Superior Energy Services 10-K 25 Feb 16 2015 FY Annual report Financial data

Document And Entity Information

Document And Entity Information - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Feb. 16, 2016	Jun. 30, 2015
Document And Entity Information [Abstract]
Entity Registrant Name	Superior Energy Services Inc
Entity Central Index Key	886,835
Document Type	10-K
Document Period End Date	Dec. 31, 2015
Amendment Flag	false
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		151,397,654
Entity Public Float			$ 3,190
Entity Well-known Seasoned Issuer	Yes
Trading Symbol	spn
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No

Consolidated Balance Sheets

Consolidated Balance Sheets - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 564,017	$ 393,046
Accounts receivable, net of allowance for doubtful accounts of $28,242 and $22,076 at December 31, 2015 and December 31, 2014, respectively	428,514	926,768
Prepaid expenses	42,298	74,750
Inventory and other current assets	165,062	185,429
Assets held for sale	95,234	116,680
Total current assets	1,295,125	1,696,673
Property, plant and equipment, net	2,123,291	2,733,839
Goodwill	1,140,101	2,468,409
Notes receivable	52,382	25,970
Intangible and other long-term assets, net	303,345	392,891
Total assets	4,914,244	7,317,782
Current liabilities:
Accounts payable	114,475	225,306
Accrued expenses	271,246	363,747
Income taxes payable	9,185	40,213
Current maturities of long-term debt	29,957	20,941
Current portion of decommissioning liabilities	19,052
Liabilities Held-for-sale	4,661	61,840
Total current liabilities	448,576	712,047
Deferred income taxes	383,069	670,858
Decommissioning liabilities	98,890	88,000
Long-term debt, net	1,588,263	1,600,373
Other long-term liabilities	$ 184,634	$ 166,766
Stockholders' equity:
Preferred stock of $0.01 par value. Authorized, 5,000,000 shares; none issued
Common stock of $0.001 par value. Authorized - 250,000,000, Issued and Outstanding- 150,861,500as of December 31, 2015 Authorized - 250,000,000, Issued - 149,648,826, Outstanding - 149,708,825 at December 31, 2014	$ 151	$ 150
Additional paid in capital	2,664,517	2,620,328
Accumulated other comprehensive loss, net	(45,694)	(36,280)
Retained earnings	(408,162)	1,495,540
Total stockholders' equity	2,210,812	4,079,738
Total liabilities and stockholders' equity	$ 4,914,244	$ 7,317,782

Consolidated Balance Sheets (Pa

Consolidated Balance Sheets (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Consolidated Balance Sheets [Abstract]
Allowance for doubtful accounts	$ 28,242	$ 22,076
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, shares authorized	5,000,000	5,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$ 0.001	$ 0.001
Common stock, shares authorized	250,000,000	250,000,000
Common stock, shares issued	150,861,500	149,648,826
Common stock, shares outstanding	150,861,500	149,708,825

Condensed Consolidated Statemen

Condensed Consolidated Statements Of Operations - USD ($) shares in Thousands, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Condensed Consolidated Statements of Operations [Abstract]
Services	$ 2,104,942	$ 3,466,279	$ 3,371,847
Rentals	669,623	1,090,343	978,210
Total, Revenues	2,774,565	4,556,622	4,350,057
Costs and expenses:
Cost of Services (exclusive of items shown separately below)	1,575,653	2,308,270	2,244,881
Cost of Rentals (exclusive of items shown separately below)	290,159	426,563	388,709
Cost of goods and services	1,865,812	2,734,833	2,633,590
Depreciation, depletion, amortization and accretion	612,147	650,814	604,441
General and administrative expenses	510,708	624,371	597,778
Reduction in value of assets	1,738,887		300,078
Income from operations	(1,952,989)	546,604	214,170
Other income (expense):
Interest expense, net	97,318	96,734	107,902
Other Expense	(9,476)	(7,681)	(5,511)
Income from continuing operations before income taxes	(2,059,783)	442,189	100,757
Income taxes	(252,020)	161,399	55,272
Net income from continuing operations	(1,807,763)	280,790	45,485
Loss from discontinued operations, net of tax	(46,955)	(22,973)	(156,903)
Net income (loss)	$ (1,854,718)	$ 257,817	$ (111,418)
Earnings per share information:
Continuing operations, basic	$ (12.02)	$ 1.81	$ 0.29
Discontinued operations, basic	(0.31)	(0.15)	(0.99)
Basic earnings (loss) per share	(12.33)	1.66	(0.70)
Continuing operations, diluted	(12.02)	1.79	0.28
Discontinued operations, diluted	(0.31)	(0.14)	(0.97)
Diluted earnings per share	(12.33)	1.65	(0.69)
Cash dividends declared per share	$ 0.32	$ 0.24	$ 0.08
Weighted average common shares used in computing earnings per share:
Basic	150,461	155,154	159,206
Incremental common shares from stock based compensation		1,572	1,574
Diluted	150,461	156,726	160,780

Consolidated Statements Of Comp

Consolidated Statements Of Comprehensive Income - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Consolidated Statement of Comprehensive Income [Abstract]
Net income (loss)	$ (1,854,718)	$ 257,817	$ (111,418)
Unrealized net gain (loss) on investment securities, net of tax			(256)
Reclassification adjustment, net of tax		1,153
Change in cumulative translation adjustment, net of tax	(9,414)	(19,933)	2,073
Comprehensive income (loss)	$ (1,864,132)	$ 239,037	$ (109,601)

Consolidated Statements Of Chan

Consolidated Statements Of Changes In Stockholders' Equity - USD ($) $ in Thousands	Common Stock [Member]	Additional Paid-in Capital [Member]	Accumulated Other Comprehensive Income (Loss) [Member]	Retained Earnings [Member]	Total
Beginning balance, value at Dec. 31, 2012	$ 158	$ 2,850,855	$ (19,317)	$ 1,399,383	$ 4,231,079
Beginning balance, shares at Dec. 31, 2012	157,501,635
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net income (loss)				(111,418)	(111,418)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Unrealized net gain (loss) on investment securities			(256)		(256)
Unrealized net gain (loss) on investment securities, net of tax			(256)		(256)
Foreign currency translation adjustment			2,073		2,073
Stock Withheld and Retired Value		(2,811)			(2,811)
Stock Withheld and Retired Shares	(119,070)
Stock Repurchased and Retired During Period, Shares	(426,883)
Stock Repurchased and Retired During Period, Value		(10,627)			(10,627)
Vesting of restricted stock assumed with acquisition	210,951
Exercise of stock options, value		6,263			6,263
Exercise of stock options, shares	(470,712)
Tax benefit (expense) from stock-based compensation		(1,185)			(1,185)
Cash dividends declared				(12,759)	(12,759)
Stock Issued During Period, Shares, Share-based Compensation	1,154,032
Stock-based compensation expense, net of forfeitures	$ 1	26,071			26,072
Shares issued under Employee Stock Purchase Plan, value		5,013			$ 5,013
Shares issued under Employee Stock Purchase Plan, shares	185,407				185,407
Exercise of stock options, shares	426,883
Ending balance, value at Dec. 31, 2013	$ 159	2,873,579	(17,500)	1,275,206	$ 4,131,444
Ending balance, shares at Dec. 31, 2013	158,976,784
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net income (loss)				257,817	257,817
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Reclassification Adjustment of unrealized net loss on available-for-sale securities, Net of Tax			(1,153)		(1,153)
Foreign currency translation adjustment			(19,933)		(19,933)
Stock Withheld and Retired Value		(7,315)			(7,315)
Stock Withheld and Retired Shares	(267,340)
Stock Repurchased and Retired During Period, Shares	(10,246,091)
Stock Repurchased and Retired During Period, Value	$ (10)	(299,734)			(299,744)
Incremental common shares from restricted stock units	95,914
Vesting of restricted stock assumed with acquisition	114,839
Exercise of stock options, value	$ 1	10,560			10,561
Exercise of stock options, shares	(880,687)
Tax benefit (expense) from stock-based compensation		6,160			6,160
Cash dividends declared				(37,483)	(37,483)
Stock Issued During Period, Shares, Share-based Compensation	(152,447)
Stock-based compensation expense, net of forfeitures		30,982			30,982
Shares issued under Employee Stock Purchase Plan, value		6,096			$ 6,096
Shares issued under Employee Stock Purchase Plan, shares					246,480
Exercise of stock options, shares	10,246,091
Ending balance, value at Dec. 31, 2014	$ 150	2,620,328	(36,280)	1,495,540	$ 4,079,738
Ending balance, shares at Dec. 31, 2014	149,648,826
Comprehensive Income (Loss), Net of Tax, Attributable to Parent [Abstract]
Net income (loss)				(1,854,718)	(1,854,718)
Other Comprehensive Income (Loss), Net of Tax [Abstract]
Foreign currency translation adjustment			(9,414)		(9,414)
Stock Withheld and Retired Value		(5,696)			(5,696)
Stock Withheld and Retired Shares	(323,537)
Stock Repurchased and Retired During Period, Shares	(506,029)
Incremental common shares from restricted stock units	460,400
Restricted stock grant and expense, net of forefeitures, shares	(48,374)
Vesting of restricted stock assumed with acquisition	61,319
Exercise of stock options, value	$ 1	8,819			$ 8,820
Exercise of stock options, shares					506,029
Tax benefit (expense) from stock-based compensation		(2,174)			$ (2,174)
Cash dividends declared				(48,984)	(48,984)
Stock-based compensation expense, net of forfeitures		32,661			32,661
Shares issued to pay performance share unit, value		5,011			5,011
Shares issued to pay performance share unit, shares	224,303
Shares issued under Employee Stock Purchase Plan, value		5,568			$ 5,568
Shares issued under Employee Stock Purchase Plan, shares	332,534				332,467
Exercise of stock options, shares	506,029
Ending balance, value at Dec. 31, 2015	$ 151	$ 2,664,517	$ (45,694)	$ (408,162)	$ 2,210,812
Ending balance, shares at Dec. 31, 2015	150,861,500

Consolidated Statements of Cha7

Consolidated Statements of Changes in Stockholders' Equity (Parenthetical) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement of Stockholders' Equity [Abstract]
Cash dividends declared per share	$ 0.32	$ 0.24	$ 0.08

Consolidated Statements Of Cash

Consolidated Statements Of Cash Flows - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Cash flows from operating activities:
Net income (loss)	$ (1,854,718)	$ 257,817	$ (111,418)
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, amortization and accretion	612,147	652,143	625,928
Deferred income taxes	(288,671)	(49,567)	14,435
Reduction in value of assets including discontinued operations	1,738,887		419,380
Stock based and performance share unit compensation expense	46,485	42,748	35,832
Amortization of debt acquisition costs and note discount	7,643	8,110	8,919
(Gains) losses on sales of assets and businesses	(14,803)	(12,777)	(657)
Other reconciling items, net	49,042	(6,803)	(899)
Changes in operating assets and liabilities, net of acquisitions and dispositions:
Accounts receivable	501,269	(9,487)	85,423
Inventory and other current assets	33,282	53,594	(70,995)
Accounts payable	(105,801)	36,450	(32,304)
Accrued expenses	(116,573)	16,411	25,154
Income taxes	(30,891)	46,134	(162,148)
Other, net	55,314	(1,762)	56,158
Net Cash Provided by (Used in) Operating Activities, Total	632,612	1,033,011	892,808
Cash flows from investing activities:
Payments for capital expenditures	(358,226)	(616,102)	(608,960)
Purchase of leased vessels	46,442
Proceeds from Sale of Available-for-sale Securities, Equity		10,622
Acquisitions of businesses, net of cash acquired		(24,327)	(23,797)
Cash Proceeds From Sales of Assets And Businesses	14,110	147,305	6,292
Proceeds from Insurance Settlement, Investing Activities			22,650
Other	2,290	7,767	(1,753)
Net Cash Provided by (Used in) Investing Activities, Total	(388,268)	(474,735)	(605,568)
Cash flows from financing activities:
Repayments of Long-term Lines of Credit	(7,475)	(14,736)	(581,771)
Proceeds from Long-term Lines of Credit	7,475	14,736	581,771
Payment to extinguish capital lease obligation	20,933
Proceeds from issuance of long-term debt	14,733	2,602
Principal payments of long-term debt	(21,038)	(21,564)	(170,000)
Share repurchases		(299,734)	(10,627)
Cash dividends	(48,139)	(49,756)
Proceeds from exercise of stock options	8,820	10,560	6,264
Proceeds from issuance of stock through employee benefit plans	4,803	4,870	4,124
Other	(2,302)	724	(6,840)
Net Cash Provided by (Used in) Financing Activities, Total	(68,859)	(357,168)	(181,203)
Effect of exchange rate changes on cash	(4,514)	(4,109)	(1,189)
Net increase in cash and cash equivalents	170,971	196,999	104,848
Cash and cash equivalents at beginning of period	393,046	196,047	91,199
Cash and cash equivalents at end of period	$ 564,017	$ 393,046	$ 196,047

Supplemental Cash Flow Informat

Supplemental Cash Flow Information	12 Months Ended
	Dec. 31, 2015
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	(2) Supplemental Cash Flow Information The following table includes the Company’s supplemental cash flow information (in thousands): Years Ended December 31, 2015 2014 2013 Cash paid for interest $ 93,946 $ 102,880 $ 97,129 Cash paid for income taxes, net of refunds $ 40,074 $ 127,132 $ 164,158 Details of business acquisitions: Fair value of assets $ - $ 29,468 $ 34,964 Fair value of liabilities - (5,125) (10,942) Common stock issued - - - Cash paid - 24,343 24,022 Less cash acquired - (16) (225) Net cash paid for acquisitions $ - $ 24,327 $ 23,797 Non-cash investing activity: Capital expenditures included in accounts payable, accrued expenses and other long term liabilities $ 28,704 $ 49,118 $ 70,463 Non-cash financing activity: Cash dividends declared $ - $ - $ 12,759

Reduction in Value of Assets

Reduction in Value of Assets	12 Months Ended
	Dec. 31, 2015
Reduction In Value Of Assets [Abstract]
Reduction In Value Of Assets	(3) Reduction in Value of Assets and Other Charges During 2015 and 2013, the Company recorded $1,738.9 million and $300.1 million in expense related to reduction in value of assets, respectively. The components of reduction in value of assets are as follows (in thousands): Years Ended December 31, 2015 2013 Reduction in value of goodwill $ 1,326,701 $ 91,016 Reduction in value of long-lived assets 330,194 180,320 Retirements of long-lived assets 42,545 14,418 Reduction in value of assets related to sale of a business 39,447 - Reduction in value of assets related to Venezuela exit activities - 14,324 Total reduction in value of assets $ 1,738,887 $ 300,078 Reduction in Value of Goodwill During 2015, the Company recorded $1,326.7 million reduction in value of goodwill relating to its Onshore Completion and Workover Services and Production Services segments. The Company determined that the implied fair value of its goodwill for the Onshore Completion and Workover Services segment was less than its carrying value and recorded a $740.0 million impairment of the Onshore Completion and Workover Services segment’s goodwill. In addition, the Company determined that the implied fair value of its goodwill for the Production Services segment was less than its carrying value and recorded a $586.7 million impairment of the Production Services segment’s goodwill. The reduction in value of goodwill in the Production Services segment was primarily driven by the continued decline in demand for coiled tubing services. The reduction in value of goodwill in the Onshore Completion and Workover Services and Production Services segments was primarily driven by further deterioration of market conditions during the year and the Company’s forecast did not indicate a timely recovery sufficient to support the carrying values of the goodwill. During 2013, the Company recorded $91.0 million reduction in value of goodwill relating to its Technical Solutions segment. The Company performed its annual test for goodwill, which indicated that the carrying value of the Technical Solutions segment exceeded its fair value, indicating that goodwill was potentially impaired. The Company determined that the implied fair value of the goodwill for the Technical Solutions segment was less than its carrying value and fully wrote-off the goodwill balance of $91.0 million. The reduction in value of goodwill in the Technical Solutions segment was primarily driven by the decline in demand for services in the subsea construction and marine technical services divisions. During 2013, the demand for these services continued to decline and the forecast for these markets did not indicate a timely recovery sufficient to support the carrying value of the goodwill. Reduction in Value of Long-Lived Assets During 2015, the Company recorded $330.2 million in connection with the reduction in value of its long-lived assets. The reduction in value of assets was comprised of $89.7 million related to equipment and $59.5 million related to intangibles in the coiled tubing business and pressure control tools businesses within the Production Services segment. The reduction in value of assets in the Production Services segment was primarily driven by the decline in demand for coiled tubing services. The demand for these services continued to decline and the Company’s forecast did not indicate a timely recovery sufficient to support the carrying values of these assets. The reduction in value of assets also included $68.9 million related to the reduction in carrying values of the marine vessels and equipment included in the marine technical services division in the Technical Solutions segment. The reduction in value of assets in the Technical Solutions segment was primarily as a result of the termination of the contract with a certain marine technical services division’s customer. Further, the reduction in value of assets also included $56.0 million related to impairment of the Gulf of Mexico oil and gas property which is included in the Technical Solutions segment. In addition, the reduction in value of assets included a $40.2 million, primarily related to reduction in carrying values of certain domestic and international accommodation units and premium drill pipe included in the Drilling Products and Services segment and $15.9 million related to mechanical drilling rigs included in the Onshore Completion and Workover Services segment. The reduction in value of assets in the Drilling Products and Services segment was primarily driven by the decrease in demand for the rental of accommodation units, changes in the regulatory requirements and a decrease in the Company’s forecast for future rentals of these units. The reduction in value of assets in the Onshore Completion and Workover Services segment related to the reduction in carrying values of the mechanical drilling rigs, primarily as a result of the decreased demand for certain mechanical drilling rigs driven by the downturn in the oil and gas market. During 2013, the Company recorded $ 180.3 million in connection with reduction in value of its long-lived assets and related other assets. The reduction in value of assets was comprised of $122.8 million related to certain marine equipment and related write-off of other assets of $31.9 million included in the Technical Solutions segment, $11.4 million related to equipment in the coiled tubing division within the Production Services segment and $11.2 million related to mechanical drilling rigs included in the Onshore Completion and Workover Services segment. In addition, the Company recorded a $3.0 million related to reduction in carrying values of the intangible assets in the coiled tubing business in the Production Services segment. The reduction in value of assets in the Technical Solutions segment was primarily driven by the decline in demand for services in the Company’s marine technical services business. During 2013, the demand for these services continued to decline and the forecast for these markets did not indicate a timely recovery sufficient to support the carrying values of these assets. The reduction in value of assets in the Onshore Completion and Workover Services segment related to the reduction in carrying values of the mechanical drilling rigs, primarily driven by the shift in customer demand away from mechanically powered rigs to electrically powered drilling rigs. The reduction in value of assets in the Production Services segment related to the coiled tubing business in Mexico and was primarily driven by the decrease in demand for the Company’s services during 2013 coupled with a decrease in the forecast for future activities in that region. Retirements of Long-Lived Assets During 2015, the Company recorded $42.5 million for retirement and abandonment of inoperable and/or functionally obsolete long-lived assets that would require a significant cost to refurbish. The total amount recorded includes $27.3 million for the Onshore Completion and Workover Services segment and $15.2 million for the Production Services segment. During 2013, the Company recorded $ 14.4 million for retirement and abandonment of inoperable and/or functionally obsolete long-lived assets. The total amount recorded includes $6.4 million for Technical Solutions segment, $5.8 million for Onshore Completion and Workover Services segment and $2.2 million for Production Services segment. Reduction in Value of Assets Related to Sale of Coiled Tubing Business in Mexico During 2015, the Company sold its Mexico based coiled tubing business and related assets. The Company received proceeds in the form of cash and a note receivable. The Company recorded a full valuation allowance on the note receivable in the amount of $16.8 million because its collectability was not reasonably assured. In connection with the sale, the Company recorded a $39.4 million reduction in value of assets, primarily related to property, plant and equipment and intangible assets. Reduction in Value of Assets Related to Venezuela Exit Activities In November 2013, the government of Venezuela seized two of the Company’s hydraulic snubbing units from its facility in Anaco, Venezuela. As a result, the Company recorded a $14.3 million reduction in value of net assets, primarily related to accounts receivable, prepaid expenses and property, plant and equipment. During 2013, the Company generated $9.5 million, in revenue from its operations in Venezuela. Other Charges During 2015, in connection with the reorganization of several of its businesses, the Company recorded $46.8 million relating to reduction in force expense and reorganization costs. The Company’s reorganization plan resulted in the consolidation of certain of its product lines and rationalization of the related facilities and offices. Included in the total reorganization costs is $20.2 million relating to the impairment of certain real estate operating leases included in the Onshore Completion and Workover Services segment. As of December 31, 2015, the accrued lease termination liability balances were $7.2 million and $11.1 million, included in accrued expenses and other long-term liabilities, respectively, on the consolidated balance sheet.

Discontinued Operations

Discontinued Operations	12 Months Ended
	Dec. 31, 2015
Discontinued Operations [Abstract]
Discontinued Operations	(4) Discontinued Operations Discontinued operations results include operating results for both of the Company’s subsea construction and conventional decommissioning businesses. Unfavorable oil and gas market conditions that have negatively impacted the demand for the assets included in these businesses. Therefore, the remaining assets of these businesses were not disposed of during the initial one-year period. As of December 31, 2015, these assets were being actively marketed and the Company’s management is committed to selling the remaining assets. Both the subsea construction business and conventional decommissioning business were included in the Technical Solutions segment. As of December 31, 2015 , the assets and liabilities of these businesses were classified as held for sale. The results of operations of these businesses for 2015, 2014 and 2013 are reported as discontinued operations in the consolidated statements of operations. The following table summarizes the components of loss from discontinued operations, net of tax (in thousands): Years Ended December 31, 2015 2014 2013 Revenues $ 18,723 $ 145,463 $ 261,767 Loss from discontinued operations, net of tax benefit of $5,626, $19,330 and $15,439 for 2015, 2014 and 2013, respectively $ (46,955) $ (22,973) $ (156,903) During 2015, loss from discontinued operations included $25.8 million and $8.8 million for the reduction in value of marine vessels in the subsea construction and conventional decommissioning businesses, respectively. During 2014, loss from discontinued operations included an $ 18.8 million gain related to the sale of marine vessels and equipment in the subsea construction business. During 2013, loss from d iscontinued operations included $119.3 million related to the reduction in value of assets. The reduction in v alue of assets included a $98.3 million charge primarily relating to certain marine vessels included in the subsea construction business; a $15.4 million expense relating to reduction in carrying values of the intangible assets in the subsea construction business; and a $5.6 million expense relating to the retirement of long-lived assets in the conventional decommissioning business. The following summarizes the assets and liabilities related to the businesses reported as discontinued operations (in thousands): December 31, 2015 2014 Accounts receivable, net $ 1,234 $ 16,701 Prepaid expenses 330 2,463 Inventory and other current assets 1,036 5,576 Current assets $ 2,600 $ 24,740 Property, plant and equipment, net 92,634 91,171 Intangible and other long-term assets, net - 769 Long-term assets $ 92,634 $ 91,940 Accounts payable 1,007 20,530 Accrued expenses 3,654 24,496 Current liabilities $ 4,661 $ 45,026 Other long-term liabilities $ - $ 16,814 During 2015, the Company spent $ 46.4 million to purchase two leased vessels in its subsea construction business. In addition, the purchase price for one of the vessels included the extinguishment of the related capital lease obligation of $20.9 million. The purchases were made to eliminate ongoing lease payments and facilitate the disposition of the vessels.

Property, Plant And Equipment

Property, Plant And Equipment	12 Months Ended
	Dec. 31, 2015
Property, Plant And Equipment [Abstract]
Property, Plant And Equipment	(5) Property, Plant and Equipment A summary of property, plant and equipment is as follows (in thousands): December 31, 2015 2014 Buildings, improvements and leasehold improvements $ 318,906 $ 328,651 Marine vessels and equipment 87 55,494 Machinery and equipment 3,770,959 4,126,570 Automobiles, trucks, tractors and trailers 45,013 66,032 Furniture and fixtures 67,483 75,631 Construction-in-progress 74,683 102,895 Land 58,731 58,814 Oil and gas producing assets 66,285 189,294 Total 4,402,147 5,003,381 Accumulated depreciation and depletion (2,278,856) (2,269,542) Property, plant and equipment, net $ 2,123,291 $ 2,733,839 The Company had $ 84.9 million and $ 93.3 million of leasehold improvements as of December 31, 2015 and 2014 , respectively. These leasehold improvements are depreciated over the shorter of the life of the asset or the term of the lease using the straight line method. Depreciation expense (excluding depletion, amortization and accretion) was $ 584.1 million, $ 620.6 million, and $ 572.9 million during 2015, 2014 and 2013 , respectively. During 2015, the Company recorded $343.3 million related to reduction in value of property, plant and equipment (see note 3).

Debt

Debt	12 Months Ended
	Dec. 31, 2015
Debt [Abstract]
Debt	(6) Debt The Company’s outstanding debt is as follows (in thousands): December 31, 2015 2014 Long-term Current Long-term Current Term loan due February 2017 $ 305,000 $ 20,000 $ 325,000 $ 20,000 Senior Notes due May 2019 500,000 - 500,000 - Senior Notes due December 2021 800,000 - 800,000 - Other 3,089 9,957 2,842 941 Total debt, gross 1,608,089 29,957 1,627,842 20,941 Unamortized debt issuance costs (19,826) - (27,469) - Total debt $ 1,588,263 $ 29,957 $ 1,600,373 $ 20,941 Debt maturities presented as of December 31, 2015 are as follows (in thousands): 2016 $ 29,957 2017 306,705 2018 1,384 2019 500,000 2020 - Thereafter 800,000 Total $ 1,638,046 Credit Facility At December 31, 2015, the Company had a credit facility that was comprised of a $600.0 million revolving line of credit and a $325.0 million term loan. In February 2016, the Company amended and extended the credit facility. The amended agreement results in a $470.3 million revolving credit facility which matures in 2019 and no longer has a term loan component. As of February 22, 2016, the Company had $325.0 million of borrowings and $42.2 million of letters of credit outstanding under the amended credit facility. Borrowings under the credit facility bear interest at LIBOR plus margins that depend on our credit rating. Indebtedness under the credit facility is secured by substantially all of the Company’s assets, including the pledge of the stock of its principal domestic subsidiaries. The credit facility contains customary events of default and requires that the Company satisfies various financial covenants. Senior Unsecured Notes The Company has outstanding $ 500 million of 6 3/8% unsecured senior notes due 2019. The indenture governing the 6 3/8% senior notes requires semi-annual interest payments on May 1 st and November 1 st of each year through the maturity date of May 1, 2019. The Company also has outstanding $ 800 million of 7 1/8% unsecured senior notes due 2021. The indenture governing the 7 1/8% senior notes requires semi-annual interest payments on June 15 th and December 15 th of each year through the maturity date of December 15, 2021.

Stock-Based Compensation And Re

Stock-Based Compensation And Retirement Plans	12 Months Ended
	Dec. 31, 2015
Disclosure of Compensation Related Costs, Share-based Payments [Abstract]
Stock-Based and Long-Term Compensation	(7) Stock-Based and Long-Term Compensation Under our 2013 Stock Incentive Plan, the Company may grant non-qualified stock options, restricted stock, restricted stock units and other types of equity based awards. The Compensation Committee determines the recipients of the equity awards, the type of awards made and the required performance measures. During 2015, the plan was amended to increase the number of shares of common stock authorized for issuance under the plan from 8,000,000 to 14,850,000 shares. As of December 31, 2015 , 8,700,000 shares of the Company’s common stock were available for future grants under the plan. Total stock-based compensation expense and the associated tax benefits are as follows (in thousands): Compensation Expense Years Ended December 31, 2015 2014 2013 Stock options $ 3,663 $ 3,900 $ 3,586 Restricted stock 9,219 15,800 21,460 Restricted stock units 19,699 11,282 - Performance share units 10,733 10,688 10,014 Strategic performance share units 2,258 2,404 - Total $ 45,572 $ 44,074 $ 35,060 Tax Benefit Years Ended December 31, 2015 2014 2013 Stock options $ 1,355 $ 1,443 $ 1,327 Restricted stock 3,411 5,846 7,940 Restricted stock units 7,289 4,174 - Total $ 12,055 $ 11,463 $ 9,267 Total stock-based compensation expense is reflected in general and administrative expenses in the consolidated statements of operations. Stock Options Stock options are granted with an exercise price equal to the market price of our ordinary shares at the date of grant. The stock options generally vest in equal installments over three years and expire in ten years from the grant date. Non-vested stock options are generally forfeited upon termination of employment. The Company recognizes compensation expense for stock option grants based on the fair value at the date of grant using the Black-Scholes-Merton option pricing model. The Company uses historical data, among other factors, to estimate the expected volatility and the expected life of the stock options. The risk-free rate is based on the U.S. Treasury yield curve in effect at the time of grant for the expected life of the stock option. The dividend yield is based on our historical dividend payouts. The weighted average fair values of stock options granted and the assumptions used in estimating those fair values are as follows: Years Ended December 31, 2015 2014 2013 Weighted average fair value of grants $ 6.25 $ 6.95 $ 8.98 Black-Scholes-Merton Assumptions: Risk free interest rate 1.33% 1.42% 0.63% Expected life (years) 5 4 4 Volatility 47.07% 34.50% 48.41% Dividend yield 1.30 1.23 - The following table summarizes stock option activity for 2015: Number of Options Weighted Average Option Price Weighted Average Remaining Contractual Term (in years) Aggregate Intrinsic Value (in thousands) Outstanding as of December 31, 2014 4,484,505 $ 23.76 5.1 $ 4,095 Granted 612,665 $ 17.27 Exercised (506,029) $ 17.43 Outstanding as of December 31, 2015 4,591,141 $ 23.60 5.3 $ 256 Exercisable as of December 31, 2015 3,488,262 $ 24.48 4.3 $ 256 Options expected to vest as of December 31, 2015 1,102,879 $ 20.81 8.5 $ - The total intrinsic value of stock options exercised during 2015, 2014 and 2013 was $2.3 million, $ 17.1 million and $5.1 million, respectively. The Company received $ 8.8 million, $10.6 million and $6.3 million during 2015, 2014 and 2013 , respectively, from employee stock option exercises. The Company has reported tax benefits of $ 0.9 million, $5.6 million and $0.7 million from the exercise of stock options for 2015, 2014 and 2013 , respectively. The following table summarizes non-vested stock option activity for 2015: Number of Options Weighted Average Grant Date Fair Value Non-vested as of December 31, 2014 824,488 $ 7.83 Granted 612,665 $ 17.27 Vested (334,274) $ 25.01 Non-vested as of December 31, 2015 1,102,879 $ 20.81 As of December 31, 2015 , the unrecognized compensation expense related to non-vested stock options was $ 3.9 million. The Company expects to recognize $ 2.6 million and $1.3 million of compensation expense during the years 2016 and 2017, respectively. Restricted Stock Shares of restricted stock generally vest in equal annual installments over three years. Non-vested shares are generally forfeited upon termination of employment. Holders of the restricted stock are entitled to all rights of a stockholder of the Company with respect to the restricted stock, including the right to vote the shares and receive any dividends or other distributions. Compensation expense associated with restricted stock is measured based on the grant date fair value of our common stock. The following table summarizes restricted stock activity for 2015: Number of Shares Weighted Average Grant Date Fair Value Non-vested as of December 31, 2014 1,022,280 $ 24.08 Vested (678,880) $ 17.88 Forfeited (50,463) $ 23.26 Non-vested as of December 31, 2015 292,937 $ 23.13 No restricted stock was granted during 2015 and 2014. The weighted average grant-date fair value per share of restricted stock granted during 2013 was $23.14 . The total fair value of restricted stock vested during 2015, 2014 and 2013 was $12.1 million, $23.0 million and $9.6 million, respectively. As of December 31, 2015 , there was $ 0.4 million of unrecognized compensation expense related to non-vested restricted stock, which is expected to be recognized during 2016. Restricted Stock Units Beginning in 2014, restricted stock unit awards (RSUs) were granted to eligible employees. Prior to 2014, only non-employee directors were granted RSU awards. RSUs granted to employees vest in equal annual installments over three years. On the vesting date, each RSU is converted to one share of the Company’s common stock having an aggregate value determined by the Company’s closing stock price on the vesting date. Holders of RSUs are not entitled to any rights of a stockholder, such as the right to vote shares, but will accrue dividends that are paid out upon vesting. Each non-employee director is issued annually a number of RSUs having an aggregate dollar value determined by the Company’s Board of Directors. The exact number of RSUs granted is determined by dividing the aggregate dollar value determined by the Company’s Board of Directors by the fair market value of the Company’s common stock on the day of the annual stockholders’ meeting. If the director’s election occurs at a time other than at the annual meeting, the director will receive a pro-rata number of RSUs based on the number of months between his or her election date and the anniversary of the last annual stockholder meeting. Each RSU granted prior to 2013 represents the right to receive from the Company, within 30 days of the date the director ceases to serve on the Board, one share of the Company’s common stock. The RSUs will vest and pay out in shares of the Company’s common stock in the year following the grant date on the date of Company’s annual meeting. The following table summarizes RSU activity for 2015: Number of Restricted Stock Units Weighted Average Grant Date Fair Value Non-vested as of December 31, 2014 1,416,477 $ 26.40 Granted 2,162,146 $ 17.74 Vested (460,400) $ 18.51 Forfeited (330,334) $ 20.16 Non-vested as of December 31, 2015 2,787,889 $ 20.41 As of December 31, 2015 , there was $30.0 million of unrecognized compensation expense related to unvested RSUs. The Company exp ects to recognize $19.3 million, $10.3 million, and $0.4 million for 2016, 2017, and 2018, respectively. Performance Share Units The Company has issued performance share units (PSUs) to its employees as part of the Company’s long-term incentive program. There is a three -year performance period associated with each PSU grant. The two performance measures applicable to all participants are the Company’s return on invested capital and total stockholder return relative to those of the Company’s pre-defined “peer group.” If the participant has met specified continued service requirements, the PSUs will settle in cash or a combination of cash and up to 50 % of equivalent value in the Company’s common stock, at the discretion of the Compensation Committee of the Board of Directors. As of December 31, 2015 , there were 370,822 PSUs outstanding ( 112,922 , 123,079 and 134,821 related to performance periods ending December 31, 2015, 2016 and 2017, respectively). The Company has recorded both current and long-term liabilities for this liability-based compensation award. Effective February 2014, the Company granted strategic performance share units (SPSUs) to the executive officers of the Company. The number of target SPSUs was established at the beginning of a two-calendar year performance period. The final value of SPSUs earned will be based upon the level of the Company’s free cash flow achieved for 2015 and 2014. The earned SPSUs will vest provided the participant remains actively employed by the Company through January 2, 2016. Employee Stock Purchase Plan In 2013, the stockholders of the Company approved the 2013 Employee Stock Purchase Plan (ESPP). This plan went into effect on July 1, 2013 and replaced the prior plan. Under this plan 3,000,000 shares of common stock were reserved for issuance. Eligible employees are allowed to purchase shares of the Company’s common stock at a discount during six-month offering periods beginning on January 1 and July 1 of each year and ending on June 30 and December 31 of each year, respectively. The following table summarizes ESPP activity (in thousands except shares): Years Ended December 31, 2015 2014 2013 2013 Plan 2013 Plan 2013 and 2007 Plans Cash received for shares issued $ 4,803 $ 4,870 $ 4,124 Compensation expense $ 835 $ 1,078 $ 947 Shares issued 332,467 246,480 185,407 401(k)/Profit Sharing Plan The Company maintains a defined contribution profit sharing plan for employees who have satisfied minimum service requirements. Employees may contribute up to 75 % of their eligible earnings to the plan subject to the contribution limitations imposed by the Internal Revenue Service. The Company provides a nondiscretionary match of 100 % of an employee’s contributions to the plan, up to 4 % of the employee’s salary. The Company made contributions of $ 13.9 million, $ 16.7 million and $ 16.0 million during 2015, 2014 and 2013 , respectively. Non-Qualified Deferred Compensation Plans The Company has a non-qualified deferred compensation plan which allows senior management to defer up to 75 % of their base salary, up to 100 % of their bonus, and up to 100 % of the cash portion of their PSU compensation to the plan. The Company also has a non-qualified deferred compensation plan for its non-employee directors which allows each director to defer up to 100 % of their cash compensation paid by the Company to the plan. Additionally, participating directors may defer up to 100 % of the shares of common stock they are entitled to receive in connection with the payout of RSUs. Payments are made to participants based on their annual enrollment elections and plan balances. Participants earn a return on their deferred compensation that is based on hypothetical investments in certain mutual funds. Changes in market value of these hypothetical participant investments are reflected as an adjustment to the deferred compensation liability of the Company with an offset to compensation expense. The Company makes contributions that approximate the participant deferrals into various investments, principally life insurance that is invested in mutual funds similar to the participants’ hypothetical investment elections. Changes in market value of the investments and life insurance are reflected as adjustments to the deferred compensation plan asset with an offset to other income (expense) in the consolidated statements of operations. The following table summarizes deferred compensation balances (in thousands): December 31, Balance sheet location 2015 2014 Deferred compensation assets Intangible and other long-term assets, net $ 11,548 $ 12,982 Deferred compensation liabilities, short-term Accounts payable $ 721 $ 2,291 Deferred compensation liabilities, long-term Other long-term liabilities $ 17,367 $ 14,720 Supplemental Executive Retirement Plan The Company has a supplemental executive retirement plan (SERP). The SERP provides retirement benefits to the Company’s executive officers and certain other designated key employees. The SERP is an unfunded, non-qualified defined contribution retirement plan, and all contributions under the plan are unfunded credits to a notional account maintained for each participant. Under the SERP, the Company will generally make annual contributions to a retirement account based on age and years of service. The participants in the plan receive contributions ranging from 5 % to 35 % of salary and annual cash bonus, which totaled $ 1.2 million during 2015 , 2014 and 2013 . The Company recorded compensation expense of $2.1 million, $1.6 million and $1.2 million in general and administrative expenses during 2015, 2014 and 2013. The Company may also make discretionary contributions to a participant’s account. During 2015, 2014 and 2013 , the Company paid $ 3.7 million, $3.0 million and $ 3.0 million, respectively, to select participants in the SERP.

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Taxes [Abstract]
Income Taxes	(8) Income Taxes The components of income (loss) from continuing operations before income taxes are as follows (in thousands): Years Ended December 31, 2015 2014 2013 Domestic $ (2,069,019) $ 372,672 $ 165,463 Foreign 9,236 69,517 (64,706) $ (2,059,783) $ 442,189 $ 100,757 The components of income tax expense (benefit) are as follows (in thousands): Years Ended December 31, 2015 2014 2013 Current: Federal $ (952) $ 150,997 $ 19,897 State 2,818 11,339 10,816 Foreign 19,227 36,287 25,613 21,093 198,623 56,326 Deferred: Federal (249,193) (33,172) (6,341) State (10,034) 648 386 Foreign (13,886) (4,700) 4,901 (273,113) (37,224) (1,054) $ (252,020) $ 161,399 $ 55,272 Income tax expense differs from the amounts computed by applying the U.S. Federal income tax rate of 35 % to income (loss) before income taxes as follows (in thousands): Years Ended December 31, 2015 2014 2013 Computed expected tax expense $ (720,923) $ 154,766 $ 35,265 Increase (decrease) resulting from State and foreign income taxes (6,353) 8,467 (852) Reduction in value of assets 464,395 - 34,874 Other 10,861 (1,834) (14,015) Income tax $ (252,020) $ 161,399 $ 55,272 The tax effects of temporary differences that give rise to significant components of deferred income tax assets and liabilities are as follows (in thousands): December 31, 2015 2014 Deferred tax assets: Allowance for doubtful accounts $ 8,275 $ 3,942 Operating loss and tax credit carryforwards 92,798 21,928 Compensation and employee benefits 59,310 57,045 Decommissioning liabilities 30,400 21,029 Other 57,768 50,641 248,551 154,585 Valuation allowance (5,395) - Net deferred tax assets 243,156 154,585 Deferred tax liabilities: Property, plant and equipment 469,728 648,054 Notes receivable 14,796 5,718 Goodwill and other intangible assets 119,661 138,017 Other 22,040 33,654 Deferred tax liabilities 626,225 825,443 Net deferred tax liability $ 383,069 $ 670,858 The net deferred tax assets reflect management’s estimate of the amount that will be realized from future profitability and the reversal of taxable temporary differences that can be predicted with reasonable certainty. A valuation allowance has been recognized on a portion of the state net operating loss carryforward deferred tax asset. After considering all available evidence at December 31, 2015, the Company determined that it was more likely than not that a portion of the carryforward would not be realized. Accordingly, the Company increased deferred income tax expense by the amount of the valuation allowance. As of December 31, 2015 , the Company had $ 102.1 million in U.S. net operating loss carryforwards, which are available to reduce future or prior taxable income. The expiration dates for utilization of the loss carryforwards are 2020 through 2035 . Utilization of $ 0.5 million of the net operating loss carryforwards will be subject to the annual limitations due to the ownership change limitations provided by the Internal Revenue Code of 1986, as amended. As of December 31, 2015 , the Company also had various state net operating loss carryforwards with expiration dates from 2016 to 2030. A net deferred tax asset of $ 25.2 million reflects the expected future tax benefit for the state loss carryforwards. As of December 31, 2015, the Company also had a U.S. foreign tax credit carryforward of $31.8 million. The Company has not provided U.S. income tax expense on earnings of its foreign subsidiaries, since the Company has reinvested or expects to reinvest outside the U.S. the undistributed earnings indefinitely. As of December 31, 2015 , the undistributed earnings of the Company’s foreign subsidiaries were $ 52.0 million. If these earnings are repatriated to the U.S. in the future, additional tax provisions may be required. It is not practicable to estimate the amount of taxes that might be payable on such undistributed earnings. The Company files income tax returns in the U.S., including federal and various state filings, and certain foreign jurisdictions. The number of years that are open under the statute of limitations and subject to audit varies depending on the tax jurisdiction. The Company remains subject to U.S. federal tax examinations for years after 2010. The Company had unrecognized tax benefits of $29.7 million, $ 30.3 million and $ 29.9 million as of December 31, 2015 , 2014 and 2013 , respectively all of which would impact the Company’s effective tax rate if recognized. The activity in unrecognized tax benefits is as follows (in thousands): Years Ended December 31, 2015 2014 2013 Unrecognized tax benefits, December 31, 2014, 2013 and 2012, respectively $ 30,344 $ 29,899 $ 26,399 Additions based on tax positions related to current year - - - Additions based on tax positions related to prior years 6,752 7,860 5,065 Reductions based on tax positions related to prior years (7,381) (7,415) (1,565) Unrecognized tax benefits, December 31, 2015, 2014 and 2013, respectively $ 29,715 $ 30,344 $ 29,899

Segment Information

Segment Information	12 Months Ended
	Dec. 31, 2015
Segment Information [Abstract]
Segment Information	(9) Segment Information Business Segments The Drilling Products and Services segment rents and sells bottom hole assemblies, premium drill pipe, tubulars and specialized equipment for use with onshore and offshore oil and gas well drilling, completion, production and workover activities. It also provides on-site accommodations and machining services. The Onshore Completion and Workover Services segment provides pressure pumping services used to complete and stimulate production in new oil and gas wells, fluid handling services and well servicing rigs that provide a variety of well completion, workover and maintenance services. The Production Services segment provides intervention services such as coiled tubing, cased hole and mechanical wireline, hydraulic workover and snubbing, production testing and optimization, and remedial pumping services. The Technical Solutions segment provides services typically requiring specialized engineering, manufacturing or project planning, including well containment systems, stimulation and sand control services and well plug and abandonment services. It also includes production handling arrangements and the production and sale of oil and gas. For 2015, 2014 and 2013 , operating results for the Company’s subsea construction and conventional decommissioning businesses are reported in discontinued operations (see note 4). Previously those operating results were reported within the Technical Solutions segment. The Company evaluates the performance of its reportable segments based on income or loss from operations. The segment measure is calculated as follows: segment revenues less segment operating expenses, depreciation, depletion, amortization and accretion expense, reduction in value of assets and allocated general and administrative expenses. General and administrative expenses are allocated to the segments based primarily on specific identification and, to the extent that such identification is not practical, other methods which the Company believes to be a reasonable reflection of the utilization of services provided. The Company believes this segment measure is useful in evaluating the performance of its reportable segments because it highlights operating trends and aids analytical comparisons. Summarized financial information for the Company’s segments is as follows (in thousands): 2015 Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Unallocated Total Revenues $ 583,139 $ 934,274 $ 759,606 $ 497,546 $ - $ 2,774,565 Cost of services and rentals (exclusive of items shown separately below) 196,921 773,119 594,286 301,486 - 1,865,812 Depreciation, depletion, amortization and accretion 194,061 225,667 130,267 62,152 - 612,147 General and administrative expenses 127,525 121,289 139,304 122,590 - 510,708 Reduction in value of assets 40,237 783,229 790,517 124,904 - 1,738,887 Income (loss) from operations 24,395 (969,030) (894,768) (113,586) - (1,952,989) Interest expense, net - - (2,013) 1,707 (97,012) (97,318) Other expense - - - - (9,476) (9,476) Income (loss) from continuing operations before income taxes $ 24,395 $ (969,030) $ (896,781) $ (111,879) $ (106,488) $ (2,059,783) 2014 Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Unallocated Total Revenues $ 904,358 $ 1,732,833 $ 1,350,956 $ 568,475 $ - $ 4,556,622 Cost of services and rentals (exclusive of items shown separately below) 282,023 1,205,443 941,030 306,337 - 2,734,833 Depreciation, depletion, amortization and accretion 186,642 233,430 164,672 66,070 - 650,814 General and administrative expenses 149,967 159,687 187,526 127,191 - 624,371 Income from operations 285,726 134,273 57,728 68,877 - 546,604 Interest expense, net - - - 1,577 (98,311) (96,734) Other expense - - - - (7,681) (7,681) Income (loss) from continuing operations before income taxes $ 285,726 $ 134,273 $ 57,728 $ 70,454 $ (105,992) $ 442,189 2013 Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Unallocated Total Revenues $ 820,538 $ 1,607,268 $ 1,434,990 $ 487,261 $ - $ 4,350,057 Cost of services and rentals (exclusive of items shown separately below) 268,127 1,091,956 1,002,628 270,879 - 2,633,590 Depreciation, depletion, amortization and accretion 168,391 216,152 177,532 42,366 - 604,441 General and administrative expenses 136,244 158,448 190,647 112,439 - 597,778 Reduction in value of assets 2,292 16,975 28,568 252,243 - 300,078 Income (loss) from operations 245,484 123,737 35,615 (190,666) - 214,170 Interest expense, net - - - 1,323 (109,225) (107,902) Other income (expense) - - - 836 (6,347) (5,511) Income (loss) from continuing operations before income taxes $ 245,484 $ 123,737 $ 35,615 $ (188,507) $ (115,572) $ 100,757 Identifiable Assets Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Unallocated Total December 31, 2015 $ 1,223,191 $ 1,929,185 $ 967,719 $ 794,149 $ - $ 4,914,244 December 31, 2014 $ 1,284,842 $ 2,993,824 $ 2,098,592 $ 940,524 $ - $ 7,317,782 December 31, 2013 $ 1,237,842 $ 2,961,390 $ 2,158,653 $ 1,009,058 $ - $ 7,366,943 As of December 31, 2015 and 2014 , the Technical Solutions segment included $95.2 million and $116.7 million, respectively, of identifiable assets of the subsea construction and conventional decommissioning businesses that were classified as assets held for sale on the consolidated balance sheets. Capital Expenditures Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Total December 31, 2015 $ 129,504 $ 103,001 $ 72,048 $ 53,673 $ 358,226 December 31, 2014 $ 274,752 $ 152,742 $ 88,870 $ 99,738 $ 616,102 December 31, 2013 $ 246,479 $ 101,854 $ 122,946 $ 137,681 $ 608,960 Geographic Segments The Company attributes revenue to various countries based on the location where services are performed or the destination of the drilling products or equipment sold or rented. Long-lived assets consist primarily of property, plant and equipment and are attributed to various countries based on the physical location of the asset at the end of a period. As of December 31, 2015 and 2014, the assets of the subsea construction and conventional decommissioning businesses were classified as assets held for sale on the consolidated balance sheets. The Company’s revenue attributed to the U.S. and to other countries and the value of its long-lived assets by those locations is as follows (in thousands): Revenues Years Ended December 31, 2015 2014 2013 United States $ 2,185,071 $ 3,848,929 $ 3,674,825 Other Countries 589,494 707,693 675,232 Total $ 2,774,565 $ 4,556,622 $ 4,350,057 Long-Lived Assets December 31, 2015 2014 United States $ 1,799,418 $ 2,416,306 Other Countries 323,873 317,533 Total, net $ 2,123,291 $ 2,733,839

Commitments And Contingencies

Commitments And Contingencies	12 Months Ended
	Dec. 31, 2015
Commitments And Contingencies [Abstract]
Commitments And Contingencies	(10) Commitments and Contingencies The Company leases many of its office, service and assembly facilities under operating leases. In addition, the Company also leases certain assets used in providing services under operating leases. The leases expire at various dates over an extended period of time. Total rent expense was $ 29.6 million, $ 26.2 million and $ 25.6 million during 2015, 2014 and 2013 , respectively. Future minimum lease payments under non-cancelable leases for the five years ending December 31, 2016 through 2020 and thereafter are as follows: $ 45.7 million, $ 32.4 million, $ 23.3 million, $ 16.1 million, $ 10.0 million and $ 25.2 million, respectively. Due to the nature of the Company’s business, the Company is involved, from time to time, in routine litigation or subject to disputes or claims regarding its business activities. Legal costs related to these matters are expensed as incurred. However, based on current circumstances, the Company does not believe that the ultimate resolution of these proceedings, after considering available defenses and any insurance coverage or indemnification rights, will have a material adverse effect on its financial position, results of operations or cash flows.

Fair Value Measurements

Fair Value Measurements	12 Months Ended
	Dec. 31, 2015
Fair Value Measurements [Abstract]
Fair Value Measurements	(11) Fair Value Measurements The following tables provide a summary of the financial assets and liabilities measured at fair value on a recurring basis (in thousands): Fair Value Measurements at Reporting Date Using December 31, 2015 Level 1 Level 2 Level 3 Intangible and other long-term assets, net Non-qualified deferred compensation assets $ 11,548 $ 368 $ 11,180 - Interest rate swaps $ 6,905 - $ 6,905 - Accounts payable Non-qualified deferred compensation liabilities $ 721 - $ 721 - Other long-term liabilities Non-qualified deferred compensation liabilities $ 17,367 - $ 17,367 - December 31, 2014 Level 1 Level 2 Level 3 Intangible and other long-term assets, net Non-qualified deferred compensation assets $ 12,982 $ 1,481 $ 11,501 - Interest rate swaps $ 4,183 - $ 4,183 - Accounts payable Non-qualified deferred compensation liabilities $ 2,291 - $ 2,291 - Other long-term liabilities Non-qualified deferred compensation liabilities $ 14,720 - $ 14,720 - The Company’s non-qualified deferred compensation plans allow officers, certain highly compensated employees and non-employee directors to defer receipt of a portion of their compensation and contribute such amounts to one or more hypothetical investment funds (see note 7). The Company entered into separate trust agreements, subject to general creditors, to segregate assets of each plan and reports the accounts of the trusts in its consolidated financial statements. These investments are reported at fair value based on unadjusted quoted prices in active markets for identifiable assets and observable inputs for similar assets and liabilities, which represent Levels 1 and 2, respectively, in the fair value hierarchy. The Company has three interest rate swap agreements related to its fixed rate debt maturing in 2021 for notional amounts of $100 million each, whereby the Company is entitled to receive semi-annual interest payments at a fixed rate of 7 1/8% per annum and is obligated to make semi-annual interest payments at floating rates, which are adjusted every 90 days, based on LIBOR plus a fixed margin. The swap agreements, scheduled to terminate on December 15, 2021, are designated as fair value hedges of a portion of the Company’s 7 1/8% senior notes, as the derivative has been tested to be highly effective in offsetting changes in the fair value of the underlying note. As these derivatives are classified as fair value hedges, the changes in the fair value of the derivatives are offset against the changes in the fair value of the underlying note in interest expense, net (see note 12). The following table reflects the fair value measurements used in testing the impairment of long-lived assets and goodwill (in thousands): Years Ended December 31, 2015 2013 Impairment Fair Value Impairment Fair Value Property, plant and equipment, net $ 177,442 $ 179,612 $ 243,781 $ 328,876 Goodwill $ 1,326,701 $ 998,288 $ 91,016 $ - Intangible assets $ 68,890 $ 6,345 $ 18,296 $ 4,355 Fair value is measured as of the impairment date using Level 3 inputs. See note 3 for discussion of reduction in value of assets recorded during 2015 and 2013.

Derivative Financial Instrument

Derivative Financial Instruments	12 Months Ended
	Dec. 31, 2015
Derivative Financial Instruments [Abstract]
Derivative Financial Instruments	(12) Derivative Financial Instruments From time to time, the Company may enter into interest rate swaps in an attempt to achieve a more balanced debt portfolio between fixed and variable debt. The Company does not use derivative financial instruments for trading or speculative purposes. The Company has three interest rate swaps for notional amounts of $100 million each related to its 7 1/8% senior notes maturing in December 2021. These transactions are designated as fair value hedges since the swaps hedge against the change in fair value of fixed rate debt resulting from changes in interest rates. The Company recorded a derivative asset of $6.9 million and $4.2 million within intangible and other long term assets in the consolidated balance sheets as of December 31, 2015 and 2014 , respectively, relating to these swaps . The changes in fair value of the interest rate swaps are included in the adjustments to reconcile net income/loss to net cash provided by operating activities in the consolidated statements of cash flows. The location and effect of the derivative instrument on the consolidated statements of operations presented on a pre-tax basis is as follows (in thousands): Years Ended December 31, Effect of derivative instrument Location of (gain) loss recognized 2015 2014 2013 Interest rate swap Interest expense, net $ (1,932) $ (11,054) $ 13,079 Hedged item - debt Interest expense, net (790) 7,208 (12,303) $ (2,722) $ (3,846) $ 776 During 2015, 2014 and 2013 , $ 2.7 million of interest income, $ 3.8 million of interest income and $ 0.8 million of interest expense, respectively, was related to the ineffectiveness associated with these fair value hedges. Hedge ineffectiveness represents the difference between the changes in fair value of the derivative instruments and the changes in fair value of the fixed rate debt attributable to changes in the benchmark interest rate.

Related Party Transactions

Related Party Transactions	12 Months Ended
	Dec. 31, 2015
Related Party Transactions [Abstract]
Related Party Transactions	(13) Related Party Transactions During 2014 and 2013, the Company purchased services, products and equipment, as well as leased certain facilities, from companies affiliated with a former officer, who retired during the first quarter of 2015, of one of its subsidiaries. During 2014 and 2013, these transactions totaled $221.1 million and $164.8 million, respectively. During 2014, $ 92.1 million was purchased from ORTEQ Energy Services, a heavy equipment construction company which also manufactures pressure pumping equipment, $ 0.7 million was purchased from Ortowski Construction, primarily related to the manufacture of pressure pumping units, $ 21.6 million was paid to Resource Transport, LLC, related to the transportation of sand used in pressure pumping equipment, $ 79.3 million was purchased from Texas Specialty Sands, LLC primarily for the purchase of sand used for pressure pumping activities, $ 25.5 million was purchased from ProFuel, LLC, primarily related to the purchase of diesel used to operate equipment and trucks and $ 1.9 million was related to facilities leased from Timber Creek Real Estate Partners. During 2013, $52.8 million was purchased from ORTEQ Energy Services, $14.0 million was paid to Resource Transport, LLC, $69.1 million was purchased from Texas Specialty Sands, LLC, $26.9 million was purchased from ProFuel, LLC, and $2.0 million was related to facilities leased from Timber Creek Real Estate Partners. As of December 31, 2014, the Company’s trade accounts payable includes amounts due to these companies totaling $ 26.8 million, of which $ 10.1 million was due ORTEQ Energy Services, $ 1.7 million was due Resource Transport, $ 14.0 million was due Texas Specialty Sands, and $ 1.0 million was due ProFuel, LLC. No amounts were due Ortowski Construction and Timber Creek Real Estate Partners. The Company’s President and Chief Executive Officer serves as an independent director of the board of Linn Energy, LLC (Linn), an independent oil and gas development company. The Company recorded revenues from Linn of $7.2 million, $ 19.7 million and $26.9 million during 2015, 2014 and 2013 , respectively. The Company had trade receivables from Linn of $2.0 million and $ 1.6 million as of December 31, 2015 and 2014 , respectively.

Interim Financial Information (

Interim Financial Information (Unaudited)	12 Months Ended
	Dec. 31, 2015
Interim Financial Information (Unaudited) [Abstract]
Interim Financial Information (Unaudited)	(14) Interim Financial Information (Unaudited) The following is a summary of consolidated interim financial information (in thousands): 2015 First Quarter Second Quarter Third Quarter Fourth Quarter Revenues $ 917,235 $ 710,784 $ 601,396 $ 545,150 Less: Cost of services and rentals 582,246 465,533 420,485 397,548 Depreciation, depletion, amortization and accretion 162,220 158,352 146,757 144,818 Gross profit 172,769 86,899 34,154 2,784 Reduction in value of assets - 807,637 755,632 175,618 Net loss from continuing operations (1,497) (775,132) (816,587) (214,547) Loss from discontinued operations, net of tax (9,640) (9,857) (4,610) (22,848) Net loss (11,137) (784,989) (821,197) (237,395) Loss per share from continuing operations: Basic and diluted $ (0.02) $ (5.15) $ (5.42) $ (1.43) Loss per share from discontinued operations: Basic and diluted $ (0.06) $ (0.07) $ (0.03) $ (0.15) 2014 First Quarter Second Quarter Third Quarter Fourth Quarter Revenues $ 1,061,418 $ 1,107,552 $ 1,209,026 $ 1,178,626 Less: Cost of services and rentals 651,605 650,293 721,692 711,243 Depreciation, depletion, amortization and accretion 162,318 160,965 170,154 157,377 Gross profit 247,495 296,294 317,180 310,006 Net income from continuing operations 42,626 79,057 85,743 73,364 Loss from discontinued operations, net of tax (5,954) (3,895) (5,886) (7,238) Net income 36,672 75,162 79,857 66,126 Earnings per share from continuing operations: Basic $ 0.27 $ 0.51 $ 0.55 $ 0.49 Diluted 0.27 0.50 0.55 0.48 Loss per share from discontinued operations: Basic and diluted $ (0.04) $ (0.03) $ (0.03) $ (0.05)

Supplementary Oil And Natural G

Supplementary Oil And Natural Gas Disclosures (Unaudited)	12 Months Ended
	Dec. 31, 2015
Supplementary Oil And Natural Gas Disclosures [Abstract]
Supplementary Oil And Natural Gas Disclosures (Unaudited)	(15) Supplementary Oil and Natural Gas Disclosures (Unaudited) The Company’s December 31, 2015 and 2014 estimates of proved reserves are based on reserve reports prepared by Ryder Scott Company, L.P., independent petroleum engineers. The Company’s December 31, 2013 estimates of proved reserves are based on reserve reports prepared by Netherland, Sewell & Associates, Inc., independent petroleum engineers. Users of this information should be aware that the process of estimating quantities of “proved”, “proved developed” and “proved undeveloped” natural gas and crude oil reserves is very complex, requiring significant subjective decisions in the evaluation of all available geological, engineering and economic data for each reservoir. This data may also change substantially over time as a result of multiple factors including, but not limited to, additional development activity, evolving production history and continual reassessment of the viability of production under varying economic conditions. Consequently, material revisions to existing reserve estimates occur from time to time. Although every reasonable effort is made to ensure that reserve estimates reported represent the most accurate assessments possible, the significance of the subjective decisions required and variances in available data for various reservoirs make these estimates generally less precise than other estimates presented in connection with financial statement disclosures. Proved reserves are estimated quantities of natural gas, crude oil and condensate that geological and engineering data demonstrate, with reasonable certainty, to be recoverable in future years from known reservoirs under existing economic and operating conditions. Proved developed reserves are proved reserves that can be expected to be recovered through existing wells with existing equipment and operating methods. Proved undeveloped reserves are proved reserves that are expected to be recovered from new wells on undrilled acreage, or from existing wells where a relatively major expenditure is required for completion. Oil and Natural Gas Reserves The following table sets forth the Company’s net proved reserves, including the changes therein, and proved developed reserves: Crude Oil Natural Gas (Mbbls) (Mmcf) Proved-developed and undeveloped reserves: December 31, 2012 8,207 11,284 Revisions (3,203) (4,036) Production (411) (296) December 31, 2013 4,593 6,952 Revisions (438) 1,431 Production (738) (1,247) December 31, 2014 3,417 7,136 Revisions (381) (245) Production (633) (1,517) December 31, 2015 2,403 5,374 Proved-developed reserves: December 31, 2013 2,397 2,100 December 31, 2014 3,184 6,945 December 31, 2015 2,202 5,216 Proved-undeveloped reserves: December 31, 2013 2,196 4,852 December 31, 2014 233 191 December 31, 2015 201 158 Costs Incurred in Oil and Natural Gas Activities The following table displays certain information regarding the costs incurred associated with finding, acquiring and developing the Company’s proved oil and natural gas reserves (in thousands): Years Ended December 31, 2015 2014 2013 Acquisition of properties - proved $ - $ - $ - Acquisition of properties - unproved - - - Exploratory costs - - - Development costs 20,636 52,719 51,527 Total costs incurred $ 20,636 $ 52,719 $ 51,527 Capitalized costs for oil and gas producing activities consist of the following (in thousands): December 31, 2015 2014 Proved oil and gas properties $ 66,285 $ 189,294 Accumulated depreciation, depletion and amortization - (55,864) Capitalized costs, net $ 66,285 $ 133,430 Productive Wells Summary The following table presents the Company’s ownership of productive oil wells as of December 31, 2015 . Productive wells consist of producing wells and wells capable of production. In the table, “gross” refers to the total wells in which the Company owns a working interest and “net” refers to the sum of fractional interests owned in gross wells. Productive Wells Gross Net Oil 11.00 5.61 Acreage The following table sets forth information as of December 31, 2015 relating to acreage held by the Company. Developed acreage is assigned to productive wells. Gross Net Acreage Acreage Developed 23,040 11,750 Undeveloped - - Total 23,040 11,750 Drilling Activity The following table shows the Company’s drilling activity. In the table, “gross” refers to the total wells in which the Company has a working interest and “net” refers to the gross wells multiplied by the Company’s working interest in these wells. Well activity refers to the number of wells completed during a fiscal year, regardless of when drilling first commenced. Years Ended December 31, 2015 2014 Gross Net Gross Net Exploratory Wells Productive - - - - Non-productive - - - - Total - - - - Development Wells Productive 1.00 0.51 2.00 1.02 Non-productive 1.00 0.51 1.00 0.51 Total 2.00 1.02 3.00 1.53 Results of Operations The following table sets forth the Company’s results of operations for producing activities (in thousands): Years Ended December 31, 2015 2014 2013 Revenues Sales $ 30,245 $ 77,845 $ 47,050 Production costs 15,466 13,529 9,876 Exploration expenses - - - Depreciation, depletion and amortization 37,623 38,768 12,032 Reduction in value of assets 56,000 - - (78,844) 25,548 25,142 Income tax expenses (28,778) 9,325 8,800 Results of operations from producing activities (excluding corporate overhead) $ (50,066) $ 16,223 $ 16,342 The Company’s oil and gas operations are in the Gulf of Mexico. The Company’s average sales price was $47.17 per barrel of oil and $2.82 per mcf of gas during 2015 , $92.86 per barrel of oil and $4.95 per mcf of gas during 2014 and $ 101.85 per barrel of oil and $ 3.98 per mcf of gas during 2013 . Average production costs were $10.38 , $7.29 and $10.70 per barrel of oil equivalent during 2015, 2014 and 2013 , respectively. Standardized Measure of Discounted Future Net Cash Flows Relating to Reserves The following information has been developed utilizing procedures prescribed by authoritative guidance related to oil and gas activities. It may be useful for certain comparative purposes, but should not be solely relied upon in evaluating the Company or its performance. Further, information contained in the following table should not be considered as representative of realistic assessments of future cash flows, nor should the standardized measure of discounted future net cash flows be viewed as representative of the current value of the Company. The Company believes that the following factors should be taken into account in reviewing this information: (1) future costs and selling prices will likely differ from those required to be used in these calculations; (2) due to future market conditions and governmental regulations, actual rates of production achieved in future years may vary significantly from the rate of production assumed in the calculations; (3) selection of a 10 % discount rate is arbitrary and may not be reasonable as a measure of the relative risk inherent in realizing future net oil and gas revenues; and (4) future net revenues may be subject to different rates of income taxation. Under the standardized measure, future cash inflows were estimated by applying period-end oil and natural gas prices adjusted for differentials. Future cash inflows were reduced by estimated future development, abandonment and production costs based on period-end costs in order to arrive at net cash flow before tax. Future income tax expense has been computed by applying period-end statutory tax rates to aggregate future net cash flows, reduced by the tax basis of the properties involved and tax carryforwards. Use of a 10% discount rate is required by authoritative guidance related to oil and gas activities. The standardized measure of discounted future net cash flows relating to proved oil and natural gas reserves is as follows (in thousands): Years Ended December 31, 2015 2014 2013 Future cash inflows $ 127,048 $ 336,944 $ 496,704 Future production costs (43,010) (71,209) (82,487) Future development and abandonment costs (84,090) (111,374) (156,340) Future income tax expenses 1,353 (60,345) (89,507) Future net cash flows 1,301 94,016 168,370 10% annual discount for estimated timing of cash flows (19,762) (17,034) 10,641 Standardized measure of discounted future net cash flows $ 21,063 $ 111,050 $ 157,729 For 2015 and 2014, the 10% annual discount for the estimated timing of cash flows resulted in a negative discount as a result of significant decreases in future cash inflows due to decreases in oil and gas prices along with lower reserve estimates. A summary of the changes in the standardized measure of discounted future net cash flows applicable to proved oil and natural gas reserves is as follows (in thousands): Years Ended December 31, 2015 2014 2013 Beginning of the period $ 111,050 $ 157,729 $ 303,430 Net change in sales and transfer prices and in production (lifting) costs related to future production (143,808) (57,568) (13,278) Changes in estimated future development costs 3,787 (5,512) (48,594) Sales and transfers of oil and gas produced during the period (14,779) (64,316) (45,866) Net change due to extensions, discoveries, and improved recovery 6,737 - 75,304 Net changes due to revisions in quantity estimates (36,397) (8,396) (228,620) Previously estimated development costs incurred during the period 20,636 40,962 10,136 Accretion of discount 17,606 24,251 46,711 Other-unspecified 1,895 4,125 (24,169) Net change in income taxes 54,336 19,775 82,675 Aggregate change in the standardized measure of discounted future net cash flows for the year (89,987) (46,679) (145,701) End of the period $ 21,063 $ 111,050 $ 157,729 The December 31, 2015 amount was estimated by Ryder Scott Company, L.P. using a twelve month average WTI price of $50.28 per barrel (bbl), and a Henry Hub gas price of $2.66 per million British Thermal Units, and price differentials. The December 31, 2014 amount was estimated by Ryder Scott Company, L.P. using a twelve month average WTI price of $ 94.99 per barrel (bbl), and a Henry Hub gas price of $ 4.35 per million British Thermal Units, and price differentials. The December 31, 2013 amount was estimated by Netherland, Sewell & Associates, Inc. using a twelve month average WTI price of $93.42 per barrel (bbl), and a Henry Hub gas price of $3.670 per million British Thermal Units, and price differentials.

Valuation and Qualifying Accoun

Valuation and Qualifying Accounts	12 Months Ended
	Dec. 31, 2015
Valuation and Qualifying Accounts [Abstract]
Schedule II Valuation and Qualifying Accounts	SUPERIOR ENERGY SERVICES, INC. AND SUBSIDIARIES Schedule II Valuation and Qualifying Accounts Years Ended December 31, 2015 , 2014 and 2013 (in thousands) Balance at the Charged to beginning of costs and Discontinued Balance at the Description the year expenses Deductions operations end of the year 2015: Allowance for doubtful accounts $ 22,076 $ 14,341 $ 4,795 $ 3,380 $ 28,242 2014: Allowance for doubtful accounts $ 31,030 $ 6,299 $ 10,639 $ 4,614 $ 22,076 2013: Allowance for doubtful accounts $ 28,715 $ 7,587 $ 7,763 $ (2,491) $ 31,030

Summary Of Significant Accounti

Summary Of Significant Accounting Policies (Policy)	12 Months Ended
	Dec. 31, 2015
Summary Of Significant Accounting Policies [Abstract]
Basis of Presentation	Basis of Presentation The consolidated financial statements include the accounts of Superior Energy Services, Inc. and subsidiaries (the Company). All significant intercompany accounts and transactions are eliminated in consolidation. Certain previously reported amounts have been reclassified to conform to the 2015 presentation.
Business	Business The Company provides a wide variety of services and products to the energy industry related to the exploration, development and production of oil and natural gas. The Company serves major, national and independent oil and natural gas companies throughout the world. The Company’s operations are managed and organized by business units, which offer products and services within the various phases of a well’s economic life cycle. The Company reports its operating results in four business segments: Drilling Products and Services; Onshore Completion and Workover Services; Production Services; and Technical Solutions. Given the Company’s history of growth and long-term strategy of expanding geographically, the Company also provides supplemental segment revenue information in three geographic areas: U.S. land; Gulf of Mexico; and International.
Use of Estimates	Use of Estimates The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make significant estimates and assumptions that affect the reported amounts of assets and liabilities and disclosure of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from those estimates.
Major Customers and Concentration of Credit Risk	Major Customers and Concentration of Credit Risk The majority of the Company’s business is conducted with major and independent oil and gas companies. The Company evaluates the financial strength of its customers and provides allowances for probable credit losses when deemed necessary. The market for the Company’s services and products is the oil and gas industry in the U.S. land and Gulf of Mexico areas and select international market areas. Oil and gas companies make capital expenditures on exploration, development and production operations. The level of these expenditures historically has been characterized by significant volatility. The Company derives a large amount of revenue from a small number of major and independent oil and gas companies. There were no customers that exceeded 10% of total revenue in 2015 and 2014. In 2013 EOG Resources, Inc. accounted for 10 % of total revenue, primarily within the Onshore Completion and Workover Services segment. In addition to trade receivables, other financial instruments that potentially subject the Company to concentrations of credit risk consist of cash and derivative instruments used in hedging activities. The financial institutions in which the Company transacts business are large, investment grade financial institutions which are “well capitalized” under applicable regulatory capital adequacy guidelines , thereby minimizing it s exposure to credit risks for deposits in excess of federally insured amounts and for failure to perform as the counterparty on interest rate swap agreements. The Company periodically evaluates the creditworthiness of financial institutions that may serve as a counterparty to its derivative instruments .
Cash Equivalents	Cash Equivalents The Company considers all short-term investments with a maturity of 90 days or less when purchased to be cash equivalents.
Accounts Receivable and Allowances	Accounts Receivable and Allowances Trade accounts receivable are recorded at the invoiced amount or the earned amount but not yet invoiced and do not bear interest. The Company maintains allowances for estimated uncollectible receivables, including bad debts and other items. The allowance for doubtful accounts is based on the Company’s best estimate of probable uncollectible amounts in existing accounts receivable. The Company determines the allowance based on historical write-off experience and specific identification.
Inventory	Inventory Inventories are stated at the lower of cost or market. Cost is determined using the first-in, first-out or weighted-average cost methods for finished goods and work-in-process. Supplies and consumables consist principally of products used in the Company’s services provided to its customers. The components of inventory balances are as follows (in thousands): December 31, 2015 2014 Finished goods $ 71,951 $ 72,788 Raw materials 23,418 29,718 Work-in-process 18,203 20,317 Supplies and consumables 35,189 42,739 Total $ 148,761 $ 165,562
Property, Plant and Equipment	Property, Plant and Equipment Property, plant and equipment are stated at cost, except for assets for which reduction in value is recorded during the period and assets acquired using purchase accounting, which are recorded at fair value as of the date of acquisition. With the exception of certain marine assets and oil and natural gas properties, depreciation is computed using the straight line method over the estimated useful lives of the related assets as follows: Buildings and improvements 5 to 40 years Marine vessels and equipment 5 to 25 years Machinery and equipment 2 to 25 years Automobiles, trucks, tractors and trailers 3 to 10 years Furniture and fixtures 2 to 10 years The Company follows the successful efforts method of accounting for its investment in oil and natural gas properties. Under the successful efforts method, the costs of successful exploratory wells and leases containing productive reserves are capitalized. Costs incurred to drill and equip developmental wells, including unsuccessful wells, are capitalized. Other costs such as geological and geophysical costs and the drilling costs of unsuccessful exploratory wells are expensed. Leasehold and well costs are depleted on a units-of-production basis based on the estimated remaining equivalent oil and gas reserves of each field.
Reduction in Value of Long-Lived Assets Text Block	Reduction in Value of Long-Lived Assets Long-lived assets, such as property, plant and equipment and purchased intangibles subject to amortization are reviewed for impairment whenever events or changes in circumstances indicate that the carrying amount of such assets may not be recoverable. Recoverability of assets to be held and used is assessed by a comparison of the carrying amount of such assets to their fair value calculated, in part, by the estimated undiscounted future cash flows expected to be generated by the assets. Cash flow estimates are based upon, among other things, historical results adjusted to reflect the best estimate of future market rates, utilization levels, and operating performance. Estimates of cash flows may differ from actual cash flows due to, among other things, changes in economic conditions or changes in an asset’s operating performance. The Company’s assets are grouped by subsidiary or division for the impairment testing, which represent the lowest level of identifiable cash flows. Impairment testing for these long-lived assets is based on the consolidated entity. If the asset grouping’s fair value is less than the carrying amount of those items, impairment losses are recorded in the amount by which the carrying amount of such assets exceeds the fair value. Assets to be disposed of are reported at the lower of the carrying amount or fair value less estimated costs to sell. The net carrying value of assets not fully recoverable is reduced to fair value. The estimate of fair value represents the Company’s best estimate based on industry trends and reference to market transactions and is subject to variability. The oil and gas industry is cyclical and estimates of the period over which future cash flows will be generated, as well as the predictability of these cash flows, can have a significant impact on the carrying values of these assets and, in periods of prolonged down cycles, may result in impairment charges. See note 3 for a discussion of the reduction in value of long-lived assets recorded during 2015 and 2013.
Goodwill	Goodwill The following table summarizes the activity for the Company’s goodwill (in thousands): Onshore Drilling Completion Products and Workover Production and Services Services Services Total Balance, December 31, 2013 $ 144,872 $ 1,419,550 $ 893,687 $ 2,458,109 Acquisition activities - - 13,909 13,909 Foreign currency translation adjustment (2,033) - (1,576) (3,609) Balance, December 31, 2014 142,839 1,419,550 906,020 2,468,409 Acquisition activities - - 1,170 1,170 Reduction in value of assets - (740,000) (586,701) (1,326,701) Foreign currency translation adjustment (1,557) - (1,220) (2,777) Other - 44,000 (44,000) - Balance, December 31, 2015 $ 141,282 $ 723,550 $ 275,269 $ 1,140,101 Goodwill is tested for impairment annually as of October 1 st or on an interim basis if events or circumstances indicate that the fair value of the asset has decreased below its carrying value. In order to estimate the fair value of the reporting units (which is consistent with the reported business segments), the Company used a weighting of the discounted cash flow method and the public company guideline method of determining fair value of each reporting unit. There is no outstanding goodwill balance associated with the Company’s Technical Solutions segment. The Company weighted the discounted cash flow method 80 % and the public company guideline method 20 % due to differences between the Company’s reporting units and the peer companies’ size, profitability and diversity of operations. In order to validate the reasonableness of the estimated fair values obtained for the reporting units, a reconciliation of fair value to market capitalization was performed for each unit on a standalone basis. A control premium, derived from market transaction data, was used in this reconciliation to ensure that fair values were reasonably stated in conjunction with the Company’s capitalization. These fair value estimates were then compared to the carrying value of the reporting units. If the fair value of the reporting unit exceeds the carrying amount, no impairment loss is recognized. If the estimated fair value of the reporting unit is below the carrying value, then a second step must be performed to determine the goodwill impairment, if any. In this second step, the estimated fair value is used as the purchase price in a hypothetical acquisition of the reporting unit. The hypothetical purchase price is allocated to the reporting unit’s assets and liabilities, with the residual amount representing an implied fair value of the goodwill. The carrying amount of the goodwill is then compared to the implied fair value of the goodwill for each reporting unit and is written down to the implied fair value, if lower. The Company uses all available information to estimate fair value of the reporting units, including discounted cash flows. The Company engages third-party appraisal firms to assist in fair value determination of property, plant and equipment, intangible assets and any other significant assets or liabilities when appropriate. A significant amount of judgment was involved in performing these evaluations since the results are based on estimated future events. See note 3 for a discussion of the reduction in value of goodwill recorded during 2015 and 2013. As of December 31, 2015 and 2014, the Company’s accumulated reduction in value of goodwill was $ 1,417.7 million and $91.0 million, respectively.
Notes Receivable	Notes Receivable The Company’s wholly owned subsidiary, Wild Well has decommissioning obligations related to its ownership of the Bullwinkle platform. Notes receivable consist of a commitment from the seller of the platform towards its eventual abandonment. Pursuant to an agreement with the seller, the Company will invoice the seller an agreed upon amount at the completion of certain decommissioning activities. The gross amount of this obligation totaled $ 115.0 million and is recorded at present value using an effective interest rate of 6.58 %. The related discount is amortized to interest income based on the expected timing of the platform’s removal. During 2015, the Company revised its estimates relating to the timing of decommissioning work on its Bullwinkle assets, due to the changes in the economics of the estimated oil and gas reserves, resulting in a 10 year acceleration of the platform decommissioning to an estimated date of 2028. This change in estimate resulted in an increase of the present value of the note receivable. The Company recorded interest income related to notes receivable of $ 1.7 million, $ 1.6 million and $ 2.6 million during 2015, 2014 and 2013 , respectively.
Intangible and Other Long-Term Assets	Intangible and Other Long-Term Assets Intangible assets consist of the following (in thousands): December 31, 2015 2014 Estimated Gross Accumulated Net Gross Accumulated Net Useful Lives Amount Amortization Balance Amount Amortization Balance Customer relationships 17 years $ 257,364 $ (65,209) $ 192,155 $ 339,695 $ (64,954) $ 274,741 Tradenames 10 years 36,119 (15,371) 20,748 41,265 (13,151) 28,114 Non-compete agreements 3 years 3,242 (2,940) 302 4,487 (3,281) 1,206 Total $ 296,725 $ (83,520) $ 213,205 $ 385,447 $ (81,386) $ 304,061 Amortization expense was $ 23.0 million, $ 25.9 million and $ 26.2 million during 2015, 2014 and 2013 , respectively. Based on the carrying values of intangible assets as of December 31, 2015, amortization expense is estimated to be as follows: $ 19.2 million for 2016, $ 18.6 million for 2017, $ 18.5 million for 2018, $18.3 million for 2019 and $18.0 million for 202 0. During 2015, the Company recorded $68.9 million of expense related to the reduction in carrying values of intangibles primarily in the Production Services segment (see note 3). As of December 31, 2015 and 2014, intangible and other long-term assets, net included $58.4 million of escrowed cash, primarily related to the future decommissioning obligations of the Bullwinkle platform.
Decommissioning Liabilities	Decommissioning Liabilities The Company’s decommissioning liabilities associated with the Bullwinkle platform and its related assets consist of costs related to the plugging of wells, the removal of the related platform and equipment, and site restoration. The Company reviews the adequacy of its decommissioning liabilities whenever indicators suggest that the estimated cash flows needed to satisfy the liability have changed materially. During 2015, the Company revised its estimates relating to the timing and the cost estimates of decommissioning work on its Bullwinkle assets due to changes in the economics of the oil and gas property, including a 10 year acceleration of the platform decommissioning to an estimated date of 2028. This change in estimate resulted in an increase in the present value of decommissioning liabilities. Further, as of December 31, 2015, the Company anticipated that it would be able to decommission several depleted wells that are part of the Bullwinkle assets based on the revised estimates. As a result, the decommissioning liabilities associated with those wells were classified as current liabilities on the consolidated balance sheet. The following table summarizes the activity for the Company’s decommissioning liabilities (in thousands): December 31, 2015 2014 Decommissioning liabilities, December 31, 2014 and 2013, respectively $ 88,000 $ 83,519 Revisions in estimated timing and cash flows 24,660 (276) Accretion 5,016 4,470 Liability acquisitions and dispositions 266 866 Liabilities settled - (579) Total decommissioning liabilities, December 31, 2015 and 2014, respectively $ 117,942 $ 88,000
Revenue Recognition	Revenue Recognition Products and services are generally sold based upon purchase orders or contracts with customers that include fixed or determinable prices. Revenue is recognized when services or equipment are provided and collectability is reasonably assured. The Company’s drilling products and services are billed on a day rate basis, and revenue from the sale of equipment is recognized when the title to the equipment has been transferred. Reimbursements from customers for the cost of drilling products and services that are damaged or lost down-hole are reflected as revenue at the time of the incident. The Company recognizes oil and gas revenue from its interests in producing wells as oil and natural gas is sold. Taxes collected from customers and remitted to governmental authorities are reported on a net basis in the Company’s financial statements.
Income Taxes	Income Taxes The Company accounts for income taxes and the related accounts under the asset and liability method. Deferred income taxes reflect the impact of temporary differences between amounts of assets and liabilities for financial reporting purposes and such amounts as measured by tax laws and rates that are in effect when the temporary differences are expected to reverse. The effect of a change in tax rates on the deferred income taxes is recognized in income in the period in which the change occurs. A valuation allowance is recorded when management believes it is more likely than not that at least some portion of any deferred tax asset will not be realized. It is the Company’s policy to recognize interest and applicable penalties related to uncertain tax positions in income tax expense.
Earnings (Loss) per Share	Earnings per Share Basic earnings per share is computed by dividing income available to common stockholders by the weighted average number of shares of common stock outstanding during the period. Diluted earnings per share is computed in the same manner as basic earnings per share except that the denominator is increased to include the number of additional shares of common stock that could have been outstanding assuming the exercise of stock options and conversion of restricted stock units. During 2015, the Company incurred a loss from continuing operations; therefore the impact of any incremental shares would be anti-dilutive. Stock options for 1,100,000 shares of the Company’s common stock were excluded in the computation of diluted earnings per share for 2014 and 2013, as the effect would have been anti-dilutive.
Fair Value Measurements	Fair Value Measurements Fair value is defined as the price that would be received to sell an asset or the price paid to transfer a liability in an orderly transaction between market participants at the measurement date. Inputs used in determining fair value are characterized according to a hierarchy that prioritizes those inputs based on the degree to which they are observable. The three input levels of the fair value hierarchy are as follows: Level 1 : Unadjusted quoted prices in active markets for identical assets and liabilities; Level 2 : Observable inputs other than those included in Level 1, such as quoted prices for similar assets and liabilities in active markets; quoted prices for identical assets or liabilities in inactive markets or model-derived valuations or other inputs that can be corroborated by observable market data; and Level 3 : Unobservable inputs reflecting management’s own assumptions about the inputs used in pricing the asset or liability.
Financial Instruments	Financial Instruments The fair value of the Company’s financial instruments of cash equivalents, accounts receivable, accounts payable, accrued expenses and borrowings under its credit facility approximates their carrying amounts due to their short maturity or market interest rates. The fair value of the Company’s debt was $ 1,508.0 million and $ 1,624.3 million as of December 31, 2015 and 2014 , respectively, and was categorized as Level 1 in the fair value hierarchy. The fair value of these debt instruments is determined by reference to the market value of the instrument as quoted in an over-the-counter market.
Foreign Currency	Foreign Currency Results of operations for foreign subsidiaries with functional currencies other than the U.S. dollar are translated using average exchange rates during the period. Assets and liabilities of these foreign subsidiaries are translated using the exchange rates in effect at the balance sheet dates, and the resulting translation adjustments are reported as accumulated other comprehensive loss in the Company’s stockholders’ equity. For international subsidiaries where the functional currency is the U.S. dollar, financial statements are remeasured into U.S. dollars using the historical exchange rate for most of the long-term assets and liabilities and the balance sheet date exchange rate for most of the current assets and liabilities. An average exchange rate is used for each period for revenues and expenses. These transaction gains and losses, as well as any other transactions in a currency other than the functional currency, are included in other income (expense) in the consolidated statements of operations in the period in which the currency exchange rates change. During 2015, 2014 and 2013 , the Company recorded $9.6 million, $7.3 million and $ 7.1 million of foreign currency losses, respectively.
Stock-Based Compensation	Stock-Based Compensation The Company records compensation costs relating to share-based payment transactions and includes such costs in general and administrative expenses in the consolidated statements of operations. The cost is measured at the grant date, based on the calculated fair value of the award, and is recognized as an expense over the employee’s requisite service period (generally the vesting period of the equity award). Excess tax benefits of awards that are recognized in equity related to stock option exercises and restricted stock vesting are reflected as financing cash flows.
Derivative Instruments and Hedging Activities	Derivative Instruments and Hedging Activities The Company recognizes all derivative instruments as either assets or liabilities in the balance sheet at their respective fair values. Interest rate swap agreements that are effective at hedging the fair value of fixed-rate debt agreements are designated and accounted for as fair value hedges. The Company also assesses, both at inception of the hedging relationship and on an ongoing basis, whether the derivatives used in hedging relationships are highly effective in offsetting changes in fair value. In an attempt to achieve a more balanced debt portfolio between fixed and variable interest, the Company enters into interest rate swaps. Under these agreements, the Company is entitled to receive semi-annual interest payments at a fixed rate and is obligated to make quarterly interest payments at a variable rate. The Company had fixed-rate interest on 62 % and 61 % of its long-term debt as of December 31, 2015 and 2014 , respectively. The Company had notional amounts of $300 million related to interest rate swaps with a variable interest rate, adjusted every 90 days, based on LIBOR plus a fixed margin as of December 31, 2015 and 2014 .
Self Insurance Reserves	Self-Insurance Reserves The Company is self-insured, through deductibles and retentions, up to certain levels for losses under its insurance programs. With the Company’s growth, the Company has elected to retain more risk by increasing its self-insurance levels. The Company accrues for these liabilities based on estimates of the ultimate cost of claims incurred as of the balance sheet date. The Company regularly reviews the estimates of reported and unreported claims and provides for losses through reserves. The Company obtains actuarial reviews to evaluate the reasonableness of internal estimates for losses related to workers’ compensation, auto liability and group medical on an annual basis.
Subsequent Events	Subsequent Events In accordance with authoritative guidance, the Company has evaluated and disclosed all material subsequent events that occurred after the balance sheet date, but before financial statements were issued
Recently Issued Accounting Pronouncements	Recently Adopted Accounting Guidance In November 2015, the Financial Accounting Standards Board (FASB) issued ASU No. 2015-17, Balance Sheet Classification of Deferred Taxes , which amends existing guidance on income taxes to require the classification of all deferred tax assets and liabilities as non-current on the balance sheet. The new standard is effective for the Company on January 1, 2017, with early adoption permitted, and the guidance may be applied either prospectively or retrospectively. The Company adopted this standard as of December 31, 2015 and applied the change retrospectively to prior periods, resulting in a $32.1 million reduction in total current assets and corresponding decrease in non-current deferred income tax liabilities. In April 2015, the FASB issued ASU No. 2015-03, Interest – Imputation of Interest: Simplifying the Presentation of Debt Issuance Costs , which changes the presentation of debt issuance costs. This guidance requires that debt on the balance sheet be presented net of unamortized debt issuance costs. Amortization of such costs is reported as interest expense, which is consistent with the Company’s current policy. This change conforms the presentation of debt issuance costs with that of debt discounts. The ASU is effective for annual reporting periods (including interim reporting periods within those periods) beginning after December 15, 2015; early adoption is permitted. The guidance is required to be applied retrospectively to all prior periods. The Company adopted this standard as of December 31, 2015. The effect of the adoption of ASU 2015-03 on the Company’s consolidated balance sheet is a reduction of total assets and long-term debt of $27.5 million as of December 31, 2014. In April 2014, the FASB issued ASU No. 2014-08, Presentation of Financial Statements and Property, Plant and Equipment , which changes the definition of discontinued operations. The guidance permits only those disposed components (or components held-for-sale) representing a strategic shift that have (or will have) a major effect on operations and financial results to be reported in discontinued operations. The new standard is effective prospectively for disposals (or classifications as held-for-sale) occurring after December 31, 2014. The Company has adopted the accounting guidance as of January 1, 2015. Recently Issued Accounting Guidance In July 2015, the FASB issued ASU No. 2015-11, Inventory – Simplifying the Measurement of Inventory , which applies to inventory measured using first-in, first-out or average cost. The guidance in this update states that inventory within its scope shall be measured at the lower of cost or net realizable value, and when the net realizable value of inventory is lower than its cost, the difference shall be recognized as a loss in earnings. The new standard is effective for the Company beginning on January 1, 2017 and should be applied on a prospective basis. The Company is evaluating the effect that ASU 2015-11 will have on its consolidated financial statements and related disclosures. In May 2014, the FASB issued ASU No. 2014-09, Revenue from Contracts with Customers , which will replace most existing revenue recognition guidance in GAAP. The guidance in this update requires an entity to recognize the amount of revenue that it expects to be entitled for the transfer of promised goods or services to customers. The new standard is effective for the Company on January 1, 2018. Early application is not permitted. The standard permits the use of either the retrospective or cumulative effect transition method. The Company is evaluating the effect that ASU 2014-09 will have on its consolidated financial statements and related disclosures. The Company has not yet selected a transition method nor has it determined the effect of the accounting guidance on its ongoing financial reporting.

Summary Of Significant Accoun25

Summary Of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Summary Of Significant Accounting Policies [Abstract]
Schedule of Inventory, Current [Table Text Block]	December 31, 2015 2014 Finished goods $ 71,951 $ 72,788 Raw materials 23,418 29,718 Work-in-process 18,203 20,317 Supplies and consumables 35,189 42,739 Total $ 148,761 $ 165,562
Estimated Useful Lives Of The Related Assets	Buildings and improvements 5 to 40 years Marine vessels and equipment 5 to 25 years Machinery and equipment 2 to 25 years Automobiles, trucks, tractors and trailers 3 to 10 years Furniture and fixtures 2 to 10 years
Summary Of Activity Of Goodwill	Onshore Drilling Completion Products and Workover Production and Services Services Services Total Balance, December 31, 2013 $ 144,872 $ 1,419,550 $ 893,687 $ 2,458,109 Acquisition activities - - 13,909 13,909 Foreign currency translation adjustment (2,033) - (1,576) (3,609) Balance, December 31, 2014 142,839 1,419,550 906,020 2,468,409 Acquisition activities - - 1,170 1,170 Reduction in value of assets - (740,000) (586,701) (1,326,701) Foreign currency translation adjustment (1,557) - (1,220) (2,777) Other - 44,000 (44,000) - Balance, December 31, 2015 $ 141,282 $ 723,550 $ 275,269 $ 1,140,101
Composition Of Intangible And Other Long-term Assets	December 31, 2015 2014 Estimated Gross Accumulated Net Gross Accumulated Net Useful Lives Amount Amortization Balance Amount Amortization Balance Customer relationships 17 years $ 257,364 $ (65,209) $ 192,155 $ 339,695 $ (64,954) $ 274,741 Tradenames 10 years 36,119 (15,371) 20,748 41,265 (13,151) 28,114 Non-compete agreements 3 years 3,242 (2,940) 302 4,487 (3,281) 1,206 Total $ 296,725 $ (83,520) $ 213,205 $ 385,447 $ (81,386) $ 304,061
Summary Of The Activity For Company's Decommissioning Liabilities	December 31, 2015 2014 Decommissioning liabilities, December 31, 2014 and 2013, respectively $ 88,000 $ 83,519 Revisions in estimated timing and cash flows 24,660 (276) Accretion 5,016 4,470 Liability acquisitions and dispositions 266 866 Liabilities settled - (579) Total decommissioning liabilities, December 31, 2015 and 2014, respectively $ 117,942 $ 88,000

Supplemental Cash Flow Inform26

Supplemental Cash Flow Information (Tables)	12 Months Ended
	Dec. 31, 2015
Supplemental Cash Flow Information [Abstract]
Supplemental Cash Flow Information	Years Ended December 31, 2015 2014 2013 Cash paid for interest $ 93,946 $ 102,880 $ 97,129 Cash paid for income taxes, net of refunds $ 40,074 $ 127,132 $ 164,158 Details of business acquisitions: Fair value of assets $ - $ 29,468 $ 34,964 Fair value of liabilities - (5,125) (10,942) Common stock issued - - - Cash paid - 24,343 24,022 Less cash acquired - (16) (225) Net cash paid for acquisitions $ - $ 24,327 $ 23,797 Non-cash investing activity: Capital expenditures included in accounts payable, accrued expenses and other long term liabilities $ 28,704 $ 49,118 $ 70,463 Non-cash financing activity: Cash dividends declared $ - $ - $ 12,759

Reduction in Value of Assets (T

Reduction in Value of Assets (Tables)	12 Months Ended
	Dec. 31, 2015
Reduction In Value Of Assets [Abstract]
Reduction in Value of Assets [Table Text Block]	Years Ended December 31, 2015 2013 Reduction in value of goodwill $ 1,326,701 $ 91,016 Reduction in value of long-lived assets 330,194 180,320 Retirements of long-lived assets 42,545 14,418 Reduction in value of assets related to sale of a business 39,447 - Reduction in value of assets related to Venezuela exit activities - 14,324 Total reduction in value of assets $ 1,738,887 $ 300,078

Discontinued Operations (Tables

Discontinued Operations (Tables)	12 Months Ended
	Dec. 31, 2015
Discontinued Operations [Abstract]
Components Of Income (Loss) From Discontinued Operations	Years Ended December 31, 2015 2014 2013 Revenues $ 18,723 $ 145,463 $ 261,767 Loss from discontinued operations, net of tax benefit of $5,626, $19,330 and $15,439 for 2015, 2014 and 2013, respectively $ (46,955) $ (22,973) $ (156,903)
Assets And Liabilities Of Disposal Groups	December 31, 2015 2014 Accounts receivable, net $ 1,234 $ 16,701 Prepaid expenses 330 2,463 Inventory and other current assets 1,036 5,576 Current assets $ 2,600 $ 24,740 Property, plant and equipment, net 92,634 91,171 Intangible and other long-term assets, net - 769 Long-term assets $ 92,634 $ 91,940 Accounts payable 1,007 20,530 Accrued expenses 3,654 24,496 Current liabilities $ 4,661 $ 45,026 Other long-term liabilities $ - $ 16,814

Property, Plant And Equipment (

Property, Plant And Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
Property, Plant And Equipment [Abstract]
Summary Of Property, Plant And Equipment	December 31, 2015 2014 Buildings, improvements and leasehold improvements $ 318,906 $ 328,651 Marine vessels and equipment 87 55,494 Machinery and equipment 3,770,959 4,126,570 Automobiles, trucks, tractors and trailers 45,013 66,032 Furniture and fixtures 67,483 75,631 Construction-in-progress 74,683 102,895 Land 58,731 58,814 Oil and gas producing assets 66,285 189,294 Total 4,402,147 5,003,381 Accumulated depreciation and depletion (2,278,856) (2,269,542) Property, plant and equipment, net $ 2,123,291 $ 2,733,839

Debt (Tables)

Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt [Abstract]
Summary Of Long-Term Debt	December 31, 2015 2014 Long-term Current Long-term Current Term loan due February 2017 $ 305,000 $ 20,000 $ 325,000 $ 20,000 Senior Notes due May 2019 500,000 - 500,000 - Senior Notes due December 2021 800,000 - 800,000 - Other 3,089 9,957 2,842 941 Total debt, gross 1,608,089 29,957 1,627,842 20,941 Unamortized debt issuance costs (19,826) - (27,469) - Total debt $ 1,588,263 $ 29,957 $ 1,600,373 $ 20,941
Schedule Of Maturities Of Long-Term Debt	2016 $ 29,957 2017 306,705 2018 1,384 2019 500,000 2020 - Thereafter 800,000 Total $ 1,638,046

Stock-Based And Long-Term Compe

Stock-Based And Long-Term Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
Stock-Based And Long-Term Compensation [Abstract]
Schedule of Compensation Cost for Share-based Payment Arrangements, Allocation of Share-based Compensation Costs by Plan [Table Text Block]	Compensation Expense Years Ended December 31, 2015 2014 2013 Stock options $ 3,663 $ 3,900 $ 3,586 Restricted stock 9,219 15,800 21,460 Restricted stock units 19,699 11,282 - Performance share units 10,733 10,688 10,014 Strategic performance share units 2,258 2,404 - Total $ 45,572 $ 44,074 $ 35,060 Tax Benefit Years Ended December 31, 2015 2014 2013 Stock options $ 1,355 $ 1,443 $ 1,327 Restricted stock 3,411 5,846 7,940 Restricted stock units 7,289 4,174 - Total $ 12,055 $ 11,463 $ 9,267
Summary Of The Valuation Assumptions Used To Calculate The Fair Value Of Stock Option Grants	Years Ended December 31, 2015 2014 2013 Weighted average fair value of grants $ 6.25 $ 6.95 $ 8.98 Black-Scholes-Merton Assumptions: Risk free interest rate 1.33% 1.42% 0.63% Expected life (years) 5 4 4 Volatility 47.07% 34.50% 48.41% Dividend yield 1.30 1.23 -
Summary Of Stock Option Activity	Number of Options Weighted Average Option Price Weighted Average Remaining Contractual Term (in years) Aggregate Intrinsic Value (in thousands) Outstanding as of December 31, 2014 4,484,505 $ 23.76 5.1 $ 4,095 Granted 612,665 $ 17.27 Exercised (506,029) $ 17.43 Outstanding as of December 31, 2015 4,591,141 $ 23.60 5.3 $ 256 Exercisable as of December 31, 2015 3,488,262 $ 24.48 4.3 $ 256 Options expected to vest as of December 31, 2015 1,102,879 $ 20.81 8.5 $ -
Summary Of Non-Vested Stock Option Activity	Number of Options Weighted Average Grant Date Fair Value Non-vested as of December 31, 2014 824,488 $ 7.83 Granted 612,665 $ 17.27 Vested (334,274) $ 25.01 Non-vested as of December 31, 2015 1,102,879 $ 20.81
Summary Of The Status Of Restricted Stock	Number of Shares Weighted Average Grant Date Fair Value Non-vested as of December 31, 2014 1,022,280 $ 24.08 Vested (678,880) $ 17.88 Forfeited (50,463) $ 23.26 Non-vested as of December 31, 2015 292,937 $ 23.13
Summary Of Restricted Stock Unit Activity	Number of Restricted Stock Units Weighted Average Grant Date Fair Value Non-vested as of December 31, 2014 1,416,477 $ 26.40 Granted 2,162,146 $ 17.74 Vested (460,400) $ 18.51 Forfeited (330,334) $ 20.16 Non-vested as of December 31, 2015 2,787,889 $ 20.41
Summary Of Employee Stock Purchase Plan Activity Table Text Block	Years Ended December 31, 2015 2014 2013 2013 Plan 2013 Plan 2013 and 2007 Plans Cash received for shares issued $ 4,803 $ 4,870 $ 4,124 Compensation expense $ 835 $ 1,078 $ 947 Shares issued 332,467 246,480 185,407
Summary of Deferred Compensation Balances Table Text Block	December 31, Balance sheet location 2015 2014 Deferred compensation assets Intangible and other long-term assets, net $ 11,548 $ 12,982 Deferred compensation liabilities, short-term Accounts payable $ 721 $ 2,291 Deferred compensation liabilities, long-term Other long-term liabilities $ 17,367 $ 14,720

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Taxes [Abstract]
Schedule Of Components Of Income And Loss From Continuing Operations Before Income Taxes	Years Ended December 31, 2015 2014 2013 Domestic $ (2,069,019) $ 372,672 $ 165,463 Foreign 9,236 69,517 (64,706) $ (2,059,783) $ 442,189 $ 100,757
Schedule Of Components Of Income Tax Expense (Benefit)	Years Ended December 31, 2015 2014 2013 Current: Federal $ (952) $ 150,997 $ 19,897 State 2,818 11,339 10,816 Foreign 19,227 36,287 25,613 21,093 198,623 56,326 Deferred: Federal (249,193) (33,172) (6,341) State (10,034) 648 386 Foreign (13,886) (4,700) 4,901 (273,113) (37,224) (1,054) $ (252,020) $ 161,399 $ 55,272
Schedule Of Effective Income Tax Rate Reconciliation	Years Ended December 31, 2015 2014 2013 Computed expected tax expense $ (720,923) $ 154,766 $ 35,265 Increase (decrease) resulting from State and foreign income taxes (6,353) 8,467 (852) Reduction in value of assets 464,395 - 34,874 Other 10,861 (1,834) (14,015) Income tax $ (252,020) $ 161,399 $ 55,272
Schedule Of Deferred Tax Assets and Liabilities	December 31, 2015 2014 Deferred tax assets: Allowance for doubtful accounts $ 8,275 $ 3,942 Operating loss and tax credit carryforwards 92,798 21,928 Compensation and employee benefits 59,310 57,045 Decommissioning liabilities 30,400 21,029 Other 57,768 50,641 248,551 154,585 Valuation allowance (5,395) - Net deferred tax assets 243,156 154,585 Deferred tax liabilities: Property, plant and equipment 469,728 648,054 Notes receivable 14,796 5,718 Goodwill and other intangible assets 119,661 138,017 Other 22,040 33,654 Deferred tax liabilities 626,225 825,443 Net deferred tax liability $ 383,069 $ 670,858
Summary Of Activity In Unrecognized Tax Benefits	Years Ended December 31, 2015 2014 2013 Unrecognized tax benefits, December 31, 2014, 2013 and 2012, respectively $ 30,344 $ 29,899 $ 26,399 Additions based on tax positions related to current year - - - Additions based on tax positions related to prior years 6,752 7,860 5,065 Reductions based on tax positions related to prior years (7,381) (7,415) (1,565) Unrecognized tax benefits, December 31, 2015, 2014 and 2013, respectively $ 29,715 $ 30,344 $ 29,899

Segment Information (Tables)

Segment Information (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Information [Abstract]
Schedule Of Segment Reporting Information	2015 Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Unallocated Total Revenues $ 583,139 $ 934,274 $ 759,606 $ 497,546 $ - $ 2,774,565 Cost of services and rentals (exclusive of items shown separately below) 196,921 773,119 594,286 301,486 - 1,865,812 Depreciation, depletion, amortization and accretion 194,061 225,667 130,267 62,152 - 612,147 General and administrative expenses 127,525 121,289 139,304 122,590 - 510,708 Reduction in value of assets 40,237 783,229 790,517 124,904 - 1,738,887 Income (loss) from operations 24,395 (969,030) (894,768) (113,586) - (1,952,989) Interest expense, net - - (2,013) 1,707 (97,012) (97,318) Other expense - - - - (9,476) (9,476) Income (loss) from continuing operations before income taxes $ 24,395 $ (969,030) $ (896,781) $ (111,879) $ (106,488) $ (2,059,783) 2014 Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Unallocated Total Revenues $ 904,358 $ 1,732,833 $ 1,350,956 $ 568,475 $ - $ 4,556,622 Cost of services and rentals (exclusive of items shown separately below) 282,023 1,205,443 941,030 306,337 - 2,734,833 Depreciation, depletion, amortization and accretion 186,642 233,430 164,672 66,070 - 650,814 General and administrative expenses 149,967 159,687 187,526 127,191 - 624,371 Income from operations 285,726 134,273 57,728 68,877 - 546,604 Interest expense, net - - - 1,577 (98,311) (96,734) Other expense - - - - (7,681) (7,681) Income (loss) from continuing operations before income taxes $ 285,726 $ 134,273 $ 57,728 $ 70,454 $ (105,992) $ 442,189 2013 Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Unallocated Total Revenues $ 820,538 $ 1,607,268 $ 1,434,990 $ 487,261 $ - $ 4,350,057 Cost of services and rentals (exclusive of items shown separately below) 268,127 1,091,956 1,002,628 270,879 - 2,633,590 Depreciation, depletion, amortization and accretion 168,391 216,152 177,532 42,366 - 604,441 General and administrative expenses 136,244 158,448 190,647 112,439 - 597,778 Reduction in value of assets 2,292 16,975 28,568 252,243 - 300,078 Income (loss) from operations 245,484 123,737 35,615 (190,666) - 214,170 Interest expense, net - - - 1,323 (109,225) (107,902) Other income (expense) - - - 836 (6,347) (5,511) Income (loss) from continuing operations before income taxes $ 245,484 $ 123,737 $ 35,615 $ (188,507) $ (115,572) $ 100,757
Schedule Of Identifiable Assets	Identifiable Assets Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Unallocated Total December 31, 2015 $ 1,223,191 $ 1,929,185 $ 967,719 $ 794,149 $ - $ 4,914,244 December 31, 2014 $ 1,284,842 $ 2,993,824 $ 2,098,592 $ 940,524 $ - $ 7,317,782 December 31, 2013 $ 1,237,842 $ 2,961,390 $ 2,158,653 $ 1,009,058 $ - $ 7,366,943
Schedule of Capital Expenditures Table Text Block	Capital Expenditures Onshore Drilling Completion Products and and Workover Production Technical Consolidated Services Services Services Solutions Total December 31, 2015 $ 129,504 $ 103,001 $ 72,048 $ 53,673 $ 358,226 December 31, 2014 $ 274,752 $ 152,742 $ 88,870 $ 99,738 $ 616,102 December 31, 2013 $ 246,479 $ 101,854 $ 122,946 $ 137,681 $ 608,960
Schedule Of Revenues By Geographic Segment	Revenues Years Ended December 31, 2015 2014 2013 United States $ 2,185,071 $ 3,848,929 $ 3,674,825 Other Countries 589,494 707,693 675,232 Total $ 2,774,565 $ 4,556,622 $ 4,350,057 Long-Lived Assets December 31, 2015 2014 United States $ 1,799,418 $ 2,416,306 Other Countries 323,873 317,533 Total, net $ 2,123,291 $ 2,733,839

Fair Value Measurements (Tables

Fair Value Measurements (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value Measurements [Abstract]
Summary Of Financial Assets And Liabilities Measured At Fair Value On Recurring Basis	Fair Value Measurements at Reporting Date Using December 31, 2015 Level 1 Level 2 Level 3 Intangible and other long-term assets, net Non-qualified deferred compensation assets $ 11,548 $ 368 $ 11,180 - Interest rate swaps $ 6,905 - $ 6,905 - Accounts payable Non-qualified deferred compensation liabilities $ 721 - $ 721 - Other long-term liabilities Non-qualified deferred compensation liabilities $ 17,367 - $ 17,367 - December 31, 2014 Level 1 Level 2 Level 3 Intangible and other long-term assets, net Non-qualified deferred compensation assets $ 12,982 $ 1,481 $ 11,501 - Interest rate swaps $ 4,183 - $ 4,183 - Accounts payable Non-qualified deferred compensation liabilities $ 2,291 - $ 2,291 - Other long-term liabilities Non-qualified deferred compensation liabilities $ 14,720 - $ 14,720 -
Fair Value, Assets and Liabilities Measured on Nonrecurring Basis, Valuation Techniques [Table Text Block]	Years Ended December 31, 2015 2013 Impairment Fair Value Impairment Fair Value Property, plant and equipment, net $ 177,442 $ 179,612 $ 243,781 $ 328,876 Goodwill $ 1,326,701 $ 998,288 $ 91,016 $ - Intangible assets $ 68,890 $ 6,345 $ 18,296 $ 4,355

Derivative Financial Instrume35

Derivative Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
Derivative Financial Instruments [Abstract]
Location And Effect Of The Derivative Instrument On The Statements Of Operations	Years Ended December 31, Effect of derivative instrument Location of (gain) loss recognized 2015 2014 2013 Interest rate swap Interest expense, net $ (1,932) $ (11,054) $ 13,079 Hedged item - debt Interest expense, net (790) 7,208 (12,303) $ (2,722) $ (3,846) $ 776

Interim Financial Information36

Interim Financial Information (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Interim Financial Information (Unaudited) [Abstract]
Schedule Of Interim Financial Information	2015 First Quarter Second Quarter Third Quarter Fourth Quarter Revenues $ 917,235 $ 710,784 $ 601,396 $ 545,150 Less: Cost of services and rentals 582,246 465,533 420,485 397,548 Depreciation, depletion, amortization and accretion 162,220 158,352 146,757 144,818 Gross profit 172,769 86,899 34,154 2,784 Reduction in value of assets - 807,637 755,632 175,618 Net loss from continuing operations (1,497) (775,132) (816,587) (214,547) Loss from discontinued operations, net of tax (9,640) (9,857) (4,610) (22,848) Net loss (11,137) (784,989) (821,197) (237,395) Loss per share from continuing operations: Basic and diluted $ (0.02) $ (5.15) $ (5.42) $ (1.43) Loss per share from discontinued operations: Basic and diluted $ (0.06) $ (0.07) $ (0.03) $ (0.15) 2014 First Quarter Second Quarter Third Quarter Fourth Quarter Revenues $ 1,061,418 $ 1,107,552 $ 1,209,026 $ 1,178,626 Less: Cost of services and rentals 651,605 650,293 721,692 711,243 Depreciation, depletion, amortization and accretion 162,318 160,965 170,154 157,377 Gross profit 247,495 296,294 317,180 310,006 Net income from continuing operations 42,626 79,057 85,743 73,364 Loss from discontinued operations, net of tax (5,954) (3,895) (5,886) (7,238) Net income 36,672 75,162 79,857 66,126 Earnings per share from continuing operations: Basic $ 0.27 $ 0.51 $ 0.55 $ 0.49 Diluted 0.27 0.50 0.55 0.48 Loss per share from discontinued operations: Basic and diluted $ (0.04) $ (0.03) $ (0.03) $ (0.05)

Supplementary Oil And Natural37

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Tables)	12 Months Ended
	Dec. 31, 2015
Supplementary Oil And Natural Gas Disclosures [Abstract]
Schedule Of Proved Developed And Undeveloped Oil And Gas Reserves	Crude Oil Natural Gas (Mbbls) (Mmcf) Proved-developed and undeveloped reserves: December 31, 2012 8,207 11,284 Revisions (3,203) (4,036) Production (411) (296) December 31, 2013 4,593 6,952 Revisions (438) 1,431 Production (738) (1,247) December 31, 2014 3,417 7,136 Revisions (381) (245) Production (633) (1,517) December 31, 2015 2,403 5,374 Proved-developed reserves: December 31, 2013 2,397 2,100 December 31, 2014 3,184 6,945 December 31, 2015 2,202 5,216 Proved-undeveloped reserves: December 31, 2013 2,196 4,852 December 31, 2014 233 191 December 31, 2015 201 158
Cost Incurred In Oil And Gas Property Acquisition, Exploration, And Development Activities	Years Ended December 31, 2015 2014 2013 Acquisition of properties - proved $ - $ - $ - Acquisition of properties - unproved - - - Exploratory costs - - - Development costs 20,636 52,719 51,527 Total costs incurred $ 20,636 $ 52,719 $ 51,527
Capitalized Costs Relating To Oil And Gas Producing Activities	December 31, 2015 2014 Proved oil and gas properties $ 66,285 $ 189,294 Accumulated depreciation, depletion and amortization - (55,864) Capitalized costs, net $ 66,285 $ 133,430
Schedule Of Ownership In Productive Oil And Natural Gas Wells	Productive Wells Gross Net Oil 11.00 5.61
Schedule Of Gas And Oil Acreage	Gross Net Acreage Acreage Developed 23,040 11,750 Undeveloped - - Total 23,040 11,750
Schedule Of Drilling Activity	Years Ended December 31, 2015 2014 Gross Net Gross Net Exploratory Wells Productive - - - - Non-productive - - - - Total - - - - Development Wells Productive 1.00 0.51 2.00 1.02 Non-productive 1.00 0.51 1.00 0.51 Total 2.00 1.02 3.00 1.53
Results Of Operations For Oil And Gas Producing Activities	Years Ended December 31, 2015 2014 2013 Revenues Sales $ 30,245 $ 77,845 $ 47,050 Production costs 15,466 13,529 9,876 Exploration expenses - - - Depreciation, depletion and amortization 37,623 38,768 12,032 Reduction in value of assets 56,000 - - (78,844) 25,548 25,142 Income tax expenses (28,778) 9,325 8,800 Results of operations from producing activities (excluding corporate overhead) $ (50,066) $ 16,223 $ 16,342
Standardized Measure Of Discounted Future Cash Flows Relating To Proved Reserves	Years Ended December 31, 2015 2014 2013 Future cash inflows $ 127,048 $ 336,944 $ 496,704 Future production costs (43,010) (71,209) (82,487) Future development and abandonment costs (84,090) (111,374) (156,340) Future income tax expenses 1,353 (60,345) (89,507) Future net cash flows 1,301 94,016 168,370 10% annual discount for estimated timing of cash flows (19,762) (17,034) 10,641 Standardized measure of discounted future net cash flows $ 21,063 $ 111,050 $ 157,729
Summary Of Changes In Standardized Measure Of Discounted Future Net Cash Flows Applicable To Proved Oil And Natural Gas Reserves	Years Ended December 31, 2015 2014 2013 Beginning of the period $ 111,050 $ 157,729 $ 303,430 Net change in sales and transfer prices and in production (lifting) costs related to future production (143,808) (57,568) (13,278) Changes in estimated future development costs 3,787 (5,512) (48,594) Sales and transfers of oil and gas produced during the period (14,779) (64,316) (45,866) Net change due to extensions, discoveries, and improved recovery 6,737 - 75,304 Net changes due to revisions in quantity estimates (36,397) (8,396) (228,620) Previously estimated development costs incurred during the period 20,636 40,962 10,136 Accretion of discount 17,606 24,251 46,711 Other-unspecified 1,895 4,125 (24,169) Net change in income taxes 54,336 19,775 82,675 Aggregate change in the standardized measure of discounted future net cash flows for the year (89,987) (46,679) (145,701) End of the period $ 21,063 $ 111,050 $ 157,729

Summary Of Significant Accoun38

Summary Of Significant Accounting Policies (Major Customers And Concentration Of Credit Risk) (Narrative) (Details)	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Summary Of Significant Accounting Policies [Abstract]
Maximum percentage of revenue for a single major customer	10.00%	10.00%

Summary Of Significant Accoun39

Summary Of Significant Accounting Policies (Cash Equivalents) (Narrative) (Details)	12 Months Ended
	Dec. 31, 2015
Summary Of Significant Accounting Policies [Abstract]
Maximum maturity of short-term investments purchased to be cash equivalents	90 days

Summary Of Significant Accoun40

Summary Of Significant Accounting Policies (Inventory) (Narrative) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Inventory	$ 148,761	$ 165,562
Finished goods	71,951	72,788
Raw materials	23,418	29,718
Work-in-progress	18,203	20,317
Supplies and consumables	$ 35,189	$ 42,739

Summary Of Significant Accoun41

Summary Of Significant Accounting Policies (Estimated Useful Lives Of The Related Assets) (Details)	12 Months Ended
	Dec. 31, 2015
Building and Building Improvements [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	5 years
Building and Building Improvements [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	40 years
Marine Vessels And Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	5 years
Marine Vessels And Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	25 years
Machinery And Equipment [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	2 years
Machinery And Equipment [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	25 years
Automobiles, Trucks, Tractors And Trailers [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	3 years
Automobiles, Trucks, Tractors And Trailers [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	10 years
Furniture And Fixtures [Member] | Minimum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	2 years
Furniture And Fixtures [Member] | Maximum [Member]
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, useful life	10 years

Summary Of Significant Accoun42

Summary Of Significant Accounting Policies (Goodwill) (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2013	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Percentage of the discounted cash flow method for estimation of fair value of reporting units	80.00%
Percentage of the public company guideline method for estimation of fair value of reporting units	20.00%
Goodwill, Impaired, Accumulated Impairment Loss	$ 1,417,700		$ 91,000
Reduction in value of goodwill	$ 1,326,701	$ 91,016

Summary Of Significant Accoun43

Summary Of Significant Accounting Policies (Summary Of Activity Of Goodwill) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Goodwill [Roll Forward]
Beginning Balance	$ 2,468,409	$ 2,458,109
Acquisition activities	1,170	13,909
Reduction in value of assets	(1,326,701)		$ (91,016)
Foreign currency translation adjustments	(2,777)	(3,609)
Ending Balance	1,140,101	2,468,409	2,458,109
Drilling Products And Services [Member]
Goodwill [Roll Forward]
Beginning Balance	142,839	144,872
Foreign currency translation adjustments	(1,557)	(2,033)
Ending Balance	141,282	142,839	144,872
Onshore Completion Services [Member]
Goodwill [Roll Forward]
Beginning Balance	1,419,550	1,419,550
Reduction in value of assets	(740,000)
Additional consideration paid for prior acquisitions	44,000
Ending Balance	723,550	1,419,550	1,419,550
Goodwill, Other Changes	44,000
Production Services [Member]
Goodwill [Roll Forward]
Beginning Balance	906,020	893,687
Acquisition activities	1,170	13,909
Reduction in value of assets	(586,701)
Additional consideration paid for prior acquisitions	(44,000)
Foreign currency translation adjustments	(1,220)	(1,576)
Ending Balance	275,269	$ 906,020	$ 893,687
Goodwill, Other Changes	$ (44,000)

Summary Of Significant Accoun44

Summary Of Significant Accounting Policies (Notes Receivable) (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Notes Receivable [Abstract]
Amount of notes receivable net	$ 115
Interest rate percentage to record present value of notes receivable	6.58%
AccelerationOfPlatformDecommissioningDate	10 years
Company recorded interest income	$ 1.7	$ 1.6	$ 2.6

Summary Of Significant Accoun45

Summary Of Significant Accounting Policies (Intangible And Other Long-Term Assets) (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended			12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Finite-Lived Intangible Assets [Line Items]
Escrow Deposit Required by Seller of Oil and Gas Properties	$ 58,400			$ 58,400
Reduction in value of assets	175,618	$ 755,632	$ 807,637	1,738,887		$ 300,078
Amortization expense exclusive of debt acquisition costs				23,000	$ 25,900	$ 26,200
Amortization of intangible assets exclusive of debt acquisitions costs for 2015	19,200			19,200
Amortization of intangible assets exclusive of debt acquisitions costs for 2016	18,600			18,600
Amortization of intangible assets exclusive of debt acquisitions costs for 2017	18,500			18,500
Amortization of intangible assets exclusive of debt acquisitions costs for 2018	18,300			18,300
Amortization of intangible assets exclusive of debt acquisitions costs for 2019	$ 18,000			$ 18,000
Customer Relationships [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life				17 years
Trade Names [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life				10 years
Noncompete Agreements [Member]
Finite-Lived Intangible Assets [Line Items]
Finite-Lived Intangible Asset, Useful Life				3 years
Unsecured Senior Notes Due 2021 [Member]
Finite-Lived Intangible Assets [Line Items]
Stated interest rate on unsecured senior notes	7.125%			7.125%

Summary Of Significant Accoun46

Summary Of Significant Accounting Policies (Composition Of Intangible And Other Long-term Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Schedule of Intangible Assets by Major Class [Line Items]
Finite-Lived Intangible Assets, Net, Total	$ 213,205	$ 304,061
Acquired Finite-lived Intangible Asset, Amount	296,725	385,447
Finite-Lived Intangible Assets, Accumulated Amortization	(83,520)	(81,386)
Customer Relationships [Member]
Schedule of Intangible Assets by Major Class [Line Items]
Finite-Lived Intangible Assets, Net, Total	192,155	274,741
Acquired Finite-lived Intangible Asset, Amount	257,364	339,695
Finite-Lived Intangible Assets, Accumulated Amortization	(65,209)	(64,954)
Trade Names [Member]
Schedule of Intangible Assets by Major Class [Line Items]
Finite-Lived Intangible Assets, Net, Total	20,748	28,114
Acquired Finite-lived Intangible Asset, Amount	36,119	41,265
Finite-Lived Intangible Assets, Accumulated Amortization	(15,371)	(13,151)
Noncompete Agreements [Member]
Schedule of Intangible Assets by Major Class [Line Items]
Finite-Lived Intangible Assets, Net, Total	302	1,206
Acquired Finite-lived Intangible Asset, Amount	3,242	4,487
Finite-Lived Intangible Assets, Accumulated Amortization	$ (2,940)	$ (3,281)

Summary Of Significant Accoun47

Summary Of Significant Accounting Policies (Decommissioning Liabilities) (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Asset Retirement Obligation, Liabilities Incurred	$ 266	$ 866

Summary Of Significant Accoun48

Summary Of Significant Accounting Policies (Summary Of The Activity For Company's Decommissioning Liabilities) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2015	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Decommissioning liabilities, December 31, 2014 and 2013, respectively	$ 88,000	$ 83,519
Liabilities acquired and incurred	266	866
Liabilities settled		(579)
Accretion	5,016	4,470
Revision in estimated liabilities	24,660	(276)
Total decommissioning liabilities, December 31, 2015 and 2014, respectively	$ 88,000	$ 83,519	$ 117,942	$ 88,000
Less: current portion of decommissioning liabilities as of December 31, 2015 and 2014, respectively			19,052
Long-term decommissioning liabilities, December 31, 2015 and 2014, respectively			$ 98,890	$ 88,000

Summary Of Significant Accoun49

Summary Of Significant Accounting Policies (Earnings (Loss) Per Share) (Narrative) (Details)	24 Months Ended
	Dec. 31, 2014shares
Summary Of Significant Accounting Policies [Abstract]
Antidilutive securities excluded from computation of earnings per share, share	1,100,000

Summary Of Significant Accoun50

Summary Of Significant Accounting Policies (Financial Instruments) (Narrative) (Details) - USD ($) $ in Millions	Dec. 31, 2015	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Fair value of debt	$ 1,508	$ 1,624.3

Summary Of Significant Accoun51

Summary Of Significant Accounting Policies (Foreign Currency) (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Summary Of Significant Accounting Policies [Abstract]
Foreign currency gains	$ (9.6)	$ 7.3	$ 7.1

Summary Of Significant Accoun52

Summary Of Significant Accounting Policies (Derivative Instruments And Hedging Activities) (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Percentage of fixed rate debt	62.00%	61.00%
Notional amount of interest rate swap	$ 300,000,000
Variable interest rate, Adjustment	90 days

Summary of Significant Accoun53

Summary of Significant Accounting Policies (Accumulated Other Comprehensive Loss) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Summary Of Significant Accounting Policies [Abstract]
Accumulated other comprehensive loss, net	$ (45,694)	$ (36,280)

Summary of Significant Accoun54

Summary of Significant Accounting Policies (Cash Dividends) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Summary Of Significant Accounting Policies [Abstract]
Cash dividends declared per share	$ 0.32	$ 0.24	$ 0.08

Summary of Significant Accoun55

Summary of Significant Accounting Policies (Recently Adopted Accounting Guidance) (Details) $ in Millions	Dec. 31, 2015USD ($)
Summary Of Significant Accounting Policies [Abstract]
Change in deferred tax balance due to reclassification	$ 32.1

Supplemental Cash Flow Inform56

Supplemental Cash Flow Information (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Supplemental Cash Flow Information [Abstract]
Cash paid for interest	$ 93,946	$ 102,880	$ 97,129
Cash paid for income taxes	40,074	127,132	164,158
Details of business acquisitions:
Fair Value of Assets Acquired		29,468	34,964
Fair value of liabilities		(5,125)	(10,942)
Cash paid		24,343	24,022
Less cash acquired		(16)	(225)
Net cash paid for acquisitions		24,327	23,797
Non-cash investing activity:
Capital Expenditures Incurred but Not yet Paid	$ 28,704	$ 49,118	70,463
Non-cash financing activity:
Dividends, Share-based Compensation, Cash			$ 12,759

Reduction in Value of Assets (N

Reduction in Value of Assets (Narrative) (Details) - USD ($) $ in Thousands	3 Months Ended			12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Asset Impairment Charges [Line Items]
Revenue Derived from Venezuela					$ 9,500
Reduction in Value of Assets Related to Exit of Venezuela Activities						$ 14,324
Retirments of Long-Lived Assets				$ 42,545		14,418
Reduction in Value of Long-Lived Assets				330,194		180,320
Reduction in value of goodwill				1,326,701		91,016
Reduction in value of assets	$ 175,618	$ 755,632	$ 807,637	1,738,887		300,078
Impairment of Intangible Assets, Finite-lived				68,900
Impairment of Long-Lived Assets Held-for-use				343,300
Allowance for Notes Receivables	16,800			16,800
Restructuring Charges				46,800
Impairment of operating leases				20,200
Restructuring Reserve, Current	7,200			7,200
Restructuring Reserve, Noncurrent	$ 11,100			11,100
Drilling Products And Services [Member]
Asset Impairment Charges [Line Items]
Reduction in value of assets				40,237		2,292
Impairment of Long-Lived Assets Held-for-use				40,200
Technical Solutions [Member]
Asset Impairment Charges [Line Items]
Reduction in value of other assets					31,900
Retirments of Long-Lived Assets					6,400
Reduction in value of assets				124,904		252,243
Impairment of Intangible Assets, Finite-lived					3,000
Impairment of Long-Lived Assets Held-for-use				68,900	122,800
Production Services [Member]
Asset Impairment Charges [Line Items]
Retirments of Long-Lived Assets				15,200	2,200
Reduction in value of goodwill				586,701
Reduction in value of assets				790,517		28,568
Impairment of Intangible Assets, Finite-lived				59,500
Impairment of Long-Lived Assets Held-for-use				89,700	11,400
Onshore Completion Services [Member]
Asset Impairment Charges [Line Items]
Retirments of Long-Lived Assets				27,300	5,800
Reduction in value of goodwill				740,000
Reduction in value of assets				783,229		$ 16,975
Impairment of Long-Lived Assets Held-for-use				$ 15,900	$ 11,200

Reduction in Value of Assets (C

Reduction in Value of Assets (Components of the Expense) (Details) - USD ($) $ in Thousands	3 Months Ended			12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Dec. 31, 2015	Dec. 31, 2013
Reduction In Value Of Assets [Abstract]
Reduction in value of assets	$ 175,618	$ 755,632	$ 807,637	$ 1,738,887	$ 300,078
Reduction in Value of Assets Related to Exit of Venezuela Activities					14,324
Reduction in Value of Long-Lived Assets				330,194	180,320
Reduction in value of goodwill				1,326,701	91,016
Retirments of Long-Lived Assets				42,545	$ 14,418
Reduction in value of assets related to sale of a business				$ 39,447

Discontinued Operations (Narrat

Discontinued Operations (Narrative) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment Included in Discontinued Operations			$ 119,300
Long-term assets	$ 92,634	$ 91,940
Subsea Construction Marine Vessels Member
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment Included in Discontinued Operations	25,800		98,300
Gain on sale of assets, disposal group accounted for as discontinued operations		$ 18,800
Subsea Construction Intangible Assets Member
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment Included in Discontinued Operations			15,400
Conventional Decommissioning Long-lived Assets Member
Income Statement, Balance Sheet and Additional Disclosures by Disposal Groups, Including Discontinued Operations [Line Items]
Impairment Included in Discontinued Operations	$ 8,800		$ 5,600

Discontinued Operations (Compon

Discontinued Operations (Components Of Income (Loss) From Discontinued Operations) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Discontinued Operations [Abstract]
Revenues									$ 18,723	$ 145,463	$ 261,767
Income tax expense (benefit)									(5,626)	(19,330)	(15,439)
Income (Loss) from Discontinued Operations, Net of Tax (benefit) expense	$ (22,848)	$ (4,610)	$ (9,857)	$ (9,640)	$ (7,238)	$ (5,886)	$ (3,895)	$ (5,954)	$ (46,955)	$ (22,973)	$ (156,903)

Discontinued Operations (Assets

Discontinued Operations (Assets And Liabilities of Disposal Groups) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Disposal Group, Including Discontinued Operation, Classified Balance Sheet Disclosures [Abstract]
Accounts receivable, net	$ 1,234	$ 16,701
Prepaid expenses	330	2,463
Disposal group inventory and other current assets	1,036	5,576
Assets of Disposal Group, Including Discontinued Operation, Current	2,600	24,740
Disposal group property, plant and equipment, net	92,634	91,171
Intangible and other long-term assets, net		769
Long-term assets	92,634	91,940
Accounts payable	1,007	20,530
Accrued expenses	3,654	24,496
Current liabilities	$ 4,661	45,026
Other long-term liabilities		$ 16,814

Property, Plant and Equipment a

Property, Plant and Equipment alt (Narrative) (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property, Plant And Equipment [Abstract]
Impairment of long lived assets	$ 343.3
Leasehold Improvements, Gross	84.9	$ 93.3
Depreciation	$ 584.1	$ 620.6	$ 572.9

Property, Plant and Equipment63

Property, Plant and Equipment (Summary Of Property, Plant And Equipment) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	$ 4,402,147	$ 5,003,381
Accumulated depreciation and depletion	(2,278,856)	(2,269,542)
Property, plant and equipment, net	2,123,291	2,733,839
Buildings, Improvements And Leasehold Improvements [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	318,906	328,651
Marine Vessels And Equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	87	55,494
Machinery And Equipment [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	3,770,959	4,126,570
Automobiles, trucks, tractors and trailers [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	45,013	66,032
Furniture And Fixtures [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	67,483	75,631
Construction in Progress [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	74,683	102,895
Land [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	58,731	58,814
Oil and Gas Properties [Member]
Property, Plant and Equipment, Net [Abstract]
Property, plant and equipment, gross	$ 66,285	$ 189,294

Debt (Narrative) (Details)

Debt (Narrative) (Details) $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Term Loan A, Amount Outstanding	$ 325
Revolving portion of credit facility, borrowing capacity	600
Revolving portion of credit facility, amount outstanding	325
Line of Credit Facility, Current Borrowing Capacity	470.3
Letters of Credit Outstanding, Amount	42.2
Unsecured Senior Notes Due 2019 [Member]
Debt Instrument [Line Items]
Senior Notes	$ 500
Stated interest rate on unsecured senior notes	6.375%
Unsecured Senior Notes Due 2021 [Member]
Debt Instrument [Line Items]
Senior Notes	$ 800
Stated interest rate on unsecured senior notes	7.125%

Debt (Summary Of Long-Term Debt

Debt (Summary Of Long-Term Debt) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Debt Instrument [Line Items]
Current	$ 29,957	$ 20,941
Long-term debt, gross	1,608,089	1,627,842
Long-term Debt, Excluding Current Maturities, Total	1,588,263	1,600,373
Accumulated Amortization, Deferred Finance Costs	(19,826)	(27,469)
Other long term debt instrument [member]
Debt Instrument [Line Items]
Current	9,957	941
Long-term debt, gross	3,089	2,842
Term Loan, Interest Payable Monthly At Floating Rate And Principal Payable Quarterly, Due December 2017 [Member]
Debt Instrument [Line Items]
Current	20,000	20,000
Long-term debt, gross	305,000	325,000
Senior Notes, Interest Payable Semiannually At 6 3/8%, Due May 2019 [Member]
Debt Instrument [Line Items]
Long-term debt, gross	500,000	500,000
Senior Notes, Interest Payable Semiannually At 7 1/8%, Due December 2021 [Member]
Debt Instrument [Line Items]
Long-term debt, gross	$ 800,000	$ 800,000

Debt (Schedule Of Maturities Of

Debt (Schedule Of Maturities Of Long-Term Debt) (Details) $ in Thousands	Dec. 31, 2015USD ($)
Debt [Abstract]
2,016	$ 29,957
2,017	306,705
2,018	1,384
2,019	500,000
Thereafter	800,000
Total	$ 1,638,046

Stock-Based And Long-Term Com67

Stock-Based And Long-Term Compensation (Narrative) (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Jul. 01, 2013
Stock Based and Long-Term Compensation (Textual) [Abstract]
Common Stock Reserved for Issuance, Shares Remaining	8,700,000
Compensation expense	$ 45,572	$ 44,074	$ 35,060
Tax benefit from exercising stock options	900	$ 5,600	$ 700
Compensation expense expected to recognize in 2015	19,300
Compensation expense expected to recognize in 2016	10,300
Compensation expense expected to recognize in 2017	$ 400
Shares issued under Employee Stock Purchase Plan, shares	332,467	246,480	185,407
Proceed from issue of shares under employee stock purchase plans	$ 4,803	$ 4,870	$ 4,124
Common stock reserved for issuance	14,850,000	8,000,000
Long-term liability	$ 17,367	$ 14,720
Current liability	721	2,291
Deferred compensation, compensation expense	2,100	1,600	1,200
Deferred compensation plan assets	11,548	12,982
Other income (expense)	$ (9,476)	(7,681)	(5,511)
Employee Stock Option [Member]
Stock Based and Long-Term Compensation (Textual) [Abstract]
Share-based payment vesting period, years	3 years
Share-based payment expiration period, years	10 years
Compensation expense	$ 3,663	3,900	3,586
Intrinsic value of options exercised	2,300	17,100	5,100
Cash received from exercising options	8,800	10,600	6,300
Unrecognized compensation expense related to non-vested options oustanding	3,900
Compensation expense expected to recognize in 2015	2,600
Compensation expense expected to recognize in 2016	$ 1,300
Restricted Stock [Member]
Stock Based and Long-Term Compensation (Textual) [Abstract]
Share-based payment vesting period, years	3 years
Compensation expense	$ 9,219	$ 15,800	21,460
Unrecognized compensation expense related to non-vested options oustanding	$ 400
Shares outstanding	292,937	1,022,280
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 17.88
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 23.13	$ 24.08
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Fair Value	$ 12,100	$ 23,000	9,600
Restricted Stock Units (RSUs) [Member]
Stock Based and Long-Term Compensation (Textual) [Abstract]
Compensation expense	19,699	$ 11,282
Unrecognized compensation expense related to non-vested options oustanding	$ 30,000
Resticted stock granted	2,162,146
Shares outstanding	2,787,889	1,416,477
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Vested in Period, Weighted Average Grant Date Fair Value	$ 18.51
Share-based Compensation Arrangement by Share-based Payment Award, Equity Instruments Other than Options, Nonvested, Weighted Average Grant Date Fair Value	$ 20.41	$ 26.40
Performance Shares [Member]
Stock Based and Long-Term Compensation (Textual) [Abstract]
Compensation expense	$ 10,733	$ 10,688	10,014
Shares outstanding	370,822
Performance period of PSU grant, years	3 years
Portion of equivalent value in common stock of company after meeting service requirements, at discretion of compensation committee	50.00%
Performance Share Units Outstanding, in 2014	112,922
Performance Share Units Outstanding, in 2015	123,079
Performance Share Units Outstanding, in 2016	134,821
Strategic Performance Shares [Member]
Stock Based and Long-Term Compensation (Textual) [Abstract]
Compensation expense	$ 2,258	2,404
2013 Employee Stock Purchase Plan Member
Stock Based and Long-Term Compensation (Textual) [Abstract]
Compensation expense	$ 835	1,078	947
Common stock reserved for issuance				3,000,000
Supplemental Executive Retirement Plan [Member]
Stock Based and Long-Term Compensation (Textual) [Abstract]
Employers Contribution to be received by plan participants, Minimum	5.00%
Employers Contribution to be received by plan participants, Maximum	35.00%
Employers contribution	$ 1,200
Distribution to select participants	$ 3,700	3,000	3,000
Other Pension Plan [Member]
Stock Based and Long-Term Compensation (Textual) [Abstract]
Maximum employee contribution to be matched by employer	4.00%
Maximum empoyee contribution	75.00%
Company contribution, percent	100.00%
Company discretionary contributions	$ 13,900	$ 16,700	$ 16,000
Non-Qualified Deferred Compensation Plans [Member]
Stock Based and Long-Term Compensation (Textual) [Abstract]
Maximum portion of base salary to defer under non-qualified deferred compensation plan	75.00%
Maximum portion of bonus to defer under non-qualified deferred compensation plan	100.00%
Non-employee cash deferred to non-qualified compensation plan	100.00%
Maximum of cash portion of PSU compensation to defer under non-qualified deferred compensation plan	100.00%
Non-employee RSU deferred to non-qualified compensation plan	100.00%

Stock-Based And Long-Term Com68

Stock-Based And Long-Term Compensation (Summary Of The Valuation Assumptions Used To Calculate The Fair Value Of Stock Option Grants) (Details) - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Weighted average fair value of grants	$ 6.25	$ 6.95	$ 8.98
Black-Scholes-Merton Assumptions:
Risk free interest rate	1.33%	1.42%	0.63%
Expected life (years)	5 years	4 years	4 years
Volatility	47.07%	34.50%	48.41%
Dividend yield	1.30%	1.23%

Stock-Based And Long-Term Com69

Stock-Based And Long-Term Compensation (Summary Of Stock Option Activity) (Details) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Summarization of stock option activity
Number of options outstanding, beginning	4,484,505
Number of options granted	612,665
Number of options exercised	(506,029)
Number of options outstanding, ending	4,591,141	4,484,505
Number of options exercisable	3,488,262
Number of options expected to vest	1,102,879
Weighted average option price outstanding, beginning	$ 23.76
Weighted average option price granted	17.27
Weighted average option price excercised	17.43
Weighted average option price outstanding, ending	23.60	$ 23.76
Weighted average option price exercisable		$ 24.48
Weighted average option price expected to vest	$ 20.81
Weighted average remaining contractual term, outstanding	5 years 3 months 18 days	5 years 1 month 6 days
Weighted average remaining contractual term, exercisable	4 years 3 months 18 days
Weighted average remaining contractual term, expected to vest	8 years 6 months
Aggregate intrinsic value, outstanding	$ 256	$ 4,095
Aggregate intrinsic value, exercisable	$ 256

Stock-Based And Long-Term Com70

Stock-Based And Long-Term Compensation (Summary Of Non-Vested Stock Option Activity) (Details)	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Summarizes Non-vested Stock Option [Abstract]
Number of Option, Beginning Balance | shares	824,488
Number of Option, Granted | shares	612,665
Number of Option, Vested | shares	(334,274)
Number of Option, Ending Balance | shares	1,102,879
Weighted Average Grant Date Fair Value, Beginning Balance | $ / shares	$ 7.83
Weighted Average Grant Date Fair Value, Granted | $ / shares	17.27
Weighted Average Grant Date Fair Value, Vested | $ / shares	25.01
Weighted Average Grant Date Fair Value, Ending Balance | $ / shares	$ 20.81

Stock-Based And Long-Term Com71

Stock-Based And Long-Term Compensation (Summary Of The Status Of Restricted Stock) (Details) - Restricted Stock [Member] - $ / shares	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Summary of restricted stock
Beginning balance	1,022,280
Shares, vested	(678,880)
Shares, fofeited	(50,463)
Ending balance	292,937	1,022,280
Weighted average grant date fair value, beginning balance	$ 24.08
Weighted average grant date fair value, granted		$ 23.14
Weighted average grant date fair value, vested	17.88
Weighted average grant date fair value, forfeited	23.26
Weighted average grant date fair value, ending balance	$ 23.13	$ 24.08

Stock-Based And Long-Term Com72

Stock-Based And Long-Term Compensation (Summary Of The Activity Of Restricted Stock Units) (Details) - Restricted Stock Units (RSUs) [Member]	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Share-based Compensation Arrangement by Share-based Payment Award [Line Items]
Beginning balance | shares	1,416,477
Granted | shares	2,162,146
Shares, vested | shares	(460,400)
Shares, fofeited | shares	(330,334)
Ending balance | shares	2,787,889
Weighted average grant date fair value, beginning balance | $ / shares	$ 26.40
Weighted average grant date fair value, granted | $ / shares	17.74
Weighted average grant date fair value, vested | $ / shares	18.51
Weighted average grant date fair value, forfeited | $ / shares	20.16
Weighted average grant date fair value, ending balance | $ / shares	$ 20.41

Stock-Based And Long-Term Com73

Stock-Based And Long-Term Compensation (Summary Of Compensation Expense and Tax Benefits) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Compensation expense	$ 45,572	$ 44,074	$ 35,060
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	12,055	11,463	9,267
Employee Stock Option [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Compensation expense	3,663	3,900	3,586
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	1,355	1,443	1,327
Restricted Stock [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Compensation expense	9,219	15,800	21,460
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	3,411	5,846	7,940
Restricted Stock Units (RSUs) [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Compensation expense	19,699	11,282
Employee Service Share-based Compensation, Tax Benefit from Compensation Expense	7,289	4,174
Performance Shares [Member]
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Compensation expense	10,733	10,688	10,014
2013 Employee Stock Purchase Plan Member
Share-based Compensation Arrangement by Share-based Payment Award, Options, Additional Disclosures [Abstract]
Compensation expense	$ 835	$ 1,078	$ 947

Income Taxes (Narrative) (Detai

Income Taxes (Narrative) (Details) - USD ($) $ in Thousands	36 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Income Taxes [Abstract]
U.S. Federal income tax rate	35.00%
net operating loss carryforwards	$ 102,100
Annual limitation on utilization of net operating loss carryforwards	500
Deferred tax assets, various state	25,200
Deferred Tax Assets, Tax Credit Carryforwards, Foreign	31,800
Undistributed earnings of foreign subsidiaries	52,000
Unrecorded tax benefits	$ 29,715	$ 30,344	$ 29,899	$ 26,399

Income Taxes (Schedule Of Compo

Income Taxes (Schedule Of Components Of Income And Loss From Continuing Operations Before Income Taxes) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income (Loss) from Continuing Operations before Equity Method Investments, Income Taxes, Extraordinary Items, Noncontrolling Interest [Abstract]
Domestic	$ (2,069,019)	$ 372,672	$ 165,463
Foreign	9,236	69,517	(64,706)
Income from continuing operations before income taxes	$ (2,059,783)	$ 442,189	$ 100,757

Income Taxes (Schedule Of Com76

Income Taxes (Schedule Of Components Of Income Tax Expense (Benefit) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Components of Income Tax Expense (Benefit), Continuing Operations [Abstract]
Current, federal	$ (952)	$ 150,997	$ 19,897
Current, state	2,818	11,339	10,816
Current, foreign	19,227	36,287	25,613
Current, total	21,093	198,623	56,326
Deferred, federal	(249,193)	(33,172)	(6,341)
Deferred, state	(10,034)	648	386
Deferred, foreign	(13,886)	(4,700)	4,901
Deferred income taxes	(273,113)	(37,224)	(1,054)
Income Tax Expense (Benefit), Total	$ (252,020)	$ 161,399	$ 55,272

Income Taxes (Schedule Of Effec

Income Taxes (Schedule Of Effective Income Tax Rate Reconciliation) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Expense (Benefit), Continuing Operations, Income Tax Reconciliation [Abstract]
Computed expected tax expense (benefit)	$ (720,923)	$ 154,766	$ 35,265
Increase (decrease) resulting from State and foreign income taxes	(6,353)	8,467	(852)
Increase (decrease) resulting other	10,861	(1,834)	(14,015)
Income Tax Expense (Benefit), Total	(252,020)	$ 161,399	55,272
Effective Income Tax Rate Reconciliation, Nondeductible Expense, Impairment Losses, Amount	$ 464,395		$ 34,874

Income Taxes (Schedule Of Defer

Income Taxes (Schedule Of Deferred Tax Assets and Liabilities) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Components of Deferred Tax Assets [Abstract]
Allowance for doubtful accounts	$ 8,275	$ 3,942
Operating loss and tax credit carryforwards	92,798	21,928
Compensation and employee benefits	59,310	57,045
Decommissioning liabilities	30,400	21,029
Other	57,768	50,641
Deferred tax assets, gross	248,551	154,585
Valuation allowance	(5,395)
Net deferred tax assets	243,156	154,585
Components of Deferred Tax Liabilities [Abstract]
Property, plant and equipment	469,728	648,054
Notes receivable	14,796	5,718
Goodwill and other intangible assets	119,661	138,017
Other	22,040	33,654
Deferred tax liabilities	626,225	825,443
Net deferred tax liability	$ (383,069)	$ (670,858)

Income Taxes (Net Deferred Tax

Income Taxes (Net Deferred Tax Liabilities Classified In The Consolidated Balance Sheet) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Deferred Tax Liabilities, Net, Classification [Abstract]
Noncurrent deferred income taxes	$ (383,069)	$ (670,858)
Net deferred tax liability	$ (383,069)	$ (670,858)

Income Taxes (Summary Of Activi

Income Taxes (Summary Of Activity In Unrecognized Tax Benefits) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Reconciliation of Unrecognized Tax Benefits, Excluding Amounts Pertaining to Examined Tax Returns [Roll Forward]
Unrecognized tax benefits, December 31, 2014, 2013 and 2012, respectively	$ 30,344	$ 29,899	$ 26,399
Additions based on tax positions related to prior years	6,752	7,860	5,065
Reductions based on tax positions related to prior years	(7,381)	(7,415)	(1,565)
Unrecognized tax benefits, December 31, 2015, 2014 and 2013, respectively	$ 29,715	$ 30,344	$ 29,899

Segment Information (Schedule O

Segment Information (Schedule Of Segment Reporting Information) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Revenues	$ 545,150	$ 601,396	$ 710,784	$ 917,235	$ 1,178,626	$ 1,209,026	$ 1,107,552	$ 1,061,418	$ 2,774,565	$ 4,556,622	$ 4,350,057
Cost of goods and services	397,548	420,485	465,533	582,246	711,243	721,692	650,293	651,605	1,865,812	2,734,833	2,633,590
Depreciation, depletion, amortization and accretion	144,818	146,757	158,352	$ 162,220	157,377	$ 170,154	$ 160,965	$ 162,318	612,147	650,814	604,441
General and administrative expenses									510,708	624,371	597,778
Reduction in the value of assets	175,618	$ 755,632	$ 807,637						1,738,887		300,078
Income from operations									(1,952,989)	546,604	214,170
Interest expense, net									97,318	96,734	107,902
Other Expense									(9,476)	(7,681)	(5,511)
Income (loss) from continuing operations before income taxes									(2,059,783)	442,189	100,757
Identifiable Assets	4,914,244				7,317,782				4,914,244	7,317,782	7,366,943
Capital Expenditures									358,226	616,102	608,960
Drilling Products And Services [Member]
Segment Reporting Information [Line Items]
Revenues									583,139	904,358	820,538
Cost of goods and services									196,921	282,023	268,127
Depreciation, depletion, amortization and accretion									194,061	186,642	168,391
General and administrative expenses									127,525	149,967	136,244
Reduction in the value of assets									40,237		2,292
Income from operations									24,395	285,726	245,484
Income (loss) from continuing operations before income taxes									24,395	285,726	245,484
Identifiable Assets	1,223,191				1,284,842				1,223,191	1,284,842	1,237,842
Capital Expenditures									129,504	274,752	246,479
Onshore Completion Services [Member]
Segment Reporting Information [Line Items]
Revenues									934,274	1,732,833	1,607,268
Cost of goods and services									773,119	1,205,443	1,091,956
Depreciation, depletion, amortization and accretion									225,667	233,430	216,152
General and administrative expenses									121,289	159,687	158,448
Reduction in the value of assets									783,229		16,975
Income from operations									(969,030)	134,273	123,737
Income (loss) from continuing operations before income taxes									(969,030)	134,273	123,737
Identifiable Assets	1,929,185				2,993,824				1,929,185	2,993,824	2,961,390
Capital Expenditures									103,001	152,742	101,854
Production Services [Member]
Segment Reporting Information [Line Items]
Revenues									759,606	1,350,956	1,434,990
Cost of goods and services									594,286	941,030	1,002,628
Depreciation, depletion, amortization and accretion									130,267	164,672	177,532
General and administrative expenses									139,304	187,526	190,647
Reduction in the value of assets									790,517		28,568
Income from operations									(894,768)	57,728	35,615
Interest expense, net									2,013
Income (loss) from continuing operations before income taxes									(896,781)	57,728	35,615
Identifiable Assets	967,719				2,098,592				967,719	2,098,592	2,158,653
Capital Expenditures									72,048	88,870	122,946
Technical Solutions [Member]
Segment Reporting Information [Line Items]
Revenues									497,546	568,475	487,261
Cost of goods and services									301,486	306,337	270,879
Depreciation, depletion, amortization and accretion									62,152	66,070	42,366
General and administrative expenses									122,590	127,191	112,439
Reduction in the value of assets									124,904		252,243
Income from operations									(113,586)	68,877	(190,666)
Interest expense, net									(1,707)	(1,577)	(1,323)
Other Expense											836
Income (loss) from continuing operations before income taxes									(111,879)	70,454	(188,507)
Identifiable Assets	$ 794,149				$ 940,524				794,149	940,524	1,009,058
Capital Expenditures									53,673	99,738	137,681
Unallocated [Member]
Segment Reporting Information [Line Items]
Interest expense, net									97,012	98,311	109,225
Other Expense									(9,476)	(7,681)	(6,347)
Income (loss) from continuing operations before income taxes									$ (106,488)	$ (105,992)	$ (115,572)

Segment Information (Schedule82

Segment Information (Schedule Of Identifiable Assets) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Assets	$ 4,914,244	$ 7,317,782	$ 7,366,943
Drilling Products And Services [Member]
Segment Reporting Information [Line Items]
Assets	1,223,191	1,284,842	1,237,842
Onshore Completion Services [Member]
Segment Reporting Information [Line Items]
Assets	1,929,185	2,993,824	2,961,390
Production Services [Member]
Segment Reporting Information [Line Items]
Assets	967,719	2,098,592	2,158,653
Technical Solutions [Member]
Segment Reporting Information [Line Items]
Assets	$ 794,149	$ 940,524	$ 1,009,058

Segment Information (Schedule83

Segment Information (Schedule Of Revenues By Geographic Segment) (Details) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Revenues	$ 545,150	$ 601,396	$ 710,784	$ 917,235	$ 1,178,626	$ 1,209,026	$ 1,107,552	$ 1,061,418	$ 2,774,565	$ 4,556,622	$ 4,350,057
Total, Revenues	545,150	$ 601,396	$ 710,784	$ 917,235	1,178,626	$ 1,209,026	$ 1,107,552	$ 1,061,418	2,774,565	4,556,622	4,350,057
Property, plant and equipment, net	2,123,291				2,733,839				2,123,291	2,733,839
UNITED STATES
Segment Reporting Information [Line Items]
Revenues									2,185,071	3,848,929	3,674,825
Total, Revenues									2,185,071	3,848,929	3,674,825
Long-lived assets	1,799,418				2,416,306				1,799,418	2,416,306
Other Countries Member
Segment Reporting Information [Line Items]
Revenues									589,494	707,693	675,232
Total, Revenues									589,494	707,693	$ 675,232
Long-lived assets	$ 323,873				$ 317,533				$ 323,873	$ 317,533

Segment Information (Schedule84

Segment Information (Schedule of Capital Expenditures, by Segment) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Capital Expenditures	$ 358,226	$ 616,102	$ 608,960
Drilling Products And Services [Member]
Segment Reporting Information [Line Items]
Capital Expenditures	129,504	274,752	246,479
Onshore Completion Services [Member]
Segment Reporting Information [Line Items]
Capital Expenditures	103,001	152,742	101,854
Production Services [Member]
Segment Reporting Information [Line Items]
Capital Expenditures	72,048	88,870	122,946
Technical Solutions [Member]
Segment Reporting Information [Line Items]
Capital Expenditures	$ 53,673	$ 99,738	$ 137,681

Commitments And Contingencies (

Commitments And Contingencies (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Commitments and Contingencies (Textual) [Abstract]
Rent expense	$ 29.6	$ 26.2	$ 25.6
2,016	45.7
2,017	32.4
2,018	23.3
2,019	16.1
2,020	10
Thereafter	$ 25.2

Fair Value Measurements (Narrat

Fair Value Measurements (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2013	Dec. 31, 2014
Fair Value Measurements [Abstract]
Interest rate swap agreement for notional amount	$ 300,000,000
Fair value of debt	1,508,000,000		$ 1,624,300,000
Impairment of long lived assets	343,300,000
Reduction in value of goodwill	1,326,701,000	$ 91,016,000
Impairment of Long-Lived Assets Held-for-use	343,300,000
Impairment of Intangible Assets, Finite-lived	$ 68,900,000

Fair Value Measurements (Summar

Fair Value Measurements (Summary Of Financial Assets And Liabilities Measured At Fair Value On Recurring Basis) (Details) - Fair Value, Measurements, Recurring [Member] - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Non-Qualified Deferred Compensation Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Accounts payable	$ 721
Intangible and other long-term assets	11,548	$ 12,982
Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Intangible and other long-term assets	6,905	4,183
Non Qualified Deferred Compensation Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other long-term liabilities	$ 17,367	14,720
Accounts payable		2,291
Level 1 [Member] | Non-Qualified Deferred Compensation Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Accounts payable
Intangible and other long-term assets	$ 368	$ 1,481
Level 1 [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Intangible and other long-term assets
Level 1 [Member] | Non Qualified Deferred Compensation Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other long-term liabilities
Accounts payable
Level 2 [Member] | Non-Qualified Deferred Compensation Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Accounts payable	$ 721
Intangible and other long-term assets	11,180	$ 11,501
Level 2 [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Intangible and other long-term assets	6,905	4,183
Level 2 [Member] | Non Qualified Deferred Compensation Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other long-term liabilities	$ 17,367	14,720
Accounts payable		$ 2,291
Level 3 [Member] | Non-Qualified Deferred Compensation Assets [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Accounts payable
Intangible and other long-term assets
Level 3 [Member] | Interest Rate Swap [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Intangible and other long-term assets
Level 3 [Member] | Non Qualified Deferred Compensation Liabilities [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Other long-term liabilities
Accounts payable

Fair Value Measurements (Fair V

Fair Value Measurements (Fair Value Measurements Used in Testing) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2013	Dec. 31, 2015	Dec. 31, 2013
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Finite Lived Intangible Assets Fair Value Used In Testing for Impairment	$ 68,890
Goodwill Fair Value Measurement Used in Testing for Impairment	1,326,701
Property, Plant and Equipment Fair Value Measurment Used in Testing Impairment of Long-Lived Assets	177,442
Reduction in value of goodwill			$ 1,326,701	$ 91,016
Impairment of Intangible Assets, Finite-lived			68,900
Impairment of Long-Lived Assets Held-for-use			$ 343,300
Level 1 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Finite Lived Intangible Assets Fair Value Used In Testing for Impairment	6,345
Goodwill Fair Value Measurement Used in Testing for Impairment	998,288
Property, Plant and Equipment Fair Value Measurment Used in Testing Impairment of Long-Lived Assets	$ 179,612
Level 2 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Finite Lived Intangible Assets Fair Value Used In Testing for Impairment		$ 18,296
Goodwill Fair Value Measurement Used in Testing for Impairment		91,016
Property, Plant and Equipment Fair Value Measurment Used in Testing Impairment of Long-Lived Assets		243,781
Level 3 [Member]
Fair Value, Assets and Liabilities Measured on Recurring and Nonrecurring Basis [Line Items]
Finite Lived Intangible Assets Fair Value Used In Testing for Impairment		4,355
Property, Plant and Equipment Fair Value Measurment Used in Testing Impairment of Long-Lived Assets		$ 328,876

Derivative Financial Instrume89

Derivative Financial Instruments (Narrative) (Details) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Financial Instruments [Abstract]
Derivative asset	$ 6,900,000	$ 4,200,000
Interest income (expense) related to the ineffectiveness associated with the fair value hedge	(2,700,000)	$ 3,800,000	$ 800,000
Interest rate swap agreement for notional amount	$ 300,000,000

Derivative Financial Instrume90

Derivative Financial Instruments (Location And Effect Of The Derivative Instrument On The Statements Of Operations) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Derivative Instruments, (Gain) Loss [Line Items]
Amount of (gain) loss recognized	$ (2,722)	$ (3,846)	$ 776
Hedged Item Debt [Member]
Derivative Instruments, (Gain) Loss [Line Items]
Amount of (gain) loss recognized	(790)	7,208	(12,303)
Interest Rate Swap [Member]
Derivative Instruments, (Gain) Loss [Line Items]
Amount of (gain) loss recognized	$ (1,932)	$ (11,054)	$ 13,079

Related Party Transactions (Det

Related Party Transactions (Details) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Related Party Transaction [Line Items]
Purchase of services		$ 221.1	$ 164.8
Trade Accounts Payable		26.8
Ortowski Construction [Member]
Related Party Transaction [Line Items]
Purchase of services		0.7
Trade Accounts Payable		0
ORTEQ Energy Services [Member]
Related Party Transaction [Line Items]
Purchase of services		92.1	52.8
Trade Accounts Payable		10.1
Resource Transport [Member]
Related Party Transaction [Line Items]
Purchase of services		21.6	14
Trade Accounts Payable		1.7
Texas Specialty Sands [Member]
Related Party Transaction [Line Items]
Purchase of services		79.3	69.1
Trade Accounts Payable		14
ProFuel LLC [Member]
Related Party Transaction [Line Items]
Purchase of services		25.5	26.9
Trade Accounts Payable		1
TIMBER CREEK REAL ESTATE PARTNERS [Member]
Related Party Transaction [Line Items]
Purchase of services		1.9	2
LINNENERGY[MEMBER]
Related Party Transaction [Line Items]
Revenue from Related Parties	$ 7.2	19.7	$ 26.9
Accounts Receivable, Related Parties, Current	$ 2	$ 1.6

Interim Financial Information92

Interim Financial Information (Unaudited) (Details) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2015	Sep. 30, 2015	Jun. 30, 2015	Mar. 31, 2015	Dec. 31, 2014	Sep. 30, 2014	Jun. 30, 2014	Mar. 31, 2014	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Selected Quarterly Financial Information [Abstract]
Revenues	$ 545,150	$ 601,396	$ 710,784	$ 917,235	$ 1,178,626	$ 1,209,026	$ 1,107,552	$ 1,061,418	$ 2,774,565	$ 4,556,622	$ 4,350,057
Costs and Expenses [Abstract]
Cost of services and rentals	397,548	420,485	465,533	582,246	711,243	721,692	650,293	651,605	1,865,812	2,734,833	2,633,590
Depreciation, depletion, amortization and accretion	144,818	146,757	158,352	162,220	157,377	170,154	160,965	162,318	612,147	650,814	604,441
Gross Profit	2,784	34,154	86,899	172,769	310,006	317,180	296,294	247,495
Reduction in value of assets	175,618	755,632	807,637						1,738,887		300,078
Net income (loss) from continuing operations	(214,547)	(816,587)	(775,132)	(1,497)	73,364	85,743	79,057	42,626	(1,807,763)	280,790	45,485
Loss from discontinued operations, net of tax	(22,848)	(4,610)	(9,857)	(9,640)	(7,238)	(5,886)	(3,895)	(5,954)	(46,955)	(22,973)	(156,903)
Net Income (Loss)	$ (237,395)	$ (821,197)	$ (784,989)	$ (11,137)	$ 66,126	$ 79,857	$ 75,162	$ 36,672	$ (1,854,718)	$ 257,817	$ (111,418)
Earnings Per Share [Abstract]
Continuing operations, basic	$ (1.43)	$ (5.42)	$ (5.15)	$ (0.02)	$ 0.49	$ 0.55	$ 0.51	$ 0.27	$ (12.02)	$ 1.81	$ 0.29
Continuing operations, diluted					0.48	0.55	0.50	0.27	(12.02)	1.79	0.28
Discontinued operations, basic	$ (0.15)	$ (0.03)	$ (0.07)	$ (0.06)	$ (0.05)	$ (0.03)	$ (0.03)	$ (0.04)	(0.31)	(0.15)	(0.99)
Discontinued operations, diluted									$ (0.31)	$ (0.14)	$ (0.97)

Supplementary Oil And Natural93

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Narrative) (Details)	12 Months Ended
	Dec. 31, 2015$ / Mcf	Dec. 31, 2015$ / Boe	Dec. 31, 2015$ / bbl	Dec. 31, 2015$ / BTU	Dec. 31, 2014$ / Mcf	Dec. 31, 2014$ / Boe	Dec. 31, 2014$ / bbl	Dec. 31, 2014$ / BTU	Dec. 31, 2014	Dec. 31, 2013$ / Mcf	Dec. 31, 2013$ / Boe	Dec. 31, 2013$ / bbl	Dec. 31, 2013$ / BTU
Oil and Gas Exploration and Production Industries Disclosures [Abstract]
Average sales prices	2.82	47.17			4.95	92.86				3.98	101.85
Average production costs | $ / Boe		10.38				7.29					10.70
Percentage of annual discount rate for future cash flows									10.00%
Supplementary Oil and Natural Gas Disclosures (Textual) [Abstract]
Twelve month average price on the basis of which oil price is estimated | $ / bbl			50.28				94.99					93.42
Twelve month average price on the basis of which gas price is estimated | $ / BTU				2.66				4,350,000					3.67

Supplementary Oil And Natural94

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Schedule Of Proved Developed And Undeveloped Oil And Gas Reserves) (Details) MMcf in Thousands, MBbls in Thousands	12 Months Ended
	Dec. 31, 2015MBblsMMcf	Dec. 31, 2014MBblsMMcf	Dec. 31, 2013MBblsMMcf
Oil [Member]
Proved Developed and Undeveloped Reserves [Abstract]
Beginning balance | MBbls	3,417	4,593	8,207
Revisions | MBbls	(381)	(438)	(3,203)
Production | MBbls	(633)	(738)	(411)
Ending balance | MBbls	2,403	3,417	4,593
Proved-developed reserves:
Proved Developed Reserves (Volume) | MBbls	2,202	3,184	2,397
Proved-undeveloped reserves:
Proved Undeveloped Reserve (Volume) | MBbls	201	233	2,196
Natural Gas [Member]
Proved Developed and Undeveloped Reserves [Abstract]
Beginning balance | MMcf	7,136	6,952	11,284
Revisions | MMcf	(245)	1,431	(4,036)
Production | MMcf	(1,517)	(1,247)	(296)
Ending balance | MMcf	5,374	7,136	6,952
Proved-developed reserves:
Proved Developed Reserves (Volume) | MMcf	5,216	6,945	2,100
Proved-undeveloped reserves:
Proved Undeveloped Reserve (Volume) | MMcf	158	191	4,852

Supplementary Oil And Natural95

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Cost Incurred In Oil And Gas Property Acquisition, Exploration, And Development Activities) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Costs Incurred, Oil and Gas Property Acquisition, Exploration, and Development Activities [Abstract]
Development costs	$ 20,636	$ 52,719	$ 51,527
Total costs incurred	$ 20,636	$ 52,719	$ 51,527

Supplementary Oil And Natural96

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Capitalized Costs Relating To Oil And Gas Producing Activities) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Capitalized Costs, Oil and Gas Producing Activities, Net [Abstract]
Proved oil and gas properties	$ 66,285	$ 189,294
Accumulated depreciation, depletion and amortization		(55,864)
Capitalized costs, net	$ 66,285	$ 133,430

Supplementary Oil And Natural97

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Schedule Of Ownership In Productive Oil And Natural Gas Wells) (Details)	Dec. 31, 2015item
Company's ownership of productive oil and natural gas wells
Oil, gross	11
Oil, net	5.61

Supplementary Oil And Natural98

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Schedule Of Gas And Oil Acreage) (Details)	Dec. 31, 2015a
Information relating to acreage held by the Company
Developed, gross acreage	23,040
Undeveloped, gross acreage	0
Total developed and undeveloped gross acreage	23,040
Developed, net acreage	11,750
Undeveloped, net acreage	0
Total developed and undeveloped net Acreage	11,750

Supplementary Oil And Natural99

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Schedule Of Drilling Activity) (Details) - item	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Exploratory Wells Drilled
Exploratory wells productive, gross	0	0
Exploratory wells non-productive, gross	0	0
Exploratory wells productive and non-productive, gross	0	0
Exploratory wells productive, net	0	0
Exploratory wells non-productive, net	0	0
Exploratory wells productive and non-productive, net	0
Development Wells Drilled
Total Development Wells Net	1.02	1.53
Non-Productive Development Wells Net	0.51	0.51
Productive Development Wells Net	0.51	1.02
Total Development Wells Gross	2	3
Non-Productive Development Wells Gross	1	1
Productive Development Wells Gross	1	2

Supplementary Oil And Natura100

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Results Of Operations For Oil And Gas Producing Activities) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Revenues
Sales	$ 30,245	$ 77,845	$ 47,050
Production costs	15,466	13,529	9,876
Depreciation, depletion and amortization	37,623	38,768	12,032
Reduction in value of assets	56,000
Income before income taxes	(78,844)	25,548	25,142
Income tax expenses	(28,778)	9,325	8,800
Results of operations from producing activities (excluding corporate overhead)	$ (50,066)	$ 16,223	$ 16,342

Supplementary Oil And Natura101

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Standardized Measure Of Discounted Future Cash Flows Relating To Proved Reserves) (Details) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Discounted Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Standardized Measure [Abstract]
Standardized measure of discounted future net cash flows	$ 21,063	$ 111,050	$ 157,729	$ 303,430
Future net cash flows	1,301	94,016	168,370
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Cash Inflows	127,048	336,944	496,704
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Production Costs	43,010	71,209	82,487
Future Net Cash Flows Relating to Prived Oil and Gas Reserves Future Develpment And Abandonment Costs	84,090	111,374	156,340
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, Future Income Tax Expense	(1,353)	60,345	89,507
Future Net Cash Flows Relating to Proved Oil and Gas Reserves, 10 Percent Annual Discount for Estimated Timing of Cash Flows	$ (19,762)	$ (17,034)	$ 10,641

Supplementary Oil And Natura102

Supplementary Oil And Natural Gas Disclosures (Unaudited) (Summary Of Changes In Standardized Measure Of Discounted Future Net Cash Flows Applicable To Proved Oil And Natural Gas Reserves) (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Increase (Decrease) in Standardized Measure of Discounted Future Net Cash Flow Relating to Proved Oil and Gas Reserves [Roll Forward]
Beginning of the period	$ 111,050	$ 157,729	$ 303,430
Net change in sales and transfer prices and in production (lifting) costs related to future production	(143,808)	(57,568)	(13,278)
Changes in estimated future development costs	3,787	(5,512)	(48,594)
Sales and transfers of oil and gas produced during the period	(14,779)	(64,316)	(45,866)
Net change due to extensions, discoveries, and improved recovery	6,737		75,304
Net changes due to revisions in quantity estimates	(36,397)	(8,396)	(228,620)
Previously estimated development costs incurred during period	20,636	40,962	10,136
Accretion of discount	17,606	24,251	46,711
Other-unspecified	1,895	4,125	(24,169)
Net change in income taxes	54,336	19,775	82,675
Aggregate change in the standardized measure of discounted future net cash flows for the year	(89,987)	(46,679)	(145,701)
End of the period	$ 21,063	$ 111,050	$ 157,729

Valuation and Qualifying Acc103

Valuation and Qualifying Accounts (Details) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Movement in Valuation Allowances and Reserves [Roll Forward]
Valuation Allowances and Reserves, Balance, Beginning Balance	$ 22,076	$ 31,030	$ 28,715
Valuation Allowances and Reserves, Charged to Cost and Expense	14,341	6,299	7,587
Valuation Allowances and Reserves, Deductions	4,795	10,639	7,763
Valuation Allowances and Reserves, Reclassifications to Assets Held for Sale	3,380	4,614	(2,491)
Valuation Allowances and Reserves, Balance, Ending Balance	$ 28,242	$ 22,076	$ 31,030