Risk Management (Carrying Value of Assets and Liabilities Recorded at Fair Value on Recurring Basis) (Details) - USD ($) $ in Thousands	Sep. 30, 2017	Dec. 31, 2016	Sep. 30, 2016
Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives	$ 18,387	$ 62,841
Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives	15,161	13,904
Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives	3,226	48,937
Non-Qualified Employee Savings Plans [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives	15,161	13,904
Non-Qualified Employee Savings Plans [Member] | Fair Value, Measurements, Recurring [Member] | Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives	15,161	13,904
Commodity Derivative Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Asset Derivatives			$ 200
Commodity Derivative Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives	3,226	48,864
Commodity Derivative Contracts [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives	$ 3,226	48,864
Foreign Exchange Derivative Contracts [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives			$ 100
Foreign Exchange Derivative Contracts [Member] | Fair Value, Measurements, Recurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives		73
Foreign Exchange Derivative Contracts [Member] | Fair Value, Measurements, Recurring [Member] | Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Liability Derivatives		$ 73

Financial Instruments and Ris56

Financial Instruments and Risk Management (Nonrecurring Fair Value Measurements) (Details) $ in Thousands	9 Months Ended
	Sep. 30, 2016USD ($)
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Total Pretax (Noncash) Impairment Expense	$ 95,088
Canada [Member] | Fair Value, Measurements, Nonrecurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Net Book Value Prior to Impairment	167,055
Total Pretax (Noncash) Impairment Expense	95,088
Canada [Member] | Level 3 [Member] | Fair Value, Measurements, Nonrecurring [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Assets: Impaired proved properties	$ 71,967

Accumulated Other Comprehensi57

Accumulated Other Comprehensive Loss (Components of Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning Balance				$ (628,212)
Before reclassifications to income				194,097
Reclassifications to income				8,611
Net other comprehensive income		$ 104,088	$ (34,372)	202,708	$ 133,511
Ending Balance		(425,504)		(425,504)
Reclassifications before taxes, included in net periodic benefit expense				11,039
Reclassifications income tax, included in net periodic benefit expense				3,873
Reclassifications before taxes, included in interest expense				2,222
Reclassifications income tax, included in interest expense				777
Foreign Currency Translation Gains (Losses) [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning Balance				(446,555)
Before reclassifications to income				194,094
Net other comprehensive income				194,094
Ending Balance		(252,461)		(252,461)
Retirement and Postretirement Benefit Plan Adjustments [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning Balance				(171,305)
Before reclassifications to income				3
Reclassifications to income	[1]			7,166
Net other comprehensive income				7,169
Ending Balance		(164,136)		(164,136)
Deferred Loss On Interest Rate Derivative Hedges [Member]
Accumulated Other Comprehensive Income (Loss) [Line Items]
Beginning Balance				(10,352)
Reclassifications to income	[2]			1,445
Net other comprehensive income				1,445
Ending Balance		$ (8,907)		$ (8,907)
[1]	Reclassifications before taxes of $11,039 for the nine-month period ended September 30, 2017 are included in the computation of net periodic benefit expense. See Note G for additional information. Related income taxes of $3,873 for the nine-month period ended September 30, 2017 are included in Income tax expense.
[2]	Reclassifications before taxes of $2,222 for the nine-month period ended September 30, 2017 are included in Interest expense, net. Related income taxes of $777 for the nine-month period ended September 30, 2017 are included in Income tax expense.

Environmental and Other Conti58

Environmental and Other Contingencies (Narrative) (Details) - USD ($)	9 Months Ended	12 Months Ended
	Sep. 30, 2017	Dec. 31, 2015
Contingencies Disclosure [Line Items]
Remediation costs		$ 43,900,000
Remediation accrual	$ 5,800,000
Canada [Member]
Contingencies Disclosure [Line Items]
Payments for environmental liabilities	$ 130,000

Commitments (Narrative) (Detail

Commitments (Narrative) (Details) - Natural Gas [Member]	Sep. 30, 2017MMcf / DMMcf / d$ / McfCAD / Mcf
October to December 2017 [Member]
Commitments and Contingencies Disclosure [Line Items]
Notional amount, per day | MMcf / d	124
Swap price (per share) | CAD / Mcf	2.97
January 2018 to December 2020 [Member]
Commitments and Contingencies Disclosure [Line Items]
Notional amount, per day | MMcf / D	59
Swap price (per share) | CAD / Mcf	2.81
November 2017 to March 2018 [Member]
Commitments and Contingencies Disclosure [Line Items]
Notional amount, per day | MMcf / d	20
Swap price (per share) | $ / Mcf	3.51

Business Segments (Segment Info

Business Segments (Segment Information) (Details) - USD ($) $ in Thousands		3 Months Ended		9 Months Ended
		Sep. 30, 2017	Sep. 30, 2016	Sep. 30, 2017	Sep. 30, 2016	Dec. 31, 2016
Segment Reporting Information [Line Items]
Total Assets		$ 10,192,759		$ 10,192,759		$ 10,295,860
External Revenues		498,319	$ 485,546	1,683,238	$ 1,329,688
Net income (loss)		(65,893)	(16,176)	(25,000)	(212,048)
Continuing Operations [Member]
Segment Reporting Information [Line Items]
Total Assets		10,169,600		10,169,600
External Revenues		498,300	485,500	1,683,200	1,329,700
Net income (loss)		(66,300)	(14,600)	(26,200)	(211,200)
Discontinued Operations [Member]
Segment Reporting Information [Line Items]
Total Assets		23,200		23,200
Net income (loss)		400	(1,600)	1,200	(800)
Corporate [Member]
Segment Reporting Information [Line Items]
Total Assets		1,124,200		1,124,200
External Revenues			(100)	4,000	3,500
Net income (loss)		(99,900)	(39,600)	(302,800)	(111,700)
Exploration and production [Member] | Operating Segments [Member]
Segment Reporting Information [Line Items]
Total Assets	[1]	9,045,400		9,045,400
External Revenues	[1]	498,300	485,600	1,679,200	1,326,200
Net income (loss)	[1]	33,600	25,000	276,600	(99,500)
Exploration and production [Member] | Operating Segments [Member] | United States [Member]
Segment Reporting Information [Line Items]
Total Assets	[1]	5,439,100		5,439,100
External Revenues	[1]	195,900	201,800	696,700	520,200
Net income (loss)	[1]	(19,900)	(27,100)	11,000	(158,500)
Exploration and production [Member] | Operating Segments [Member] | Canada [Member]
Segment Reporting Information [Line Items]
Total Assets	[1]	1,711,100		1,711,100
External Revenues	[1]	81,900	80,900	388,100	264,400
Net income (loss)	[1]	(3,200)	(4,800)	102,600	(36,900)
Exploration and production [Member] | Operating Segments [Member] | Malaysia [Member]
Segment Reporting Information [Line Items]
Total Assets	[1]	1,755,300		1,755,300
External Revenues	[1]	220,500	202,700	594,400	541,400
Net income (loss)	[1]	67,700	65,000	173,900	135,100
Exploration and production [Member] | Operating Segments [Member] | Other Regions [Member]
Segment Reporting Information [Line Items]
Total Assets	[1]	139,900		139,900
External Revenues	[1]		200		200
Net income (loss)	[1]	$ (11,000)	$ (8,100)	$ (10,900)	$ (39,200)
[1]	Additional details about results of oil and gas operations are presented in the tables on pages 29 and 30.