Patterson-UTI Energy (PTEN) 10-K 10 Feb 16 2015 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2015	Feb. 04, 2016	Jun. 30, 2015
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2015
Document Fiscal Year Focus	2,015
Document Fiscal Period Focus	FY
Trading Symbol	PTEN
Entity Registrant Name	PATTERSON UTI ENERGY INC
Entity Central Index Key	889,900
Current Fiscal Year End Date	--12-31
Entity Well-known Seasoned Issuer	Yes
Entity Current Reporting Status	Yes
Entity Voluntary Filers	No
Entity Filer Category	Large Accelerated Filer
Entity Common Stock, Shares Outstanding		147,179,777
Entity Public Float			$ 2.7

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Current assets:
Cash and cash equivalents	$ 113,346	$ 43,012
Accounts receivable, net of allowance for doubtful accounts of $3,545 and $3,546 at December 31, 2015 and 2014, respectively	219,672	663,404
Federal and state income taxes receivable	33,454	81,726
Inventory	14,716	32,251
Deferred tax assets, net	65,121	37,075
Other	40,227	51,624
Total current assets	486,536	909,092
Property and equipment, net	3,920,708	4,131,071
Goodwill and intangible assets	92,609	220,813
Deposits on equipment purchases	22,367	112,379
Other	11,097	20,656
Total assets	4,533,317	5,394,011
Current liabilities:
Accounts payable	82,771	382,438
Accrued expenses	161,611	173,466
Current portion of long-term debt	63,750	12,500
Total current liabilities	308,132	568,404
Borrowings under revolving credit facility		303,000
Other long-term debt	791,250	670,000
Deferred tax liabilities, net	863,833	935,660
Other	8,971	11,137
Total liabilities	$ 1,972,186	$ 2,488,201
Commitments and contingencies (see Note 8)
Stockholders’ equity:
Preferred stock, par value $.01; authorized 1,000,000 shares, no shares issued
Common stock, par value $.01; authorized 300,000,000 shares with 190,374,801 and 189,262,876 issued and 147,167,561 and 146,444,291 outstanding at December 31, 2015 and 2014, respectively	$ 1,904	$ 1,893
Additional paid-in capital	1,011,811	984,674
Retained earnings	2,458,554	2,811,815
Accumulated other comprehensive income (loss)	(4,093)	6,463
Treasury stock, at cost, 43,207,240 shares and 42,818,585 shares at December 31, 2015 and 2014, respectively	(907,045)	(899,035)
Total stockholders’ equity	2,561,131	2,905,810
Total liabilities and stockholders’ equity	$ 4,533,317	$ 5,394,011

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Statement Of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 3,545	$ 3,546
Preferred stock, par value	$ 0.01	$ 0.01
Preferred stock, authorized	1,000,000	1,000,000
Preferred stock, shares issued	0	0
Common stock, par value	$ 0.01	$ 0.01
Common stock, authorized	300,000,000	300,000,000
Common stock, issued	190,374,801	189,262,876
Common stock, outstanding	147,167,561	146,444,291
Treasury stock, shares	43,207,240	42,818,585

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Operating revenues:
Oil and natural gas		$ 24,931,000	$ 50,196,000	$ 57,257,000
Total operating revenues		1,891,277,000	3,182,291,000	2,716,034,000
Operating costs and expenses:
Contract drilling		608,848,000	1,066,659,000	968,754,000
Pressure pumping		612,021,000	1,036,310,000	744,243,000
Oil and natural gas		11,500,000	13,102,000	12,909,000
Depreciation, depletion, amortization and impairment		864,759,000	718,730,000	597,469,000
Impairment of goodwill		124,561,000
Selling, general and administrative		87,173,000	80,145,000	73,852,000
Net gain on asset disposals	[1]	(10,613,000)	(15,781,000)	(3,384,000)
Total operating costs and expenses		2,298,249,000	2,899,165,000	2,393,843,000
Operating income (loss)		(406,972,000)	283,126,000	322,191,000
Other income (expense):
Interest income		964,000	979,000	918,000
Interest expense, net of amount capitalized		(36,475,000)	(29,825,000)	(28,359,000)
Other		34,000	3,000	1,691,000
Total other expense		(35,477,000)	(28,843,000)	(25,750,000)
Income (loss) before income taxes		(442,449,000)	254,283,000	296,441,000
Income tax expense (benefit):
Current		(48,090,000)	47,946,000	57,863,000
Deferred		(99,873,000)	43,673,000	50,569,000
Total income tax expense (benefit)		(147,963,000)	91,619,000	108,432,000
Net income (loss)		$ (294,486,000)	$ 162,664,000	$ 188,009,000
Net income (loss) per common share:
Basic		$ (2)	$ 1.12	$ 1.29
Diluted		$ (2)	$ 1.11	$ 1.28
Weighted average number of common shares outstanding:
Basic		145,416	144,066	144,356
Diluted		145,416	145,376	145,303
Cash dividends per common share		$ 0.40	$ 0.40	$ 0.20
Contract Drilling
Operating revenues:
Oil and gas services		$ 1,153,892,000	$ 1,838,830,000	$ 1,679,611,000
Operating costs and expenses:
Impairment of goodwill		0
Pressure Pumping
Operating revenues:
Oil and gas services		$ 712,454,000	$ 1,293,265,000	$ 979,166,000
[1]	Net gains or losses associated with the disposal of assets relate to corporate strategy decisions of the executive management group. Accordingly, the related gains or losses have been separately presented and excluded from the results of specific segments.

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement Of Income And Comprehensive Income [Abstract]
Net income (loss)	$ (294,486)	$ 162,664	$ 188,009
Other comprehensive loss, net of taxes of $0 for 2015, $0 for 2014 and $0 for 2013:
Foreign currency translation adjustment	(10,556)	(7,613)	(7,691)
Total comprehensive income (loss)	$ (305,042)	$ 155,051	$ 180,318

CONSOLIDATED STATEMENTS OF COM6

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement Of Income And Comprehensive Income [Abstract]
Other comprehensive income (loss), taxes	$ 0	$ 0	$ 0

CONSOLIDATED STATEMENTS OF CHAN

CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Income	Treasury Stock
Beginning Balance at Dec. 31, 2012	$ 2,640,657	$ 1,841	$ 863,558	$ 2,548,542	$ 21,767	$ (795,051)
Beginning Balance (in shares) at Dec. 31, 2012		184,060,000
Net income (loss)	188,009			188,009
Foreign currency translation adjustment	(7,691)				(7,691)
Issuance of restricted stock (in shares)		1,312,000
Issuance of restricted stock		$ 13	(13)
Vesting of restricted stock units (in shares)		9,000
Forfeitures of restricted stock (in shares)		(84,000)
Forfeitures of restricted stock		$ (1)	1
Exercise of stock options (in shares)		1,190,000
Exercise of stock options	19,286	$ 12	19,274
Stock-based compensation	25,891		25,891
Tax benefit (expense) related to stock-based compensation	4,794		4,794
Payment of cash dividends	(29,112)			(29,112)
Purchase of treasury stock	(85,837)					(85,837)
Ending Balance at Dec. 31, 2013	2,755,997	$ 1,865	913,505	2,707,439	14,076	(880,888)
Ending Balance (in shares) at Dec. 31, 2013		186,487,000
Net income (loss)	162,664			162,664
Foreign currency translation adjustment	(7,613)				(7,613)
Issuance of restricted stock (in shares)		1,102,000
Issuance of restricted stock		$ 11	(11)
Vesting of restricted stock units (in shares)		10,000
Vesting of restricted stock units	1	$ 1
Forfeitures of restricted stock (in shares)		(61,000)
Forfeitures of restricted stock		$ (1)	1
Exercise of stock options (in shares)		1,725,000
Exercise of stock options	35,435	$ 17	35,418
Stock-based compensation	27,032		27,032
Tax benefit (expense) related to stock-based compensation	8,729		8,729
Payment of cash dividends	(58,288)			(58,288)
Purchase of treasury stock	(18,147)					(18,147)
Ending Balance at Dec. 31, 2014	$ 2,905,810	$ 1,893	984,674	2,811,815	6,463	(899,035)
Ending Balance (in shares) at Dec. 31, 2014	189,262,876	189,263,000
Net income (loss)	$ (294,486)			(294,486)
Foreign currency translation adjustment	(10,556)				(10,556)
Issuance of restricted stock (in shares)		1,180,000
Issuance of restricted stock		$ 12	(12)
Vesting of restricted stock units (in shares)		14,000
Forfeitures of restricted stock (in shares)		(82,000)
Forfeitures of restricted stock		$ (1)	1
Stock-based compensation	28,510		28,510
Tax benefit (expense) related to stock-based compensation	(1,362)		(1,362)
Payment of cash dividends	(58,775)			(58,775)
Purchase of treasury stock	(8,010)					(8,010)
Ending Balance at Dec. 31, 2015	$ 2,561,131	$ 1,904	$ 1,011,811	$ 2,458,554	$ (4,093)	$ (907,045)
Ending Balance (in shares) at Dec. 31, 2015	190,374,801	190,375,000

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)		$ (294,486)	$ 162,664	$ 188,009
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion, amortization and impairment		864,759	718,730	597,469
Impairment of goodwill		124,561
Dry holes and abandonments		1,224	550	89
Deferred income tax expense (benefit)		(99,873)	43,673	50,569
Stock-based compensation expense		28,510	27,032	25,891
Net gain on asset disposals	[1]	(10,613)	(15,781)	(3,384)
Tax expense related to stock-based compensation		(1,362)
Changes in operating assets and liabilities:
Accounts receivable		440,884	(214,059)	12,007
Income taxes receivable/payable		49,895	(92,352)	4,447
Inventory and other assets		40,238	(5,737)	570
Accounts payable		(131,649)	86,621	11,331
Accrued expenses		(10,303)	12,838	1,973
Other liabilities		(2,348)	4,547	(100)
Net cash provided by operating activities		999,437	728,726	888,871
Cash flows from investing activities:
Acquisitions			(176,301)
Purchases of property and equipment		(743,776)	(1,052,341)	(662,461)
Proceeds from disposal of assets		20,814	33,233	10,386
Net cash used in investing activities		(722,962)	(1,195,409)	(652,075)
Cash flows from financing activities:
Purchases of treasury stock		(8,010)	(13,554)	(73,510)
Dividends paid		(58,775)	(58,288)	(29,112)
Tax benefit related to stock-based compensation			8,729	4,794
Proceeds from long-term debt		200,000
Repayment of long-term debt		(27,500)	(10,000)	(6,250)
Proceeds from borrowings under revolving credit facility		54,000	349,500
Repayment of borrowings under revolving credit facility		(357,000)	(46,500)
Debt issuance costs		(1,979)
Proceeds from exercise of stock options			30,842	6,959
Net cash provided by (used in) financing activities		(199,264)	260,729	(97,119)
Effect of foreign exchange rate changes on cash		(6,877)	(543)	(891)
Net increase (decrease) in cash and cash equivalents		70,334	(206,497)	138,786
Cash and cash equivalents at beginning of year		43,012	249,509	110,723
Cash and cash equivalents at end of year		113,346	43,012	249,509
Net cash (paid) received during the year for:
Interest, net of capitalized interest of $6,332 in 2015, $6,883 in 2014 and $7,775 in 2013		(33,452)	(27,813)	(26,228)
Income taxes		97,333	(125,953)	(42,600)
Non-cash investing and financing activities:
Net (decrease) increase in payables for purchases of property and equipment		(167,308)	122,148	(26,899)
Net decrease in deposits on equipment purchases		$ (90,012)	$ (59,819)	$ (8,784)
[1]	Net gains or losses associated with the disposal of assets relate to corporate strategy decisions of the executive management group. Accordingly, the related gains or losses have been separately presented and excluded from the results of specific segments.

CONSOLIDATED STATEMENTS OF CAS9

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Statement Of Cash Flows [Abstract]
Interest expense, capitalized interest	$ 6,332	$ 6,883	$ 7,775

Description of Business and Sum

Description of Business and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Description of Business and Summary of Significant Accounting Policies	1. Description of Business and Summary of Significant Accounting Policies A description of the business and basis of presentation follows: Description of business — Patterson-UTI Energy, Inc., through its wholly-owned subsidiaries (collectively referred to herein as “Patterson-UTI” or the “Company”), provides onshore contract drilling services to major, independent and other oil and natural gas operators in the continental United States and western Canada. The Company provides pressure pumping services to major, independent and other oil and natural gas operators primarily in Texas and the Appalachian region. The Company also invests in oil and natural gas properties on a non-operating working interest basis. Basis of presentation — The consolidated financial statements include the accounts of Patterson-UTI and its wholly-owned subsidiaries. All significant intercompany accounts and transactions have been eliminated. Except for wholly-owned subsidiaries, the Company has no controlling financial interests in any other entity which would require consolidation. The U.S. dollar is the functional currency for all of the Company’s operations except for its Canadian operations, which use the Canadian dollar as its functional currency. The effects of exchange rate changes are reflected in accumulated other comprehensive income, which is a separate component of stockholders’ equity. A summary of the significant accounting policies follows: Management estimates — The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make 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 such estimates. Revenue recognition — Revenues from daywork drilling and pressure pumping activities are recognized as services are performed. Expenditures reimbursed by customers are recognized as revenue and the related expenses are recognized as direct costs. All of the wells the Company drilled in 2015, 2014 and 2013 were drilled under daywork contracts. Accounts receivable — Trade accounts receivable are recorded at the invoiced amount. The allowance for doubtful accounts represents the Company’s estimate of the amount of probable credit losses existing in the Company’s accounts receivable. The Company reviews the adequacy of its allowance for doubtful accounts at least quarterly. Significant individual accounts receivable balances and balances which have been outstanding greater than 90 days are reviewed individually for collectability. Account balances, when determined to be uncollectable, are charged against the allowance. Inventories — Inventories consist primarily of sand and other products to be used in conjunction with the Company’s pressure pumping activities. The inventories are stated at the lower of cost or market, determined under the average cost method. Property and equipment — Property and equipment is carried at cost less accumulated depreciation. Depreciation is provided on the straight-line method over the estimated useful lives. The method of depreciation does not change whenever equipment becomes idle. The estimated useful lives, in years, are shown below: Useful Lives Drilling rigs and other equipment 1.25-15 Buildings 15-20 Other 3-12 Long-lived assets, including property and equipment, are evaluated for impairment when certain triggering events or changes in circumstances indicate that the carrying values may not be recoverable over their estimated remaining useful life. Oil and natural gas properties — Working interests in oil and natural gas properties are accounted for using the successful efforts method of accounting. Under the successful efforts method of accounting, exploration costs which result in the discovery of oil and natural gas reserves and all development costs are capitalized to the appropriate well. Exploration costs which do not result in discovering oil and natural gas reserves are charged to expense when such determination is made. Costs of exploratory wells are initially capitalized to wells-in-progress until the outcome of the drilling is known. The Company reviews wells-in-progress quarterly to determine whether sufficient progress is being made in assessing the reserves and economic viability of the respective projects. If no progress has been made in assessing the reserves and economic viability of a project after one year following the completion of drilling, the Company considers the well costs to be impaired and recognizes the costs as expense. Geological and geophysical costs, including seismic costs, and costs to carry and retain undeveloped properties are charged to expense when incurred. The capitalized costs of both developmental and successful exploratory type wells, consisting of lease and well equipment and intangible development costs, are depreciated, depleted and amortized using the units-of-production method, based on engineering estimates of total proved developed oil and natural gas reserves for each respective field. Oil and natural gas leasehold acquisition costs are depreciated, depleted and amortized using the units-of-production method, based on engineering estimates of total proved oil and natural gas reserves for each respective field. The Company reviews its proved oil and natural gas properties for impairment whenever a triggering event occurs, such as downward revisions in reserve estimates or decreases in expected future oil and natural gas prices. Proved properties are grouped by field and undiscounted cash flow estimates are prepared based on management’s expectation of future pricing over the lives of the respective fields. These cash flow estimates are reviewed by an independent petroleum engineer. If the net book value of a field exceeds its undiscounted cash flow estimate, impairment expense is measured and recognized as the difference between net book value and fair value. The fair value estimates used in measuring impairment are based on internally developed unobservable inputs including reserve volumes and future production, pricing and operating costs (Level 3 inputs in the fair value hierarchy of fair value accounting). The expected future net cash flows are discounted using an annual rate of 10% to determine fair value. The Company reviews unproved oil and natural gas properties quarterly to assess potential impairment. The Company’s impairment assessment is made on a lease-by-lease basis and considers factors such as management’s intent to drill, lease terms and abandonment of an area. If an unproved property is determined to be impaired, the related property costs are expensed. Goodwill — Goodwill is considered to have an indefinite useful economic life and is not amortized. The Company assesses impairment of its goodwill at least annually as of December 31, or on an interim basis if events or circumstances indicate that the fair value of goodwill may have decreased below its carrying value. Maintenance and repairs — Maintenance and repairs are charged to expense when incurred. Renewals and betterments which extend the life or improve existing property and equipment are capitalized. Disposals — Upon disposition of property and equipment, the cost and related accumulated depreciation are removed and any resulting gain or loss is reflected in the consolidated statement of operations. Net income (loss) per common share — The Company provides a dual presentation of its net income (loss) per common share in its consolidated statements of operations: Basic net income (loss) per common share (“Basic EPS”) and diluted net income (loss) per common share (“Diluted EPS”). Basic EPS excludes dilution and is computed by first allocating earnings between common stockholders and holders of non-vested shares of restricted stock. Basic EPS is then determined by dividing the earnings attributable to common stockholders by the weighted average number of common shares outstanding during the period, excluding non-vested shares of restricted stock. Diluted EPS is based on the weighted average number of common shares outstanding plus the dilutive effect of potential common shares, including stock options, non-vested shares of restricted stock and restricted stock units. The dilutive effect of stock options and restricted stock units is determined using the treasury stock method. The dilutive effect of non-vested shares of restricted stock is based on the more dilutive of the treasury stock method or the two-class method, assuming a reallocation of undistributed earnings to common stockholders after considering the dilutive effect of potential common shares other than non-vested shares of restricted stock. The following table presents information necessary to calculate net income (loss) per share for the years ended December 31, 2015, 2014 and 2013, as well as potentially dilutive securities excluded from the weighted average number of diluted common shares outstanding because their inclusion would have been anti-dilutive (in thousands, except per share amounts): 2015 2014 2013 BASIC EPS: Net income (loss) $ (294,486 ) $ 162,664 $ 188,009 Adjust for (income) loss attributed to holders of non-vested restricted stock 3,022 (1,663 ) (1,859 ) Income (loss) attributed to common stockholders $ (291,464 ) $ 161,001 $ 186,150 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 145,416 144,066 144,356 Basic net income (loss) per common share $ (2.00 ) $ 1.12 $ 1.29 DILUTED EPS: Income (loss) attributed to common stockholders $ (291,464 ) $ 161,001 $ 186,150 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 145,416 144,066 144,356 Add dilutive effect of potential common shares — 1,310 947 Weighted average number of diluted common shares outstanding 145,416 145,376 145,303 Diluted net income (loss) per common share $ (2.00 ) $ 1.11 $ 1.28 Potentially dilutive securities excluded as anti-dilutive 7,781 1,088 2,447 Income taxes — The asset and liability method is used in accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for operating loss and tax credit carryforwards and for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the results of operations in the period that includes the enactment date. If applicable, a valuation allowance is recorded to reduce the carrying amounts of deferred tax assets unless it is more likely than not that such assets will be realized. The Company’s policy is to account for interest and penalties with respect to income taxes as operating expenses. Stock-based compensation — The Company recognizes the cost of share-based payments under the fair-value-based method. Under this method, compensation cost related to share-based payments is measured based on the estimated fair value of the awards at the date of grant, net of estimated forfeitures. This expense is recognized over the expected life of the awards (See Note 10). Statement of cash flows — For purposes of reporting cash flows, cash and cash equivalents include cash on deposit and money market funds. Recently Issued Accounting Standards — In May 2014, the Financial Accounting Standards Board (“FASB”) issued an accounting standards update to provide guidance on the recognition of revenue from customers. Under this guidance, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects what it expects in exchange for the goods or services. This guidance also requires more detailed disclosures to enable users of the financial statements to understand the nature, amount, timing and uncertainty, if any, of revenue and cash flows arising from contracts with customers. The requirements in this update are effective during interim and annual periods beginning after December 15, 2016. The Company is currently evaluating the impact this guidance will have on its consolidated financial statements. In June 2014, the FASB issued an accounting standards update to provide guidance on the accounting for share-based payments when the terms of an award provide that a performance target could be achieved after the requisite service period. The guidance requires that a performance target that affects vesting and that could be achieved after the requisite service period is treated as a performance condition. The requirements in this update are effective during interim and annual periods beginning after December 15, 2015. The adoption of this update is not expected to have a material impact on the Company’s consolidated financial statements. In April 2015, the FASB issued an accounting standards update to provide guidance for the presentation of debt issuance costs. Under this guidance, debt issuance costs shall be presented in the balance sheet as a direct deduction from the carrying amount of the related debt and shall not be classified as a deferred charge. Amortization of debt issuance costs shall continue to be reported as interest expense. The requirements in this update are effective during interim and annual periods beginning after December 15, 2015. The adoption of this update is not expected to have a material impact on the Company’s consolidated financial statements. In November 2015, the FASB issued an accounting standards update to provide guidance for the presentation of deferred tax liabilities and assets. Under this guidance, for a particular tax-paying component of an entity and within a particular tax jurisdiction, all deferred tax liabilities and assets, as well as any related valuation allowance, shall be offset and presented as a single noncurrent amount. The requirements in this update are effective during interim and annual periods beginning after December 15, 2016. The adoption of this update is not expected to have a material impact on the Company’s consolidated financial statements.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Acquisitions	2. Acquisitions During 2014, the Company completed two pressure pumping acquisitions. In June 2014, a subsidiary of the Company acquired the East Texas-based pressure pumping assets of a privately held company. This acquisition included 31,500 horsepower of hydraulic fracturing equipment. In October 2014, a subsidiary of the Company completed the acquisition of the Texas-based pressure pumping assets of a privately held company. This acquisition included 148,250 horsepower of hydraulic fracturing equipment. In total, the Company paid $176 million in cash for these two acquisitions plus the assumption of property leases and other contractual obligations. The purchase price was allocated to the assets acquired based on fair value. A summary of the purchase price allocation follows (in thousands): Inventory $ 1,357 Equipment 117,958 Goodwill 56,986 Total purchase price $ 176,301 Results of operations of the acquired businesses are included in the Company’s consolidated results of operations from their respective dates of acquisition. Revenues of $80.8 million and income from operations of $13.7 million from the acquired businesses are included in the consolidated statement of operations for the year ended December 31, 2014. The following represents pro-forma unaudited financial information for the years ended December 31, 2014 and 2013 as if the acquisitions had been completed on January 1, 2013 (in thousands, except per share amounts): 2014 2013 (Unaudited) Revenue $ 3,302,492 $ 2,854,867 Net income $ 169,831 $ 196,600 Basic net income per common share $ 1.17 $ 1.35 Diluted net income per common share $ 1.16 $ 1.34

Property and Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2015
Property Plant And Equipment [Abstract]
Property and Equipment	3. Property and Equipment Property and equipment consisted of the following at December 31, 2015 and 2014 (in thousands): 2015 2014 Equipment $ 6,963,148 $ 6,679,894 Oil and natural gas properties 200,923 196,234 Buildings 96,470 83,465 Land 22,370 12,038 Total property and equipment 7,282,911 6,971,631 Less accumulated depreciation, depletion and impairment (3,362,203 ) (2,840,560 ) Property and equipment, net $ 3,920,708 $ 4,131,071 Depreciation, depletion, amortization and impairment — The following table summarizes depreciation, depletion, amortization and impairment expense related to property and equipment and intangible assets for 2015, 2014 and 2013 (in thousands): 2015 2014 2013 Depreciation and impairment expense $ 845,543 $ 693,390 $ 573,106 Amortization expense 3,643 3,643 3,993 Depletion expense 15,573 21,697 20,370 Total $ 864,759 $ 718,730 $ 597,469 On a periodic basis, the Company evaluates its fleet of drilling rigs for marketability based on the condition of inactive rigs, expenditures that would be necessary to bring them to working condition and the expected demand for drilling services by rig type (such as drilling conventional, vertical wells versus drilling longer, horizontal wells using higher specification rigs). The components comprising rigs that will no longer be marketed are evaluated, and those components with continuing utility to the Company’s other marketed rigs are transferred to other rigs or to the Company’s yards to be used as spare equipment. The remaining components of these rigs will be retired. In 2015, the Company identified 24 mechanical rigs and 9 non-APEX® electric rigs that would no longer be marketed. Also, the Company had 15 additional mechanical rigs that were not operating. Although these 15 rigs remain marketable, the Company has lower expectations with respect to utilization of these rigs due to the industry shift to higher specification drilling rigs. In 2015, the Company recorded a charge of $131 million related to the retirement of the 33 rigs, the 15 mechanical rigs that remain marketable but were not operating, and the write-down of excess spare rig components to their realizable values. In 2014, the Company identified 55 mechanical rigs that it determined would no longer be marketed, and the Company recorded a charge of $77.9 million related to the retirement of these mechanical rigs and the write-off of excess spare components for the reduced size of the Company’s mechanical fleet. In 2013, the Company identified 48 rigs that would no longer be marketed. Also, the Company had 55 additional mechanical rigs that were not operating. Although these 55 rigs remained marketable at the time, the Company had lower expectations with respect to utilization of these rigs due to the industry shift to electric powered drilling rigs. In 2013, the Company recorded a charge of $37.8 million related to the retirement of the 48 rigs and the 55 mechanical rigs that remained marketable but were not operating. The Company also periodically evaluates its pressure pumping assets, and in 2015, the Company recorded a charge of $22.0 million for the write-down of pressure pumping equipment and certain closed facilities. There were no similar charges in 2014 or 2013. The Company evaluates the recoverability of its long-lived assets whenever events or changes in circumstances indicate that their carrying amounts may not be recoverable (a “triggering event”). During the first quarter of 2015, oil prices averaged $48.54 per barrel and reached a low of $43.39 per barrel in March 2015. Oil prices improved during the second quarter of 2015 and averaged $57.85 per barrel. Although the price improvement was earlier than the Company projected, this improvement was generally consistent with the Company’s assumption at December 31, 2014 that oil prices would improve late in 2015 and continue to improve in 2016, resulting in improved activity levels for both the contract drilling and pressure pumping businesses. During the second quarter of 2015 as oil prices increased, the Company received requests from customers to reactivate drilling rigs to resume operations in the third quarter of 2015. The Company believed this was an indication that future activity levels would be improving for both the contract drilling and pressure pumping businesses. During the third quarter of 2015, however, oil prices declined and averaged $46.42 per barrel and reached a new low for 2015 of $38.22 per barrel in August 2015. With lower oil prices in August, the Company lowered its expectations with respect to future activity levels in both the contract drilling and pressure pumping businesses. Due to the continued deterioration of crude oil prices in the fourth quarter of 2015, management deemed it necessary to again assess the recoverability of long-lived assets groups for both contract drilling and pressure pumping. The Company performed a Step 1 analysis as required by ASC 360-10-35 to assess the recoverability of long-lived assets within its contract drilling and pressure pumping segments. With respect to these assets, future cash flows were estimated over the expected remaining life of the assets, and the Company determined that, on an undiscounted basis, expected cash flows exceeded the carrying value of the long-lived assets, and no impairment was indicated. Expected cash flows, on an undiscounted basis, exceeded the carrying values of the long-lived assets within the contract drilling and pressure pumping segments by approximately 120% and 100%, respectively. For both of the assessments performed in 2015, the expected cash flows for the contract drilling segment included the backlog of commitments for contract drilling revenues under term contracts, which was approximately $801 million and $710 million at September 30, 2015 and December 31, 2015, respectively . Rigs not under term contracts will be subject to pricing in the spot market. Utilization and rates for rigs in the spot market and for the pressure pumping segment were estimated based upon the Company’s historical experience in prior downturns. Also, the expected cash flows for the contract drilling and pressure pumping segments were based on the assumption that activity levels in both segments would begin to recover in the first quarter of 2017 in response to improved oil prices. While management believes these assumptions with respect to future pricing for oil and natural gas are reasonable, actual future prices may vary significantly from the ones that were assumed. The timeframe over which oil and natural gas prices will recover is highly uncertain. Potential events that could affect the Company’s assumptions regarding future prices and the timeframe for a recovery are affected by factors such as: · · · · · · · · · All of these factors are beyond the Company’s control. If the current lower oil and natural gas commodity price environment were to last into 2017 and beyond, the Company’s actual cash flows would likely be less than the expected cash flows used in these assessments and could result in impairment charges in the future and such impairment could be material. With respect to the long-lived assets in the Company’s oil and natural gas exploration and production segment, the Company assessed the recoverability of long-lived assets each quarter due to revisions in oil and natural gas reserve estimates and expectations about future commodity prices. The Company’s analysis indicated that the carrying amounts of certain oil and natural gas properties were not recoverable at various testing dates in 2015. The Company’s estimates of expected future net cash flows from impaired properties are used in measuring the fair value of such properties. The Company recorded impairment charges of $10.7 million in 2015 related to our oil and natural gas properties.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2015
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	4. Goodwill and Intangible Assets Goodwill — Goodwill by operating segment as of December 31, 2015 and 2014 and changes for the years then ended are as follows (in thousands): Contract Pressure Drilling Pumping Total Balance December 31, 2013 $ 86,234 $ 67,575 $ 153,809 Changes to goodwill — 56,986 56,986 Balance December 31, 2014 86,234 124,561 210,795 Changes to goodwill — (124,561 ) (124,561 ) Balance December 31, 2015 $ 86,234 $ — $ 86,234 There were no accumulated impairment losses related to goodwill in the contract drilling operating segment as of December 31, 2015 or 2014. Goodwill is evaluated at least annually as of December 31, or when circumstances require, to determine if the fair value of recorded goodwill has decreased below its carrying value. For purposes of impairment testing, goodwill is evaluated at the reporting unit level. The Company’s reporting units for impairment testing have been determined to be its operating segments. The Company first determines whether it is more likely than not that the fair value of a reporting unit is less than its carrying value after considering qualitative, market and other factors, and if it is, then goodwill impairment is determined using a two-step quantitative impairment test. From time to time, the Company may perform the first step of the quantitative testing for goodwill impairment in lieu of performing the qualitative assessment. The first step of the quantitative testing is to compare the fair value of an entity’s reporting units to the respective carrying value of those reporting units. If the carrying value of a reporting unit exceeds its fair value, the second step of the quantitative testing is performed whereby the fair value of the reporting unit is allocated to its identifiable tangible and intangible assets and liabilities with any remaining fair value representing the fair value of goodwill. If this resulting fair value of goodwill is less than the carrying value of goodwill, an impairment loss would be recognized in the amount of the shortfall. During the first quarter of 2015, oil prices averaged $48.54 per barrel and reached a low of $43.39 per barrel in March 2015. Oil prices improved during the second quarter of 2015 and averaged $57.85 per barrel. Although the price improvement was earlier than the Company projected, this improvement was generally consistent with the Company’s assumption at December 31, 2014, that oil prices would improve in late 2015 and continue to improve in 2016, resulting in improved activity levels for both the contract drilling and pressure pumping businesses. During the second quarter of 2015 as oil prices increased, the Company received requests from customers to reactivate drilling rigs to resume operations in the third quarter of 2015. The Company believed this was an indication that future activity levels would be improving for both the contract drilling and pressure pumping businesses. During the third quarter of 2015, however, oil prices declined and averaged $46.42 per barrel and reached a new low for 2015 of $38.22 per barrel in August 2015. With lower oil prices in August, the Company lowered its expectations with respect to future activity levels in both the contract drilling and pressure pumping businesses. In light of the Company’s revised expectations of the duration of the lower oil and natural gas commodity price environment and the related deterioration of the markets for contract drilling and pressure pumping services during the third quarter of 2015, the Company performed a quantitative impairment assessment of its goodwill as of September 30, 2015. In completing the first step of the assessment, the fair value of each reporting unit was estimated using both the income and market valuation methods. The estimate of the fair value of each reporting unit required the use of significant unobservable inputs, representative of a Level 3 fair value measurement. The inputs included assumptions related to the future performance of the Company’s contract drilling and pressure pumping reporting units, such as future oil and natural gas prices and projected demand for the Company’s services, and assumptions related to discount rates, long-term growth rates and control premiums. Based on the results of the first step of the goodwill impairment test as of September 30, 2015, the fair value of the contract drilling reporting unit exceeded its carrying value by approximately 15%, and management concluded that no impairment was indicated in its contract drilling reporting unit; however, impairment was indicated in its pressure pumping reporting unit. In the three months ended September 30, 2015, the Company recognized an impairment charge of $125 million associated with the impairment of all of the goodwill of the pressure pumping reporting unit. The Company performed a quantitative impairment assessment of the goodwill of its contract drilling reporting unit as of December 31, 2015. In completing the first step of the assessment, the fair value of the contract drilling reporting unit was estimated using both the income and market valuation methods. The estimate of the fair value of the reporting unit required the use of significant unobservable inputs, representative of a Level 3 fair value measurement. The inputs included assumptions related to the future performance of the Company’s contract drilling reporting unit, such as future oil and natural gas prices and projected demand for the Company’s services, and assumptions related to discount rates, long-term growth rates and control premiums. Based on the results of the first step of the quantitative impairment assessment of its goodwill as of December 31, 2015, the fair value of the contract drilling reporting unit exceeded its carrying value by approximately 16%, and management concluded that no impairment was indicated in its contract drilling reporting unit. In connection with its annual goodwill impairment assessment as of December 31, 2014, the Company determined based on an assessment of qualitative factors that it was more likely than not that the fair values of the Company’s reporting units were greater than their carrying amounts and further testing was not necessary. In making this determination, the Company considered the continued demand experienced during 2014 for its services in the contract drilling and pressure pumping businesses. The Company also considered the current and expected levels of commodity prices for oil and natural gas, which influence its overall level of business activity in these operating segments. Additionally, operating results for 2014 and forecasted operating results for 2015 were also taken into account. The Company’s overall market capitalization and the large amount of calculated excess of the fair values of the Company’s reporting units over their carrying values from its 2013 quantitative impairment assessment were also considered. The Company has undertaken extensive efforts in the past several years to upgrade its fleet of equipment and believes that it is well positioned from a competitive standpoint to satisfy demand for high technology drilling of unconventional horizontal wells, which should help mitigate decreases in demand for drilling conventional vertical wells that has resulted primarily from currently low oil and natural gas prices. In the event that market conditions were to remain weak for a protracted period, the Company may be required to record an impairment of goodwill in its contract drilling reporting unit in the future, and such impairment could be material. Intangible Assets — Intangible assets were recorded in the pressure pumping operating segment in connection with the fourth quarter 2010 acquisition of the assets of a pressure pumping business. As a result of the purchase price allocation, the Company recorded intangible assets related to a non-compete agreement and the customer relationships acquired. These intangible assets were recorded at fair value on the date of acquisition. The non-compete agreement had a term of three years from October 1, 2010. The value of this agreement was estimated using a with and without scenario where cash flows were projected through the term of the agreement assuming the agreement is in place and compared to cash flows assuming the non-compete agreement was not in place. The intangible asset associated with the non-compete agreement was amortized on a straight-line basis over the three-year term of the agreement. Amortization expense of $350,000 was recorded in the year ended December 31, 2013 associated with the non-compete agreement. The non-compete agreement expired in 2013. The value of the customer relationships was estimated using a multi-period excess earnings model to determine the present value of the projected cash flows associated with the customers in place at the time of the acquisition and taking into account a contributory asset charge. The resulting intangible asset is being amortized on a straight-line basis over seven years. Amortization expense of $3.6 million was recorded in each of the years ended December 31, 2015, 2014 and 2013, associated with customer relationships. The Company concluded no triggering events necessitating an impairment assessment of the non-compete agreement had occurred in 2013. The Company concluded no triggering events necessitating an impairment assessment of the customer relationships had occurred in 2014 or 2013. The assessment of the recoverability of the pressure pumping asset group included the customer relationship intangible asset, and no impairment was indicated. The following table presents the gross carrying amount and accumulated amortization of the customer relationships as of December 31, 2015 and 2014 (in thousands): 2015 2014 Gross Carrying Accumulated Net Carrying Gross Carrying Accumulated Net Carrying Amount Amortization Amount Amount Amortization Amount Customer relationships $ 25,500 $ (19,125 ) $ 6,375 $ 25,500 $ (15,482 ) $ 10,018

Accrued Expenses

Accrued Expenses	12 Months Ended
	Dec. 31, 2015
Payables And Accruals [Abstract]
Accrued Expenses	5. Accrued Expenses Accrued expenses consisted of the following at December 31, 2015 and 2014 (in thousands): 2015 2014 Salaries, wages, payroll taxes and benefits $ 27,055 $ 52,956 Workers’ compensation liability 75,358 77,348 Property, sales, use and other taxes 9,061 11,644 Insurance, other than workers’ compensation 12,817 9,632 Accrued interest payable 7,668 7,427 Other 29,652 14,459 $ 161,611 $ 173,466

Asset Retirement Obligation

Asset Retirement Obligation	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Asset Retirement Obligation	6. Asset Retirement Obligation The Company records a liability for the estimated costs to be incurred in connection with the abandonment of oil and natural gas properties in the future. This liability is included in the caption “other” in the liabilities section of the consolidated balance sheet. The following table describes the changes to the Company’s asset retirement obligations during 2015 and 2014 (in thousands): 2015 2014 Balance at beginning of year $ 5,301 $ 4,837 Liabilities incurred 340 473 Liabilities settled (120 ) (197 ) Accretion expense 171 169 Revision in estimated costs of plugging oil and natural gas wells — 19 Asset retirement obligation at end of year $ 5,692 $ 5,301

Long Term Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Long Term Debt	7. Long-Term Debt 2012 Credit Agreement — On September 27, 2012, the Company entered into a Credit Agreement (the “Credit Agreement”) with Wells Fargo Bank, N.A., as administrative agent, letter of credit issuer, swing line lender and lender, and each of the other lenders party thereto. The Credit Agreement is a committed senior unsecured credit facility that includes a revolving credit facility and a term loan facility. The Credit Agreement replaced a previous senior unsecured revolving credit facility. The revolving credit facility permits aggregate borrowings of up to $500 million outstanding at any time. The revolving credit facility contains a letter of credit facility that is limited to $150 million and a swing line facility that is limited to $40 million, in each case outstanding at any time. The term loan facility provides for a loan of $100 million, which was drawn on December 24, 2012. The term loan facility is payable in quarterly principal installments, which commenced December 27, 2012. The installment amounts vary from 1.25% of the original principal amount for each of the first four quarterly installments, 2.50% of the original principal amount for each of the subsequent eight quarterly installments, 5.00% of the original principal amount for the subsequent four quarterly installments and 13.75% of the original principal amount for the final four quarterly installments. Subject to customary conditions, the Company may request that the lenders’ aggregate commitments with respect to the revolving credit facility and/or the term loan facility be increased by up to $100 million, not to exceed total commitments of $700 million. The maturity date under the Credit Agreement is September 27, 2017 for both the revolving facility and the term facility. Loans under the Credit Agreement bear interest by reference, at the Company’s election, to the LIBOR rate or base rate, provided, that swing line loans bear interest by reference only to the base rate. The applicable margin on LIBOR rate loans varies from 2.25% to 3.25% and the applicable margin on base rate loans varies from 1.25% to 2.25%, in each case determined based upon the Company’s debt to capitalization ratio. At December 31, 2015, the applicable margin on LIBOR rate loans was 2.25% and the applicable margin on base rate loans was 1.25%. Based on the Company’s debt to capitalization ratio at September 30, 2015, the applicable margin on LIBOR rate loans is 2.25% and the applicable margin on base rate loans is 1.25% as of January 1, 2016. Based on the Company’s debt to capitalization ratio at December 31, 2015, the applicable margin on LIBOR rate loans will be 2.75% Each domestic subsidiary of the Company will unconditionally guarantee all existing and future indebtedness and liabilities of the other guarantors and the Company arising under the Credit Agreement, other than (a) Ambar Lone Star Fluid Services LLC, (b) domestic subsidiaries that directly or indirectly have no material assets other than equity interests in, or capitalization indebtedness owed by, foreign subsidiaries, and (c) any subsidiary having total assets of less than $1 million. Such guarantees also cover obligations of the Company and any subsidiary of the Company arising under any interest rate swap contract with any person while such person is a lender or an affiliate of a lender under the Credit Agreement. The Credit Agreement requires compliance with two financial covenants. The Company must not permit its debt to capitalization ratio to exceed 45%. The Credit Agreement generally defines the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit the interest coverage ratio as of the last day of a fiscal quarter to be less than 3.00 to 1.00. The Credit Agreement generally defines the interest coverage ratio as the ratio of earnings before interest, taxes, depreciation and amortization (“EBITDA”) of the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at December 31, 2015. The Credit Agreement also contains customary representations, warranties and affirmative and negative covenants. Events of default under the Credit Agreement include failure to pay principal or interest when due, failure to comply with the financial and operational covenants, as well as a cross default event, loan document enforceability event, change of control event and bankruptcy and other insolvency events. If an event of default occurs and is continuing, then a majority of the lenders have the right, among others, to (i) terminate the commitments under the Credit Agreement, (ii) accelerate and require the Company to repay all the outstanding amounts owed under any loan document (provided that in limited circumstances with respect to insolvency and bankruptcy of the Company, such acceleration is automatic), and (iii) require the Company to cash collateralize any outstanding letters of credit. As of December 31, 2015, the Company had $70.0 million principal amount outstanding under the term loan facility at an interest rate of 2.875% and no amounts outstanding under the revolving credit facility. The Company currently has available borrowing capacity of $500 million under the revolving credit facility. 2015 Reimbursement Agreement — On March 16, 2015, the Company entered into a Reimbursement Agreement (the “Reimbursement Agreement”) with The Bank of Nova Scotia (“Scotiabank”), pursuant to which the Company may from time to time request that Scotiabank issue an unspecified amount of letters of credit. As of December 31, 2015, the Company had $41.1 million in letters of credit outstanding under the Reimbursement Agreement. Under the terms of the Reimbursement Agreement, the Company will reimburse Scotiabank on demand for any amounts that Scotiabank has disbursed under any letters of credit. Fees, charges and other reasonable expenses for the issuance of letters of credit are payable by the Company at the time of issuance at such rates and amounts as are in accordance with Scotiabank’s prevailing practice. The Company is obligated to pay to Scotiabank interest on all amounts not paid by the Company on the date of demand or when otherwise due at the LIBOR rate plus 2.25% per annum, calculated daily and payable monthly, in arrears, on the basis of a calendar year for the actual number of days elapsed, with interest on overdue interest at the same rate as on the reimbursement amounts. The Company has also agreed that if obligations under the Credit Agreement are secured by liens on any of its or any of its subsidiaries’ property, then the Company’s reimbursement obligations and (to the extent similar obligations would be secured under the Credit Agreement) other obligations under the Reimbursement Agreement and any letters of credit will be equally and ratably secured by all property subject to such liens securing the Credit Agreement. Pursuant to a Continuing Guaranty dated as of March 16, 2015, the Company’s payment obligations under the Reimbursement Agreement are jointly and severally guaranteed as to payment and not as to collection by subsidiaries of the Company that from time to time guarantee payment under the Credit Agreement. 2015 Term Loan Agreement — On March 18, 2015, the Company entered into a Term Loan Agreement (the “2015 Term Loan Agreement”) with Wells Fargo Bank, N.A., as administrative agent and lender, each of the other lenders party thereto, Wells Fargo Securities, LLC, as Lead Arranger and Sole Book Runner, and Bank of America, N.A. and The Bank Of Tokyo-Mitsubishi UFJ, LTD., as Co-Syndication Agents. The 2015 Term Loan Agreement is a senior unsecured single-advance term loan facility pursuant to which the Company made a term loan borrowing of $200 million on March 18, 2015 (the “Term Loan Borrowing”). The Term Loan Borrowing is payable in quarterly principal installments, together with accrued interest, on each June 30, September 30, December 31 and March 31, commencing on June 30, 2015. Each of the first four principal installments is in an amount equal to 2.5% of the Term Loan Borrowing and each successive quarterly installment, until and including June 30, 2017, is in an amount equal to 5.0% of the Term Loan Borrowing, with the outstanding principal balance of the Term Loan Borrowing due on the maturity date under the 2015 Term Loan Agreement. The maturity date under the 2015 Term Loan Agreement is September 27, 2017. Loans under the 2015 Term Loan Agreement bear interest, at the Company’s election, at the per annum rate of LIBOR rate plus 3.25% or base rate plus 2.25%. Each domestic subsidiary of the Company will unconditionally guarantee all existing and future indebtedness and liabilities of the other guarantors and the Company arising under the 2015 Term Loan Agreement and other Loan Documents (as defined in the 2015 Term Loan Agreement), other than (a) Ambar Lone Star Fluid Services LLC, (b) domestic subsidiaries that directly or indirectly have no material assets other than equity interests in, or capitalization indebtedness owed by, foreign subsidiaries, and (c) any subsidiary having total assets of less than $1 million. The 2015 Term Loan Agreement requires quarterly compliance with two financial covenants. The Company must not permit its debt to capitalization ratio to exceed 45%. The 2015 Term Loan Agreement generally defines the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the most recently ended fiscal quarter. The Company also must not permit the interest coverage ratio as of the last day of a fiscal quarter to be less than 3.00 to 1.00. The 2015 Term Loan Agreement generally defines the interest coverage ratio as the ratio of EBITDA of the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at December 31, 2015. The 2015 Term Loan Agreement further provides that neither the Company nor its subsidiaries is permitted to make restricted payments unless, after giving effect to such restricted payment, its pro forma ratio of debt to EBITDA for the four prior fiscal quarters, determined as of the preceding ending quarterly period, does not exceed 2.50 to 1.00. Restricted payments are generally defined as (a) dividends and distributions made on account of equity interests of the Company or its subsidiaries and (b) payments made to redeem, repurchase or otherwise retire equity interests of the Company or its subsidiaries. Payments made solely in the form of common equity interests, made to the Company and its subsidiaries, or made in connection with the Company’s long-term incentive plans are not restricted payments under the 2015 Term Loan Agreement. The 2015 Term Loan Agreement also contains customary representations, warranties, affirmative and negative covenants, and events of default. Events of default under the 2015 Term Loan Agreement include failure to pay principal or interest when due, failure to comply with the financial and operational covenants, as well as a cross default event, Loan Document enforceability event, change of control event and bankruptcy and other insolvency events. If an event of default occurs and is continuing, then a majority of the lenders have the right, among others, to accelerate and require the Company to repay all the outstanding amounts owed under any Loan Document (provided that in limited circumstances with respect to insolvency and bankruptcy of the Company, such acceleration is automatic). As of December 31, 2015, the Company had $185 million principal amount outstanding under the 2015 Term Loan Agreement at a rate of 3.875%. Senior Notes – On October 5, 2010, the Company completed the issuance and sale of $300 million in aggregate principal amount of its 4.97% Series A Senior Notes due October 5, 2020 (the “Series A Notes”) in a private placement. The Series A Notes bear interest at a rate of 4.97% per annum. The Company pays interest on the Series A Notes on April 5 and October 5 of each year. The Series A Notes will mature on October 5, 2020. On June 14, 2012, the Company completed the issuance and sale of $300 million in aggregate principal amounts of its 4.27% Series B Senior Notes due June 14, 2022 (the “Series B Notes”) in a private placement. The Series B Notes bear interest at a rate of 4.27% per annum. The Company pays interest on the Series B Notes on April 5 and October 5 of each year. The Series B Notes will mature on June 14, 2022. The Series A Notes and Series B Notes are senior unsecured obligations of the Company, which rank equally in right of payment with all other unsubordinated indebtedness of the Company. The Series A Notes and Series B Notes are guaranteed on a senior unsecured basis by each of the existing domestic subsidiaries of the Company other than subsidiaries that are not required to be guarantors under the Credit Agreement. The Series A Notes and Series B Notes are prepayable at the Company’s option, in whole or in part, provided that in the case of a partial prepayment, prepayment must be in an amount not less than 5% of the aggregate principal amount of the notes then outstanding, at any time and from time to time at 100% of the principal amount prepaid, plus accrued and unpaid interest to the prepayment date, plus a “make-whole” premium as specified in the note purchase agreements. The Company must offer to prepay the notes upon the occurrence of any change of control. In addition, the Company must offer to prepay the notes upon the occurrence of certain asset dispositions if the proceeds therefrom are not timely reinvested in productive assets. If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date. The respective note purchase agreements require compliance with two financial covenants. The Company must not permit its debt to capitalization ratio to exceed 50% at any time. The note purchase agreements generally define the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit the interest coverage ratio as of the last day of a fiscal quarter to be less than 2.50 to 1.00. The note purchase agreements generally define the interest coverage ratio as the ratio of EBITDA for the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at December 31, 2015. Events of default under the note purchase agreements include failure to pay principal or interest when due, failure to comply with the financial and operational covenants, a cross default event, a judgment in excess of a threshold event, the guaranty agreement ceasing to be enforceable, the occurrence of certain ERISA events, a change of control event and bankruptcy and other insolvency events. If an event of default under the note purchase agreements occurs and is continuing, then holders of a majority in principal amount of the respective notes have the right to declare all the notes then-outstanding to be immediately due and payable. In addition, if the Company defaults in payments on any note, then until such defaults are cured, the holder thereof may declare all the notes held by it pursuant to the note purchase agreement to be immediately due and payable. The Company incurred approximately $10.8 million in debt issuance costs during 2010 in connection with the Series A Notes and a previous senior unsecured revolving credit facility. The Company incurred approximately $7.6 million in debt issuance costs during 2012 in connection with the Series B Notes and the Credit Agreement. The Company incurred approximately $2.0 million in debt issuance costs during 2015 in connection with the Reimbursement Agreement and the 2015 Term Loan Agreement. Presented below is a schedule of the principal repayment requirements of long-term debt by fiscal year as of December 31, 2015 (in thousands): Year ending December 31, 2016 $ 63,750 2017 191,250 2018 — 2019 — 2020 300,000 Thereafter 300,000 Total $ 855,000

Commitments, Contingencies and

Commitments, Contingencies and Other Matters	12 Months Ended
	Dec. 31, 2015
Commitments And Contingencies Disclosure [Abstract]
Commitments, Contingencies and Other Matters	8. Commitments, Contingencies and Other Matters Commitments – As of December 31, 2015, the Company maintained letters of credit in the aggregate amount of $41.1 million for the benefit of various insurance companies as collateral for retrospective premiums and retained losses which could become payable under the terms of the underlying insurance contracts. These letters of credit expire annually at various times during the year and are typically renewed. As of December 31, 2015, no amounts had been drawn under the letters of credit. As of December 31, 2015, the Company had commitments to purchase approximately $73.5 million of major equipment for its drilling and pressure pumping businesses. The Company’s pressure pumping business has entered into agreements to purchase minimum quantities of proppants and chemicals from certain vendors. These agreements expire in 2016, 2017 and 2018. As of December 31, 2015, the remaining obligation under these agreements was approximately $26.5 million, of which materials with a total purchase price of approximately $9.5 million are required to be purchased during 2016. In the event that the required minimum quantities are not purchased during any contract year, the Company could be required to make a liquidated damages payment to the respective vendor for any shortfall. In November 2011, the Company’s pressure pumping business entered into an agreement with a proppant vendor to advance up to $12.0 million to such vendor to finance the construction of certain processing facilities. This advance is secured by the underlying processing facilities and bears interest at an annual rate of 5.0%. Repayment of the advance is to be made through discounts applied to purchases from the vendor and repayment of all amounts advanced must be made no later than October 1, 2017. As of December 31, 2015, advances of approximately $11.8 million had been made under this agreement and repayments of approximately $10.6 million had been received resulting in a balance outstanding of approximately $1.2 million. Contingencies – A $12.3 million charge related to the previously disclosed settlement of a lawsuit filed by the U.S. Equal Employment Opportunity Commission against the Company’s U.S. contract drilling subsidiary was recorded in 2015. The Company’s operations are subject to many hazards inherent in the contract drilling and pressure pumping businesses, including inclement weather, blowouts, well fires, loss of well control, pollution, exposure and reservoir damage. These hazards could cause personal injury or death, work stoppage, and serious damage to equipment and other property, as well as significant environmental and reservoir damages. These risks could expose the Company to substantial liability for personal injury, wrongful death, property damage, loss of oil and natural gas production, pollution and other environmental damages. Any contractual right to indemnification that the Company may have for any such risk, may be unenforceable or limited due to negligent or willful acts of commission or omission by the Company, its subcontractors and/or suppliers. The Company’s customers and other third parties may dispute, or be unable to meet, their contractual indemnification obligations to the Company due to financial, legal or other reasons. Accordingly, the Company may be unable to transfer these risks to its customers and other third parties by contract or indemnification agreements. Incurring a liability for which the Company is not fully indemnified or insured could have a material adverse effect on its business, financial condition, cash flows and results of operations. The Company has insurance coverage for fire, windstorm and other risks of physical loss to its rigs and certain other assets, employer’s liability, automobile liability, commercial general liability, workers’ compensation and insurance for other specific risks. The Company has also elected in some cases to accept a greater amount of risk through increased deductibles on certain insurance policies. For example, the Company generally maintains a $1.5 million per occurrence deductible on its workers’ compensation insurance coverage, a $1.0 million per occurrence deductible on its equipment insurance coverage, a $2.0 million per occurrence self-insured retention on its general liability coverage and a $2.0 million per occurrence deductible on its automobile liability insurance coverage. The Company self-insures a number of other risks, including loss of earnings and business interruption, and does not carry a significant amount of insurance to cover risks of underground reservoir damage. If a significant accident or other event occurs that is not fully covered by insurance or an enforceable and recoverable indemnity from a third party, it could have a material adverse effect on the Company’s business, financial condition, cash flows and results of operations. Accrued expenses related to insurance claims are set forth in Note 5. The Company is party to various legal proceedings arising in the normal course of its business. The Company does not believe that the outcome of these proceedings, either individually or in the aggregate, will have a material adverse effect on its financial condition, results of operations or cash flows. Other Matters — The Company has Change in Control Agreements with its Chairman of the Board, Chief Executive Officer, two Senior Vice Presidents and its General Counsel (the “Key Employees”). Each Change in Control Agreement generally has an initial term with automatic twelve-month renewals unless the Company notifies the Key Employee at least ninety days before the end of such renewal period that the term will not be extended. If a change in control of the Company occurs during the term of the agreement and the Key Employee’s employment is terminated (i) by the Company other than for cause or other than automatically as a result of death, disability or retirement, or (ii) by the Key Employee for good reason (as those terms are defined in the Change in Control Agreements), then the Key Employee shall generally be entitled to, among other things: — a bonus payment equal to the highest bonus paid after the Change in Control Agreement was entered into (such bonus payment for each Key Employee prorated for the portion of the fiscal year preceding the termination date); — a payment equal to 2.5 times (in the case of the Chairman of the Board and Chief Executive Officer), 2 times (in the case of the Senior Vice Presidents) or 1.5 times (in the case of the General Counsel) of the sum of (i) the highest annual salary in effect for such Key Employee and (ii) the average of the three annual bonuses earned by the Key Employee for the three fiscal years preceding the termination date and — continued coverage under the Company’s welfare plans for up to three years (in the case of the Chairman of the Board and Chief Executive Officer) or two years (in the case of the Senior Vice Presidents and General Counsel). Other than with respect to the Chief Executive Officer, each Change in Control Agreement provides the Key Employee with a full gross-up payment for any excise taxes imposed on payments and benefits received under the Change in Control Agreements or otherwise, including other taxes that may be imposed as a result of the gross-up payment.

Stockholders' Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Stockholders' Equity	9. Stockholders’ Equity Cash Dividends – The Company paid cash dividends during the years ended December 31, 2013, 2014 and 2015 as follows: Per Share Total (in thousands) 2013: Paid on March 29, 2013 $ 0.05 $ 7,312 Paid on June 28, 2013 0.05 7,361 Paid on September 30, 2013 0.05 7,231 Paid on December 31, 2013 0.05 7,208 Total cash dividends $ 0.20 $ 29,112 2014: Paid on March 27, 2014 $ 0.10 $ 14,456 Paid on June 26, 2014 0.10 14,562 Paid on September 24, 2014 0.10 14,634 Paid on December 24, 2014 0.10 14,636 Total cash dividends $ 0.40 $ 58,288 2015: Paid on March 25, 2015 $ 0.10 $ 14,640 Paid on June 24, 2015 0.10 14,712 Paid on September 24, 2015 0.10 14,712 Paid on December 24, 2015 0.10 14,711 Total cash dividends $ 0.40 $ 58,775 On February 3, 2016, the Company’s Board of Directors approved a cash dividend on its common stock in the amount of $0.10 per share to be paid on March 24, 2016 to holders of record as of March 10, 2016. The Company’s 2015 Term Loan Agreement contains a covenant that could restrict its ability to make dividend payments later in 2016. The amount and timing of all future dividend payments, if any, are subject to the discretion of the Board of Directors and will depend upon business conditions, results of operations, financial condition, terms of the Company’s debt agreements and other factors. On July 25, 2012, the Company’s Board of Directors approved a stock buyback program authorizing purchases of up to $150 million of common stock in open market or privately negotiated transactions. On September 6, 2013, the Company’s Board of Directors terminated any remaining authority under the 2012 stock buyback program, and approved a new stock buyback program that authorizes purchase of up to $200 million of the Company’s common stock in open market or privately negotiated transactions. As of December 31, 2015, the Company had remaining authorization to purchase approximately $187 million of the Company’s outstanding common stock under the 2013 stock buyback program. Shares purchased under a buyback program are accounted for as treasury stock. The Company acquired shares of stock from employees during 2015, 2014 and 2013 that are accounted for as treasury stock. Certain of these shares were acquired to satisfy the exercise price in connection with the exercise of stock options by employees. The remainder of these shares was acquired to satisfy payroll tax withholding obligations upon the exercise of stock options, the settlement of performance unit awards and the vesting of restricted stock. These shares were acquired at fair market value. These acquisitions were made pursuant to the terms of the Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan (the “2005 Plan”) or the Patterson-UTI Energy, Inc. 2014 Long-Term Incentive Plan (the “2014 Plan”) and not pursuant to the stock buyback programs. Treasury stock acquisitions during the years ended December 31, 2015, 2014 and 2013 were as follows (dollars in thousands): 2015 2014 2013 Shares Cost Shares Cost Shares Cost Treasury shares at beginning of period 42,818,585 $ 899,035 42,268,057 $ 880,888 38,146,738 $ 795,051 Purchases pursuant to stock buyback programs: 2012 program — — — — 2,567,266 51,107 2013 program 8,618 180 13,898 466 602,564 12,517 Acquisitions pursuant to long-term incentive plans 380,037 7,830 536,630 17,681 951,489 22,213 Treasury shares at end of period 43,207,240 $ 907,045 42,818,585 $ 899,035 42,268,057 $ 880,888

Stock-based Compensation

Stock-based Compensation	12 Months Ended
	Dec. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Stock-based Compensation	10. Stock-based Compensation The Company uses share-based payments to compensate employees and non-employee directors. The Company recognizes the cost of share-based payments under the fair-value-based method. Share-based awards consist of equity instruments in the form of stock options, restricted stock or restricted stock units and have included service and, in certain cases, performance conditions. The Company issues shares of common stock when vested stock options are exercised, when restricted stock is granted and when restricted stock units and share-settled performance unit awards vest. The Company’s shareholders have approved the 2014 Plan, and the Board of Directors adopted a resolution that no future grants would be made under any of the Company’s other previously existing plans. The Company’s share-based compensation plans at December 31, 2015 follow: Shares Shares Underlying Shares Authorized Awards Available Plan Name for Grant Outstanding for Grant Patterson-UTI Energy, Inc. 2014 Long-Term Incentive Plan 9,100,000 2,509,623 4,018,824 Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended — 5,271,563 — A summary of the 2014 Plan follows: · The Compensation Committee of the Board of Directors administers the plan other than the awards to directors. · All employees, officers and directors are eligible for awards. · The Compensation Committee determines the vesting schedule for awards. Awards typically vest over one year for non-employee directors and three years for employees. · The Compensation Committee sets the term of awards and no option term can exceed 10 years. · All options granted under the plan are granted with an exercise price equal to or greater than the fair market value of the Company’s common stock at the time the option is granted. · The plan provides for awards of incentive stock options, non-incentive stock options, tandem and freestanding stock appreciation rights, restricted stock awards, other stock unit awards, performance share awards, performance unit awards and dividend equivalents. As of December 31, 2015, non-incentive stock options, restricted stock awards, restricted stock units and performance unit awards had been granted under the plan. Options granted under the 2005 Plan typically vested over one year for non-employee directors and three years for employees. All options were granted with an exercise price equal to the fair market value of the related common stock at the time of grant. Restricted stock awards granted under the 2005 Plan typically vested over one year for non-employee directors and three years for employees. Stock Options— The Company estimates the grant date fair values of stock options using the Black-Scholes-Merton valuation model. Volatility assumptions are based on the historic volatility of the Company’s common stock over the most recent period equal to the expected term of the options as of the date the options are granted. The expected term assumptions are based on the Company’s experience with respect to employee stock option activity. Dividend yield assumptions are based on the expected dividends at the time the options are granted. The risk-free interest rate assumptions are determined by reference to United States Treasury yields. Weighted-average assumptions used to estimate grant date fair values for stock options granted in the years ended December 31, 2015, 2014 and 2013 follow: 2015 2014 2013 Volatility 37.95 % 35.89 % 41.36 % Expected term (in years) 5.00 5.00 5.00 Dividend yield 2.00 % 1.17 % 0.89 % Risk-free interest rate 1.37 % 1.76 % 0.70 % Stock option activity for the year ended December 31, 2015 follows: Weighted-average Shares exercise price Outstanding at beginning of year 6,086,250 $ 22.32 Granted 831,000 $ 20.06 Exercised — — Cancelled (10,000 ) $ 16.59 Expired (600,000 ) $ 26.06 Outstanding at end of year 6,307,250 $ 21.68 Exercisable at end of year 5,224,082 $ 21.49 Options outstanding at December 31, 2015 have an aggregate intrinsic value of approximately $1.7 million and a weighted-average remaining contractual term of 4.99 years. Options exercisable at December 31, 2015 have an aggregate intrinsic value of approximately $1.7 million and a weighted-average remaining contractual term of 4.16 years. Additional information with respect to options granted, vested and exercised during the years ended December 31, 2015, 2014 and 2013 follows: 2015 2014 2013 Weighted-average grant date fair value of stock options granted (per share) $ 5.79 $ 9.81 $ 7.59 Aggregate grant date fair value of stock options vested during the year (in thousands) $ 5,077 $ 5,173 $ 5,240 Aggregate intrinsic value of stock options exercised (in thousands) $ — $ 21,862 $ 8,683 As of December 31, 2015, options to purchase 1.1 million shares were outstanding and not vested. All of these non-vested options are expected to ultimately vest. Additional information as of December 31, 2015 with respect to these non-vested options follows: Aggregate intrinsic value (in thousands) $ — Weighted-average remaining contractual term 8.99 years Weighted-average remaining expected term 3.99 years Weighted-average remaining vesting period 1.89 years Unrecognized compensation cost $5.8 million Restricted Stock— For all restricted stock awards to date, shares of common stock were issued when the awards were made. Non-vested shares are subject to forfeiture for failure to fulfill service conditions and, in certain cases, performance conditions. Non-forfeitable dividends are paid on non-vested shares of restricted stock. The Company uses the straight-line method to recognize periodic compensation cost over the vesting period. Restricted stock activity for the year ended December 31, 2015 follows: Weighted- average Grant Shares Date Fair Value Non-vested restricted stock outstanding at beginning of year 1,493,059 $ 26.93 Granted 795,600 $ 20.58 Vested (774,235 ) $ 24.89 Forfeited (82,174 ) $ 25.89 Non-vested restricted stock outstanding at end of year 1,432,250 $ 24.56 As of December 31, 2015, approximately 1.3 million shares of non-vested restricted stock outstanding are expected to vest. Additional information as of December 31, 2015 with respect to these non-vested shares follows: Aggregate intrinsic value $19.9 million Weighted-average remaining vesting period 1.8 years Unrecognized compensation cost $25.1 million Restricted Stock Units— For all restricted stock unit awards made to date, shares of common stock are not issued until the units vest. Restricted stock units are subject to forfeiture for failure to fulfill service conditions. Non-forfeitable cash dividend equivalents are paid on certain non-vested restricted stock units. The Company uses the straight-line method to recognize periodic compensation cost over the vesting period. Restricted stock unit activity for the year ended December 31, 2015 follows: Weighted-average Grant Date Fair Shares Value Non-vested restricted stock units outstanding at beginning of year 34,085 $ 30.20 Granted 22,100 $ 20.85 Vested (14,499 ) $ 27.37 Forfeited — $ — Non-vested restricted stock units outstanding at end of year 41,686 $ 26.22 Performance Unit Awards. Each year, beginning in 2010, the Company granted stock-settled performance unit awards to certain executive officers (the “Stock-Settled Performance Units”). The Stock-Settled Performance Units provide for the recipients to receive a grant of shares of stock upon the achievement of certain performance goals established by the Compensation Committee during a specified period. The performance period for the Stock-Settled Performance Units is the three year period commencing on April 1 of the year of grant. For the 2012 and 2013 Stock-Settled Performance Units, the performance period can extend for an additional two years in certain circumstances. The performance goals for the Stock-Settled Performance Units are tied to the Company’s total shareholder return for the performance period as compared to total shareholder return for a peer group determined by the Compensation Committee. These goals are considered to be market conditions under the relevant accounting standards and the market conditions were factored into the determination of the fair value of the respective performance units. Generally, the recipients will receive a target number of shares if the Company’s total shareholder return is positive and, when compared to the peer group, is at the 50 th percentile and two times the target if at the 75 th percentile or higher. If the Company’s total shareholder return is positive, and, when compared to the peer group, is at the 25 th percentile, the recipients will only receive one-half of the target number of shares. The grant of shares when achievement is between the 25 th and 75 th percentile will be determined on a pro-rata basis. There is no payout unless the Company’s total shareholder return is positive and, when compared to the peer group, is at or above the 25 th percentile. The total target number of shares with respect to the Stock-Settled Performance Units is set forth below: 2015 2014 2013 2012 2011 2010 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Target number of shares 190,600 154,000 236,500 192,000 144,375 178,750 For the stock-settled Performance Units that have been settled, following are the total shareholder return percentiles and the number of shares issued: 2012 2011 2010 Performance Performance Performance Unit Awards Unit Awards Unit Awards Total shareholder return percentile for performance period 87 th 94 th 93 rd Shares issued 384,000 288,750 357,500 Because the Stock-Settled Performance Units are stock-settled awards, they are accounted for as equity awards and measured at fair value on the date of grant using a Monte Carlo simulation model. The fair value of the Stock-Settled Performance Units is set forth below (in thousands): 2015 2014 2013 2012 2011 2010 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Aggregate fair value at date of grant $ 4,052 $ 5,388 $ 5,564 $ 3,065 $ 5,569 $ 3,117 These fair value amounts are charged to expense on a straight-line basis over the performance period. Compensation expense associated with the Stock-Settled Performance Units is set forth below (in thousands): 2015 2014 2013 2012 2011 2010 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Year ended December 31, 2015 $ 1,013 $ 1,796 $ 1,855 $ 255 NA NA Year ended December 31, 2014 NA $ 1,347 $ 1,855 $ 1,022 $ 464 NA Year ended December 31, 2013 NA NA $ 1,391 $ 1,022 $ 1,856 $ 260 Dividends on Equity Awards – Non-forfeitable cash dividends are paid on restricted stock awards and dividend equivalents are paid on certain restricted stock units. These payments are recognized as follows: · Dividends are recognized as reductions of retained earnings for the portion of restricted stock awards expected to vest. · Dividends are recognized as additional compensation cost for the portion of restricted stock awards that are not expected to vest or that ultimately do not vest. · Dividend equivalents are recognized as additional compensation cost for restricted stock units.

Leases

Leases	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Leases	11. Leases The Company incurred rent expense of $37.6 million, $51.9 million and $47.4 million for the years ended December 31, 2015, 2014 and 2013, respectively. Rent expense is primarily related to short-term equipment rentals that are generally passed through to customers. Future minimum rental payments required under operating leases having initial or remaining non-cancelable lease terms in excess of one year at December 31, 2015 are as follows: Year ending December 31, 2016 $ 10,522 2017 4,969 2018 4,053 2019 3,229 2020 2,734 Thereafter 4,655 Total $ 30,162

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Income Taxes	12. Income Taxes Components of the income tax provision applicable to federal, state and foreign income taxes for the years ended December 31, 2015, 2014 and 2013 are as follows (in thousands): 2015 2014 2013 Federal income tax expense (benefit): Current $ (42,020 ) $ 39,438 $ 41,558 Deferred (83,812 ) 39,673 47,136 (125,832 ) 79,111 88,694 State income tax expense (benefit): Current (3,480 ) 3,987 11,733 Deferred (12,433 ) 5,292 4,229 (15,913 ) 9,279 15,962 Foreign income tax expense (benefit): Current (2,590 ) 4,521 4,572 Deferred (3,628 ) (1,292 ) (796 ) (6,218 ) 3,229 3,776 Total income tax expense (benefit): Current (48,090 ) 47,946 57,863 Deferred (99,873 ) 43,673 50,569 Total income tax expense (benefit): $ (147,963 ) $ 91,619 $ 108,432 The difference between the statutory federal income tax rate and the effective income tax rate for the years ended December 31, 2015, 2014 and 2013 is summarized as follows: 2015 2014 2013 Statutory tax rate 35.0 % 35.0 % 35.0 % State income taxes 2.1 2.5 3.7 Permanent differences (1.3 ) (1.4 ) (1.5 ) Other differences, net (2.4 ) (0.1 ) (0.6 ) Effective tax rate 33.4 % 36.0 % 36.6 % The Domestic Production Activities Deduction (IRC section 199 deduction) was enacted as part of the American Jobs Creation Act of 2004 (as revised by the Emergency Economic Stabilization Act of 2008) and allows a deduction of 9% in 2010 and thereafter on the lesser of qualified production activities income or taxable income. The permanent differences for 2013 include a deduction of $10.0 million as the Company fully utilized its remaining net operating loss carryforwards. The permanent differences for 2014 include a deduction of $8.8 million. The permanent differences for 2015 do not include any deduction as it is limited to taxable income, and the Company did not have taxable income in 2015 as a result of the Company’s election to utilize bonus depreciation. The 2015 other differences include a 1% reduction related to the reconciliation of the deferred tax liability associated with the conversion of the Company’s Canadian operations to a controlled foreign corporation. The impact to the deferred tax liability from the conversion is being amortized over the weighted average remaining useful life of the Canadian assets. The 2015 other differences also include a 0.7% reduction for the lost benefit of the 2014 IRC section 199 deduction of $8.8 million as a result of the Company’s adoption of the final tangible property regulations with the filing of the 2014 tax return. The tax effect of significant temporary differences representing deferred tax assets and liabilities and changes therein were as follows (in thousands): December 31, Net December 31, Net December Net December 2015 Change 2014 Change 2013 Change 2012 Deferred tax assets: Current: Net operating loss carryforwards $ 27,887 $ 27,887 $ — $ — $ — $ (18,914 ) $ 18,914 Workers’ compensation allowance 28,734 424 28,310 698 27,612 2,534 25,078 Other 21,305 (1,091 ) 22,396 2,749 19,647 (804 ) 20,451 77,926 27,220 50,706 3,447 47,259 (17,184 ) 64,443 Non-current: Net operating loss carryforwards 77,514 65,050 12,464 (988 ) 13,452 1,690 11,762 Expense associated with employee stock options 14,591 205 14,386 (1,822 ) 16,208 1,536 14,672 Federal benefit of state deferred tax liabilities 24,485 466 24,019 1,181 22,838 816 22,022 Other 20,441 4,394 16,047 1,344 14,703 (421 ) 15,124 137,031 70,115 66,916 (285 ) 67,201 3,621 63,580 Less: Allowance to reduce deferred tax asset to expected realizable value (603 ) (603 ) — — — — — Total deferred tax assets 214,354 96,732 117,622 3,162 114,460 (13,563 ) 128,023 Deferred tax liabilities: Current: Other (12,805 ) 826 (13,631 ) 676 (14,307 ) (2,823 ) (11,484 ) Non-current: Property and equipment basis difference (986,922 ) 31 (986,953 ) (47,359 ) (939,594 ) (33,997 ) (905,597 ) Other (13,339 ) 2,284 (15,623 ) (152 ) (15,471 ) (186 ) (15,285 ) (1,000,261 ) 2,315 (1,002,576 ) (47,511 ) (955,065 ) (34,183 ) (920,882 ) Total deferred tax liabilities (1,013,066 ) 3,141 (1,016,207 ) (46,835 ) (969,372 ) (37,006 ) (932,366 ) Net deferred tax liability $ (798,712 ) $ 99,873 $ (898,585 ) $ (43,673 ) $ (854,912 ) $ (50,569 ) $ (804,343 ) In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized, and necessary allowances are provided. The ultimate realization of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. Management considers the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment. The Company expects the carrying value of the deferred tax assets at December 31, 2015 and 2014 to be realized as a result of the reversal of existing taxable temporary differences giving rise to deferred tax liabilities and the generation of taxable income. The valuation allowance of $603,000 is related to state net operating losses being carried forward that will expire in 2016. Other deferred tax assets consist primarily of the tax effect of various allowance accounts and tax-deferred expenses expected to generate future tax benefits of approximately $41.7 million. Other deferred tax liabilities consist primarily of the tax effect of receivables from insurance companies and tax-deferred income not yet recognized for tax purposes. For income tax purposes, the Company has approximately $257 million of federal net operating losses and approximately $237 million, net of valuation allowance, of state net operating losses as of December 31, 2015. Of these amounts, approximately $111 million will be carried back to prior years and the remaining balance can be carried forward to future years. Net operating losses that can be carried forward, if unused, are scheduled to expire as follows: 2025—$2.8 million; 2026—$17.1 million; 2027—$75,000; 2029—$33.2 million; 2030—$27.5 million; 2031—$88.0 million; 2034—$2,000; 2035—$213.9 million. As of December 31, 2015, the Company had no unrecognized tax benefits. The Company has established a policy to account for interest and penalties related to uncertain income tax positions as operating expenses. As of December 31, 2015, the tax years ended December 31, 2012 through December 31, 2014 are open for examination by U.S. taxing authorities. As of December 31, 2015, the tax years ended December 31, 2011 through December 31, 2014 are open for examination by Canadian taxing authorities. On January 1, 2010, the Company converted its Canadian operations from a Canadian branch to a controlled foreign corporation for federal income tax purposes. This transaction triggered a $1.0 million increase in deferred tax liabilities, which is being amortized as an increase to deferred income tax expense over the weighted average remaining useful life of the Canadian assets. This will be fully amortized by December 31, 2016. As a result of the above conversion, the Company’s Canadian assets are no longer directly subject to United States taxation, provided that the related unremitted earnings are permanently reinvested in Canada. Effective January 1, 2010, the Company has elected to permanently reinvest these unremitted earnings in Canada, and intends to do so for the foreseeable future. As a result, no deferred United States federal or state income taxes have been provided on such unremitted foreign earnings, which totaled approximately $28.4 million as of December 31, 2015. The unrecognized deferred tax liability associated with these earnings was approximately $3.8 million, net of available foreign tax credits. This liability would be recognized if the Company received a dividend of the unremitted earnings.

Employee Benefits

Employee Benefits	12 Months Ended
	Dec. 31, 2015
Compensation And Retirement Disclosure [Abstract]
Employee Benefits	13. Employee Benefits The Company maintains a 401(k) plan for all eligible employees. The Company’s operating results include expenses of approximately $7.1 million in 2015, $7.2 million in 2014 and $6.2 million in 2013 for the Company’s contributions to the plan.

Business Segments

Business Segments	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Business Segments	14. Business Segments The Company’s revenues, operating profits and identifiable assets are primarily attributable to three business segments: (i) contract drilling of oil and natural gas wells, (ii) pressure pumping services and (iii) the investment, on a non-operating working interest basis, in oil and natural gas properties. Each of these segments represents a distinct type of business. These segments have separate management teams which report to the Company’s chief operating decision maker. The results of operations in these segments are regularly reviewed by the chief operating decision maker for purposes of determining resource allocation and assessing performance. Contract Drilling — The Company markets its contract drilling services to major and independent oil and natural gas operators. As of December 31, 2015, the Company had 221 land-based drilling rigs in the continental United States and western Canada. For the years ended December 31, 2015, 2014 and, 2013, contract drilling revenue earned in Canada was $37.5 million, $87.5 million and $86.6 million, respectively. Additionally, long-lived assets within the contract drilling segment located in Canada totaled $53.4 million and $57.6 million as of December 31, 2015 and 2014, respectively. Pressure Pumping — The Company provides pressure pumping services to oil and natural gas operators primarily in Texas and the Appalachian region. Pressure pumping services are primarily well stimulation services (such as hydraulic fracturing) and cementing services for the completion of new wells and remedial work on existing wells. Well stimulation involves processes inside a well designed to enhance the flow of oil, natural gas, or other desired substances from the well. Cementing is the process of inserting material between the hole and the pipe to center and stabilize the pipe in the hole. Oil and Natural Gas — The Company owns and invests in oil and natural gas assets as a non-operating working interest owner. The Company’s oil and natural gas interests are located primarily in Texas and New Mexico. Major Customer — During 2015, one customer accounted for approximately $244 million or 13% of the Company’s consolidated operating revenues. These revenues were earned in both the Company’s contract drilling and pressure pumping businesses. During 2014, no single customer accounted for more than 10% of consolidated operating revenue. During 2013, one customer accounted for approximately $286 million or 10.5% of the Company’s consolidated operating revenues. These revenues were earned in both the Company’s contract drilling and pressure pumping businesses. The following tables summarize selected financial information relating to the Company’s business segments (in thousands): Years Ended December 31, 2015 2014 2013 Revenues: Contract drilling $ 1,155,565 $ 1,843,707 $ 1,684,878 Pressure pumping 712,454 1,294,569 979,166 Oil and natural gas 24,931 50,196 57,257 Total segment revenues 1,892,950 3,188,472 2,721,301 Elimination of intercompany revenues(a) (1,673 ) (6,181 ) (5,267 ) Total revenues $ 1,891,277 $ 3,182,291 $ 2,716,034 Income (loss) before income taxes: Contract drilling $ (91,230 ) $ 241,851 $ 266,262 Pressure pumping (254,998 ) 89,081 87,244 Oil and natural gas (12,870 ) (5,482 ) 19,948 (359,098 ) 325,450 373,454 Corporate and other (58,487 ) (58,105 ) (54,647 ) Net gain on asset disposals(b) 10,613 15,781 3,384 Interest income 964 979 918 Interest expense (36,475 ) (29,825 ) (28,359 ) Other 34 3 1,691 Income (loss) before income taxes $ (442,449 ) $ 254,283 $ 296,441 Identifiable assets: Contract drilling $ 3,457,044 $ 4,000,576 $ 3,569,588 Pressure pumping 813,704 1,186,010 761,199 Oil and natural gas 34,073 50,945 58,656 Corporate and other(c) 228,496 156,480 297,684 Total assets $ 4,533,317 $ 5,394,011 $ 4,687,127 Depreciation, depletion, amortization and impairment: Contract drilling $ 618,434 $ 524,023 $ 438,728 Pressure pumping 214,552 147,595 129,984 Oil and natural gas 26,301 42,576 24,400 Corporate and other 5,472 4,536 4,357 Total depreciation, depletion, amortization and impairment $ 864,759 $ 718,730 $ 597,469 Capital expenditures: Contract drilling $ 527,054 $ 771,593 $ 504,508 Pressure pumping 197,577 241,359 122,782 Oil and natural gas 16,625 36,683 31,245 Corporate and other 2,520 2,706 3,926 Total capital expenditures $ 743,776 $ 1,052,341 $ 662,461 (a) Consists of contract drilling and, in 2014, pressure pumping intercompany revenues for services provided to the oil and natural gas exploration and production segment. (b) Net gains or losses associated with the disposal of assets relate to corporate strategy decisions of the executive management group. Accordingly, the related gains or losses have been separately presented and excluded from the results of specific segments. (c) Corporate and other assets primarily include cash on hand, income tax receivables and certain deferred tax assets.

Concentrations of Credit Risk

Concentrations of Credit Risk	12 Months Ended
	Dec. 31, 2015
Risks And Uncertainties [Abstract]
Concentrations of Credit Risk	15. Concentrations of Credit Risk Financial instruments which potentially subject the Company to concentrations of credit risk consist primarily of demand deposits, temporary cash investments and trade receivables. The Company believes it has placed its demand deposits and temporary cash investments with high credit-quality financial institutions. At December 31, 2015 and 2014, the Company’s demand deposits and temporary cash investments consisted of the following (in thousands): 2015 2014 Deposits in FDIC and SIPC-insured institutions under insurance limits $ 617 $ 636 Deposits in FDIC and SIPC-insured institutions over insurance limits 130,330 1,420 Deposits in foreign banks 15,303 43,664 146,250 45,720 Less outstanding checks and other reconciling items (32,904 ) (2,708 ) Cash and cash equivalents $ 113,346 $ 43,012 Concentrations of credit risk with respect to trade receivables are primarily focused on companies involved in the exploration and development of oil and natural gas properties. The concentration is somewhat mitigated by the diversification of customers for which the Company provides services. As is general industry practice, the Company typically does not require customers to provide collateral. No significant losses from individual customers were experienced during the years ended December 31, 2015, 2014 or 2013. No provision for bad debts was recognized in 2015, 2014 or 2013.

Fair Values of Financial Instru

Fair Values of Financial Instruments	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Fair Values of Financial Instruments	16. Fair Values of Financial Instruments The carrying values of cash and cash equivalents, trade receivables and accounts payable approximate fair value due to the short-term maturity of these items. These fair value estimates are considered Level 1 fair value estimates in the fair value hierarchy of fair value accounting. The estimated fair value of the Company’s outstanding debt balances (including current portion) as of December 31, 2015 and 2014 is set forth below (in thousands): December 31, 2015 December 31, 2014 Carrying Fair Carrying Fair Value Value Value Value Borrowings under Credit Agreement: Revolving credit facility $ — $ — $ 303,000 $ 303,000 Term loan facility 70,000 70,000 82,500 82,500 2015 Term Loan 185,000 185,000 — — 4.97% Series A Senior Notes 300,000 279,635 300,000 288,346 4.27% Series B Senior Notes 300,000 258,806 300,000 269,173 Total debt $ 855,000 $ 793,441 $ 985,500 $ 943,019 The carrying values of the balances outstanding under the revolving credit facility, the term loan facility, and the 2015 Term Loan approximate their fair values as these instruments have floating interest rates. The fair values of the Series A Notes and Series B Notes at December 31, 2015 and 2014 are based on discounted cash flows associated with the respective notes using current market rates of interest at those respective dates. For the Series A Notes, the current market rates used in measuring this fair value were 6.66% at December 31, 2015 and 5.77% at December 31, 2014. For the Series B Notes, the current market rates used in measuring this fair value were 6.95% at December 31, 2015 and 6.00% at December 31, 2014. These fair value estimates are based on observable market inputs and are considered Level 2 fair value estimates in the fair value hierarchy of fair value accounting.

Quarterly Financial Information

Quarterly Financial Information	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information	17. Quarterly Financial Information (in thousands, except per share amounts) (unaudited) 1 st 2 nd 3 rd 4 th Quarter Quarter Quarter Quarter 2014 Operating revenues $ 678,168 $ 757,276 $ 845,628 $ 901,219 Operating income 58,776 87,226 30,291 106,833 Net income 34,822 54,283 15,976 57,583 Net income per common share: Basic $ 0.24 $ 0.37 $ 0.11 $ 0.39 Diluted $ 0.24 $ 0.37 $ 0.11 $ 0.39 2015 Operating revenues $ 657,699 $ 472,761 $ 422,251 $ 338,566 Operating income (loss) 24,103 (24,764 ) (329,515 ) (76,796 ) Net income (loss) 9,125 (18,975 ) (225,978 ) (58,658 ) Net income (loss) per common share: Basic $ 0.06 $ (0.13 ) $ (1.54 ) $ (0.40 ) Diluted $ 0.06 $ (0.13 ) $ (1.54 ) $ (0.40 )

Valuation And Qualifying Accoun

Valuation And Qualifying Accounts	12 Months Ended
	Dec. 31, 2015
Valuation And Qualifying Accounts [Abstract]
Valuation And Qualifying Accounts	SCHEDULE II — VALUATION AND QUALIFYING ACCOUNTS Charged to Beginning Costs and Ending Description Balance Expenses Deductions(1) Balance (In thousands) Year Ended December 31, 2015 Deducted from asset accounts: Allowance for doubtful accounts $ 3,546 $ — $ (1 ) $ 3,545 Year Ended December 31, 2014 Deducted from asset accounts: Allowance for doubtful accounts $ 3,674 $ — $ (128 ) $ 3,546 Year Ended December 31, 2013 Deducted from asset accounts: Allowance for doubtful accounts $ 3,513 $ — $ 161 $ 3,674 (1) Consists of uncollectible accounts (written off) or recovered.

Description of Business and S28

Description of Business and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Management Estimates	Management estimates — The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America requires management to make 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 such estimates.
Revenue Recognition	Revenue recognition — Revenues from daywork drilling and pressure pumping activities are recognized as services are performed. Expenditures reimbursed by customers are recognized as revenue and the related expenses are recognized as direct costs. All of the wells the Company drilled in 2015, 2014 and 2013 were drilled under daywork contracts.
Accounts Receivable	Accounts receivable — Trade accounts receivable are recorded at the invoiced amount. The allowance for doubtful accounts represents the Company’s estimate of the amount of probable credit losses existing in the Company’s accounts receivable. The Company reviews the adequacy of its allowance for doubtful accounts at least quarterly. Significant individual accounts receivable balances and balances which have been outstanding greater than 90 days are reviewed individually for collectability. Account balances, when determined to be uncollectable, are charged against the allowance.
Inventories	Inventories — Inventories consist primarily of sand and other products to be used in conjunction with the Company’s pressure pumping activities. The inventories are stated at the lower of cost or market, determined under the average cost method.
Property and Equipment	Property and equipment — Property and equipment is carried at cost less accumulated depreciation. Depreciation is provided on the straight-line method over the estimated useful lives. The method of depreciation does not change whenever equipment becomes idle. The estimated useful lives, in years, are shown below: Useful Lives Drilling rigs and other equipment 1.25-15 Buildings 15-20 Other 3-12 Long-lived assets, including property and equipment, are evaluated for impairment when certain triggering events or changes in circumstances indicate that the carrying values may not be recoverable over their estimated remaining useful life.
Oil and Natural Gas Properties	Oil and natural gas properties — Working interests in oil and natural gas properties are accounted for using the successful efforts method of accounting. Under the successful efforts method of accounting, exploration costs which result in the discovery of oil and natural gas reserves and all development costs are capitalized to the appropriate well. Exploration costs which do not result in discovering oil and natural gas reserves are charged to expense when such determination is made. Costs of exploratory wells are initially capitalized to wells-in-progress until the outcome of the drilling is known. The Company reviews wells-in-progress quarterly to determine whether sufficient progress is being made in assessing the reserves and economic viability of the respective projects. If no progress has been made in assessing the reserves and economic viability of a project after one year following the completion of drilling, the Company considers the well costs to be impaired and recognizes the costs as expense. Geological and geophysical costs, including seismic costs, and costs to carry and retain undeveloped properties are charged to expense when incurred. The capitalized costs of both developmental and successful exploratory type wells, consisting of lease and well equipment and intangible development costs, are depreciated, depleted and amortized using the units-of-production method, based on engineering estimates of total proved developed oil and natural gas reserves for each respective field. Oil and natural gas leasehold acquisition costs are depreciated, depleted and amortized using the units-of-production method, based on engineering estimates of total proved oil and natural gas reserves for each respective field. The Company reviews its proved oil and natural gas properties for impairment whenever a triggering event occurs, such as downward revisions in reserve estimates or decreases in expected future oil and natural gas prices. Proved properties are grouped by field and undiscounted cash flow estimates are prepared based on management’s expectation of future pricing over the lives of the respective fields. These cash flow estimates are reviewed by an independent petroleum engineer. If the net book value of a field exceeds its undiscounted cash flow estimate, impairment expense is measured and recognized as the difference between net book value and fair value. The fair value estimates used in measuring impairment are based on internally developed unobservable inputs including reserve volumes and future production, pricing and operating costs (Level 3 inputs in the fair value hierarchy of fair value accounting). The expected future net cash flows are discounted using an annual rate of 10% to determine fair value. The Company reviews unproved oil and natural gas properties quarterly to assess potential impairment. The Company’s impairment assessment is made on a lease-by-lease basis and considers factors such as management’s intent to drill, lease terms and abandonment of an area. If an unproved property is determined to be impaired, the related property costs are expensed.
Goodwill	Goodwill — Goodwill is considered to have an indefinite useful economic life and is not amortized. The Company assesses impairment of its goodwill at least annually as of December 31, or on an interim basis if events or circumstances indicate that the fair value of goodwill may have decreased below its carrying value.
Maintenance and Repairs	Maintenance and repairs — Maintenance and repairs are charged to expense when incurred. Renewals and betterments which extend the life or improve existing property and equipment are capitalized.
Disposals	Disposals — Upon disposition of property and equipment, the cost and related accumulated depreciation are removed and any resulting gain or loss is reflected in the consolidated statement of operations.
Net Income (Loss) Per Common Share	Net income (loss) per common share — The Company provides a dual presentation of its net income (loss) per common share in its consolidated statements of operations: Basic net income (loss) per common share (“Basic EPS”) and diluted net income (loss) per common share (“Diluted EPS”). Basic EPS excludes dilution and is computed by first allocating earnings between common stockholders and holders of non-vested shares of restricted stock. Basic EPS is then determined by dividing the earnings attributable to common stockholders by the weighted average number of common shares outstanding during the period, excluding non-vested shares of restricted stock. Diluted EPS is based on the weighted average number of common shares outstanding plus the dilutive effect of potential common shares, including stock options, non-vested shares of restricted stock and restricted stock units. The dilutive effect of stock options and restricted stock units is determined using the treasury stock method. The dilutive effect of non-vested shares of restricted stock is based on the more dilutive of the treasury stock method or the two-class method, assuming a reallocation of undistributed earnings to common stockholders after considering the dilutive effect of potential common shares other than non-vested shares of restricted stock. The following table presents information necessary to calculate net income (loss) per share for the years ended December 31, 2015, 2014 and 2013, as well as potentially dilutive securities excluded from the weighted average number of diluted common shares outstanding because their inclusion would have been anti-dilutive (in thousands, except per share amounts): 2015 2014 2013 BASIC EPS: Net income (loss) $ (294,486 ) $ 162,664 $ 188,009 Adjust for (income) loss attributed to holders of non-vested restricted stock 3,022 (1,663 ) (1,859 ) Income (loss) attributed to common stockholders $ (291,464 ) $ 161,001 $ 186,150 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 145,416 144,066 144,356 Basic net income (loss) per common share $ (2.00 ) $ 1.12 $ 1.29 DILUTED EPS: Income (loss) attributed to common stockholders $ (291,464 ) $ 161,001 $ 186,150 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 145,416 144,066 144,356 Add dilutive effect of potential common shares — 1,310 947 Weighted average number of diluted common shares outstanding 145,416 145,376 145,303 Diluted net income (loss) per common share $ (2.00 ) $ 1.11 $ 1.28 Potentially dilutive securities excluded as anti-dilutive 7,781 1,088 2,447
Income Taxes	Income taxes — The asset and liability method is used in accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for operating loss and tax credit carryforwards and for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the results of operations in the period that includes the enactment date. If applicable, a valuation allowance is recorded to reduce the carrying amounts of deferred tax assets unless it is more likely than not that such assets will be realized. The Company’s policy is to account for interest and penalties with respect to income taxes as operating expenses.
Stock-based Compensation	Stock-based compensation — The Company recognizes the cost of share-based payments under the fair-value-based method. Under this method, compensation cost related to share-based payments is measured based on the estimated fair value of the awards at the date of grant, net of estimated forfeitures. This expense is recognized over the expected life of the awards (See Note 10).
Statement of Cash Flows	Statement of cash flows — For purposes of reporting cash flows, cash and cash equivalents include cash on deposit and money market funds.
Recently Issued Accounting Standards	Recently Issued Accounting Standards — In May 2014, the Financial Accounting Standards Board (“FASB”) issued an accounting standards update to provide guidance on the recognition of revenue from customers. Under this guidance, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects what it expects in exchange for the goods or services. This guidance also requires more detailed disclosures to enable users of the financial statements to understand the nature, amount, timing and uncertainty, if any, of revenue and cash flows arising from contracts with customers. The requirements in this update are effective during interim and annual periods beginning after December 15, 2016. The Company is currently evaluating the impact this guidance will have on its consolidated financial statements. In June 2014, the FASB issued an accounting standards update to provide guidance on the accounting for share-based payments when the terms of an award provide that a performance target could be achieved after the requisite service period. The guidance requires that a performance target that affects vesting and that could be achieved after the requisite service period is treated as a performance condition. The requirements in this update are effective during interim and annual periods beginning after December 15, 2015. The adoption of this update is not expected to have a material impact on the Company’s consolidated financial statements. In April 2015, the FASB issued an accounting standards update to provide guidance for the presentation of debt issuance costs. Under this guidance, debt issuance costs shall be presented in the balance sheet as a direct deduction from the carrying amount of the related debt and shall not be classified as a deferred charge. Amortization of debt issuance costs shall continue to be reported as interest expense. The requirements in this update are effective during interim and annual periods beginning after December 15, 2015. The adoption of this update is not expected to have a material impact on the Company’s consolidated financial statements. In November 2015, the FASB issued an accounting standards update to provide guidance for the presentation of deferred tax liabilities and assets. Under this guidance, for a particular tax-paying component of an entity and within a particular tax jurisdiction, all deferred tax liabilities and assets, as well as any related valuation allowance, shall be offset and presented as a single noncurrent amount. The requirements in this update are effective during interim and annual periods beginning after December 15, 2016. The adoption of this update is not expected to have a material impact on the Company’s consolidated financial statements.

Description of Business and S29

Description of Business and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Estimated Useful Lives of Property and Equipment	The estimated useful lives, in years, are shown below: Useful Lives Drilling rigs and other equipment 1.25-15 Buildings 15-20 Other 3-12
Calculation of Basic and Diluted Net Income (Loss) per Share	The following table presents information necessary to calculate net income (loss) per share for the years ended December 31, 2015, 2014 and 2013, as well as potentially dilutive securities excluded from the weighted average number of diluted common shares outstanding because their inclusion would have been anti-dilutive (in thousands, except per share amounts): 2015 2014 2013 BASIC EPS: Net income (loss) $ (294,486 ) $ 162,664 $ 188,009 Adjust for (income) loss attributed to holders of non-vested restricted stock 3,022 (1,663 ) (1,859 ) Income (loss) attributed to common stockholders $ (291,464 ) $ 161,001 $ 186,150 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 145,416 144,066 144,356 Basic net income (loss) per common share $ (2.00 ) $ 1.12 $ 1.29 DILUTED EPS: Income (loss) attributed to common stockholders $ (291,464 ) $ 161,001 $ 186,150 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 145,416 144,066 144,356 Add dilutive effect of potential common shares — 1,310 947 Weighted average number of diluted common shares outstanding 145,416 145,376 145,303 Diluted net income (loss) per common share $ (2.00 ) $ 1.11 $ 1.28 Potentially dilutive securities excluded as anti-dilutive 7,781 1,088 2,447

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2015
Business Combinations [Abstract]
Summary of the Purchase Price Allocation	A summary of the purchase price allocation follows (in thousands): Inventory $ 1,357 Equipment 117,958 Goodwill 56,986 Total purchase price $ 176,301
Business Acquisition Pro-forma Unaudited Financial Information	The following represents pro-forma unaudited financial information for the years ended December 31, 2014 and 2013 as if the acquisitions had been completed on January 1, 2013 (in thousands, except per share amounts): 2014 2013 (Unaudited) Revenue $ 3,302,492 $ 2,854,867 Net income $ 169,831 $ 196,600 Basic net income per common share $ 1.17 $ 1.35 Diluted net income per common share $ 1.16 $ 1.34

Property and Equipment (Tables)

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2015
Property Plant And Equipment [Abstract]
Property and Equipment	Property and equipment consisted of the following at December 31, 2015 and 2014 (in thousands): 2015 2014 Equipment $ 6,963,148 $ 6,679,894 Oil and natural gas properties 200,923 196,234 Buildings 96,470 83,465 Land 22,370 12,038 Total property and equipment 7,282,911 6,971,631 Less accumulated depreciation, depletion and impairment (3,362,203 ) (2,840,560 ) Property and equipment, net $ 3,920,708 $ 4,131,071
Summary of Depreciation, Depletion, Amortization and Impairment Expense related to Property and Equipment and Intangible Assets	Depreciation, depletion, amortization and impairment — The following table summarizes depreciation, depletion, amortization and impairment expense related to property and equipment and intangible assets for 201 5, 2014 and 2013 (in thousands): 2015 2014 2013 Depreciation and impairment expense $ 845,543 $ 693,390 $ 573,106 Amortization expense 3,643 3,643 3,993 Depletion expense 15,573 21,697 20,370 Total $ 864,759 $ 718,730 $ 597,469

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2015
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill by Operating Segment	Goodwill — Goodwill by operating segment as of December 31, 201 5 and 2014 and changes for the years then ended are as follows (in thousands): Contract Pressure Drilling Pumping Total Balance December 31, 2013 $ 86,234 $ 67,575 $ 153,809 Changes to goodwill — 56,986 56,986 Balance December 31, 2014 86,234 124,561 210,795 Changes to goodwill — (124,561 ) (124,561 ) Balance December 31, 2015 $ 86,234 $ — $ 86,234
Gross Carrying Amount and Accumulated Amortization of Customer Relationships	The following table presents the gross carrying amount and accumulated amortization of the customer relationships as of December 31, 2015 and 2014 (in thousands): 2015 2014 Gross Carrying Accumulated Net Carrying Gross Carrying Accumulated Net Carrying Amount Amortization Amount Amount Amortization Amount Customer relationships $ 25,500 $ (19,125 ) $ 6,375 $ 25,500 $ (15,482 ) $ 10,018

Accrued Expenses (Tables)

Accrued Expenses (Tables)	12 Months Ended
	Dec. 31, 2015
Payables And Accruals [Abstract]
Accrued Expenses	Accrued expenses consisted of the following at December 31, 2015 and 2014 (in thousands): 2015 2014 Salaries, wages, payroll taxes and benefits $ 27,055 $ 52,956 Workers’ compensation liability 75,358 77,348 Property, sales, use and other taxes 9,061 11,644 Insurance, other than workers’ compensation 12,817 9,632 Accrued interest payable 7,668 7,427 Other 29,652 14,459 $ 161,611 $ 173,466

Asset Retirement Obligation (Ta

Asset Retirement Obligation (Tables)	12 Months Ended
	Dec. 31, 2015
Asset Retirement Obligation Disclosure [Abstract]
Changes to Company's Asset Retirement Obligations	The following table describes the changes to the Company’s asset retirement obligations during 2015 and 2014 (in thousands): 2015 2014 Balance at beginning of year $ 5,301 $ 4,837 Liabilities incurred 340 473 Liabilities settled (120 ) (197 ) Accretion expense 171 169 Revision in estimated costs of plugging oil and natural gas wells — 19 Asset retirement obligation at end of year $ 5,692 $ 5,301

Long Term Debt (Tables)

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2015
Debt Disclosure [Abstract]
Schedule of Principal Repayment Requirements of Long Term Debt	Presented below is a schedule of the principal repayment requirements of long-term debt by fiscal year as of December 31, 2015 (in thousands): Year ending December 31, 2016 $ 63,750 2017 191,250 2018 — 2019 — 2020 300,000 Thereafter 300,000 Total $ 855,000

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2015
Equity [Abstract]
Cash Dividends	Cash Dividends – The Company paid cash dividends during the years ended December 31, 201 3, 2014 and 2015 as follows: Per Share Total (in thousands) 2013: Paid on March 29, 2013 $ 0.05 $ 7,312 Paid on June 28, 2013 0.05 7,361 Paid on September 30, 2013 0.05 7,231 Paid on December 31, 2013 0.05 7,208 Total cash dividends $ 0.20 $ 29,112 2014: Paid on March 27, 2014 $ 0.10 $ 14,456 Paid on June 26, 2014 0.10 14,562 Paid on September 24, 2014 0.10 14,634 Paid on December 24, 2014 0.10 14,636 Total cash dividends $ 0.40 $ 58,288 2015: Paid on March 25, 2015 $ 0.10 $ 14,640 Paid on June 24, 2015 0.10 14,712 Paid on September 24, 2015 0.10 14,712 Paid on December 24, 2015 0.10 14,711 Total cash dividends $ 0.40 $ 58,775
Treasury Stock Acquisition	Treasury stock acquisitions during the years ended December 31, 2015, 2014 and 2013 were as follows (dollars in thousands): 2015 2014 2013 Shares Cost Shares Cost Shares Cost Treasury shares at beginning of period 42,818,585 $ 899,035 42,268,057 $ 880,888 38,146,738 $ 795,051 Purchases pursuant to stock buyback programs: 2012 program — — — — 2,567,266 51,107 2013 program 8,618 180 13,898 466 602,564 12,517 Acquisitions pursuant to long-term incentive plans 380,037 7,830 536,630 17,681 951,489 22,213 Treasury shares at end of period 43,207,240 $ 907,045 42,818,585 $ 899,035 42,268,057 $ 880,888

Stock-based Compensation (Table

Stock-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Share-based Compensation Plans	The Company’s share-based compensation plans at December 31, 2015 follow: Shares Shares Underlying Shares Authorized Awards Available Plan Name for Grant Outstanding for Grant Patterson-UTI Energy, Inc. 2014 Long-Term Incentive Plan 9,100,000 2,509,623 4,018,824 Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended — 5,271,563 —
Weighted-Average Assumptions Used to Estimate Grant Date Fair Values for Stock Options Granted	Weighted-average assumptions used to estimate grant date fair values for stock options granted in the years ended December 31, 2015, 2014 and 2013 follow: 2015 2014 2013 Volatility 37.95 % 35.89 % 41.36 % Expected term (in years) 5.00 5.00 5.00 Dividend yield 2.00 % 1.17 % 0.89 % Risk-free interest rate 1.37 % 1.76 % 0.70 %
Stock Option Activity	Stock option activity for the year ended December 31, 2015 follows: Weighted-average Shares exercise price Outstanding at beginning of year 6,086,250 $ 22.32 Granted 831,000 $ 20.06 Exercised — — Cancelled (10,000 ) $ 16.59 Expired (600,000 ) $ 26.06 Outstanding at end of year 6,307,250 $ 21.68 Exercisable at end of year 5,224,082 $ 21.49
Additional Information with Respect to Options Granted, Vested and Exercised	Additional information with respect to options granted, vested and exercised during the years ended December 31, 2015, 2014 and 2013 follows: 2015 2014 2013 Weighted-average grant date fair value of stock options granted (per share) $ 5.79 $ 9.81 $ 7.59 Aggregate grant date fair value of stock options vested during the year (in thousands) $ 5,077 $ 5,173 $ 5,240 Aggregate intrinsic value of stock options exercised (in thousands) $ — $ 21,862 $ 8,683
Restricted Stock Activity	Restricted stock activity for the year ended December 31, 2015 follows: Weighted- average Grant Shares Date Fair Value Non-vested restricted stock outstanding at beginning of year 1,493,059 $ 26.93 Granted 795,600 $ 20.58 Vested (774,235 ) $ 24.89 Forfeited (82,174 ) $ 25.89 Non-vested restricted stock outstanding at end of year 1,432,250 $ 24.56
Restricted Stock Unit Activity	Restricted stock unit activity for the year ended December 31, 2015 follows: Weighted-average Grant Date Fair Shares Value Non-vested restricted stock units outstanding at beginning of year 34,085 $ 30.20 Granted 22,100 $ 20.85 Vested (14,499 ) $ 27.37 Forfeited — $ — Non-vested restricted stock units outstanding at end of year 41,686 $ 26.22
Stock-Settled Performance Units	The total target number of shares with respect to the Stock-Settled Performance Units is set forth below: 2015 2014 2013 2012 2011 2010 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Target number of shares 190,600 154,000 236,500 192,000 144,375 178,750
Total Shareholder Return Percentiles and Number of Shares Issued	For the stock-settled Performance Units that have been settled, following are the total shareholder return percentiles and the number of shares issued: 2012 2011 2010 Performance Performance Performance Unit Awards Unit Awards Unit Awards Total shareholder return percentile for performance period 87 th 94 th 93 rd Shares issued 384,000 288,750 357,500
Fair Value of Stock-Settled Performance Units	The fair value of the Stock-Settled Performance Units is set forth below (in thousands): 2015 2014 2013 2012 2011 2010 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Aggregate fair value at date of grant $ 4,052 $ 5,388 $ 5,564 $ 3,065 $ 5,569 $ 3,117
Compensation Expense Associated with Stock-Settled Performance Units	Compensation expense associated with the Stock-Settled Performance Units is set forth below (in thousands): 2015 2014 2013 2012 2011 2010 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Year ended December 31, 2015 $ 1,013 $ 1,796 $ 1,855 $ 255 NA NA Year ended December 31, 2014 NA $ 1,347 $ 1,855 $ 1,022 $ 464 NA Year ended December 31, 2013 NA NA $ 1,391 $ 1,022 $ 1,856 $ 260
Employee Stock Option
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Additional Information with Respect to Non-vested Shares	Additional information as of December 31, 2015 with respect to these non-vested options follows: Aggregate intrinsic value (in thousands) $ — Weighted-average remaining contractual term 8.99 years Weighted-average remaining expected term 3.99 years Weighted-average remaining vesting period 1.89 years Unrecognized compensation cost $5.8 million
Restricted Stock Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Additional Information with Respect to Non-vested Shares	As of December 31, 2015, approximately 1.3 million shares of non-vested restricted stock outstanding are expected to vest. Additional information as of December 31, 2015 with respect to these non-vested shares follows: Aggregate intrinsic value $19.9 million Weighted-average remaining vesting period 1.8 years Unrecognized compensation cost $25.1 million

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2015
Leases [Abstract]
Summary of Future Minimum Rental Payments Under Operating Leases	Future minimum rental payments required under operating leases having initial or remaining non-cancelable lease terms in excess of one year at December 31, 2015 are as follows: Year ending December 31, 2016 $ 10,522 2017 4,969 2018 4,053 2019 3,229 2020 2,734 Thereafter 4,655 Total $ 30,162

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Components of Income Tax Provision	Components of the income tax provision applicable to federal, state and foreign income taxes for the years ended December 31, 2015, 2014 and 2013 are as follows (in thousands): 2015 2014 2013 Federal income tax expense (benefit): Current $ (42,020 ) $ 39,438 $ 41,558 Deferred (83,812 ) 39,673 47,136 (125,832 ) 79,111 88,694 State income tax expense (benefit): Current (3,480 ) 3,987 11,733 Deferred (12,433 ) 5,292 4,229 (15,913 ) 9,279 15,962 Foreign income tax expense (benefit): Current (2,590 ) 4,521 4,572 Deferred (3,628 ) (1,292 ) (796 ) (6,218 ) 3,229 3,776 Total income tax expense (benefit): Current (48,090 ) 47,946 57,863 Deferred (99,873 ) 43,673 50,569 Total income tax expense (benefit): $ (147,963 ) $ 91,619 $ 108,432
Difference Between Statutory Federal Income Tax Rate and Effective Income Tax Rate	The difference between the statutory federal income tax rate and the effective income tax rate for the years ended December 31, 2015, 2014 and 2013 is summarized as follows: 2015 2014 2013 Statutory tax rate 35.0 % 35.0 % 35.0 % State income taxes 2.1 2.5 3.7 Permanent differences (1.3 ) (1.4 ) (1.5 ) Other differences, net (2.4 ) (0.1 ) (0.6 ) Effective tax rate 33.4 % 36.0 % 36.6 %
Tax Effect of Significant Temporary Differences Representing Deferred Tax Assets and Liabilities	The tax effect of significant temporary differences representing deferred tax assets and liabilities and changes therein were as follows (in thousands): December 31, Net December 31, Net December Net December 2015 Change 2014 Change 2013 Change 2012 Deferred tax assets: Current: Net operating loss carryforwards $ 27,887 $ 27,887 $ — $ — $ — $ (18,914 ) $ 18,914 Workers’ compensation allowance 28,734 424 28,310 698 27,612 2,534 25,078 Other 21,305 (1,091 ) 22,396 2,749 19,647 (804 ) 20,451 77,926 27,220 50,706 3,447 47,259 (17,184 ) 64,443 Non-current: Net operating loss carryforwards 77,514 65,050 12,464 (988 ) 13,452 1,690 11,762 Expense associated with employee stock options 14,591 205 14,386 (1,822 ) 16,208 1,536 14,672 Federal benefit of state deferred tax liabilities 24,485 466 24,019 1,181 22,838 816 22,022 Other 20,441 4,394 16,047 1,344 14,703 (421 ) 15,124 137,031 70,115 66,916 (285 ) 67,201 3,621 63,580 Less: Allowance to reduce deferred tax asset to expected realizable value (603 ) (603 ) — — — — — Total deferred tax assets 214,354 96,732 117,622 3,162 114,460 (13,563 ) 128,023 Deferred tax liabilities: Current: Other (12,805 ) 826 (13,631 ) 676 (14,307 ) (2,823 ) (11,484 ) Non-current: Property and equipment basis difference (986,922 ) 31 (986,953 ) (47,359 ) (939,594 ) (33,997 ) (905,597 ) Other (13,339 ) 2,284 (15,623 ) (152 ) (15,471 ) (186 ) (15,285 ) (1,000,261 ) 2,315 (1,002,576 ) (47,511 ) (955,065 ) (34,183 ) (920,882 ) Total deferred tax liabilities (1,013,066 ) 3,141 (1,016,207 ) (46,835 ) (969,372 ) (37,006 ) (932,366 ) Net deferred tax liability $ (798,712 ) $ 99,873 $ (898,585 ) $ (43,673 ) $ (854,912 ) $ (50,569 ) $ (804,343 )

Business Segments (Tables)

Business Segments (Tables)	12 Months Ended
	Dec. 31, 2015
Segment Reporting [Abstract]
Business Segments - Financial Information	The following tables summarize selected financial information relating to the Company’s business segments (in thousands): Years Ended December 31, 2015 2014 2013 Revenues: Contract drilling $ 1,155,565 $ 1,843,707 $ 1,684,878 Pressure pumping 712,454 1,294,569 979,166 Oil and natural gas 24,931 50,196 57,257 Total segment revenues 1,892,950 3,188,472 2,721,301 Elimination of intercompany revenues(a) (1,673 ) (6,181 ) (5,267 ) Total revenues $ 1,891,277 $ 3,182,291 $ 2,716,034 Income (loss) before income taxes: Contract drilling $ (91,230 ) $ 241,851 $ 266,262 Pressure pumping (254,998 ) 89,081 87,244 Oil and natural gas (12,870 ) (5,482 ) 19,948 (359,098 ) 325,450 373,454 Corporate and other (58,487 ) (58,105 ) (54,647 ) Net gain on asset disposals(b) 10,613 15,781 3,384 Interest income 964 979 918 Interest expense (36,475 ) (29,825 ) (28,359 ) Other 34 3 1,691 Income (loss) before income taxes $ (442,449 ) $ 254,283 $ 296,441 Identifiable assets: Contract drilling $ 3,457,044 $ 4,000,576 $ 3,569,588 Pressure pumping 813,704 1,186,010 761,199 Oil and natural gas 34,073 50,945 58,656 Corporate and other(c) 228,496 156,480 297,684 Total assets $ 4,533,317 $ 5,394,011 $ 4,687,127 Depreciation, depletion, amortization and impairment: Contract drilling $ 618,434 $ 524,023 $ 438,728 Pressure pumping 214,552 147,595 129,984 Oil and natural gas 26,301 42,576 24,400 Corporate and other 5,472 4,536 4,357 Total depreciation, depletion, amortization and impairment $ 864,759 $ 718,730 $ 597,469 Capital expenditures: Contract drilling $ 527,054 $ 771,593 $ 504,508 Pressure pumping 197,577 241,359 122,782 Oil and natural gas 16,625 36,683 31,245 Corporate and other 2,520 2,706 3,926 Total capital expenditures $ 743,776 $ 1,052,341 $ 662,461 (a) Consists of contract drilling and, in 2014, pressure pumping intercompany revenues for services provided to the oil and natural gas exploration and production segment. (b) Net gains or losses associated with the disposal of assets relate to corporate strategy decisions of the executive management group. Accordingly, the related gains or losses have been separately presented and excluded from the results of specific segments. (c) Corporate and other assets primarily include cash on hand, income tax receivables and certain deferred tax assets.

Concentrations of Credit Risk (

Concentrations of Credit Risk (Tables)	12 Months Ended
	Dec. 31, 2015
Risks And Uncertainties [Abstract]
Company's Demand Deposits and Temporary Cash Investments	At December 31, 2015 and 2014, the Company’s demand deposits and temporary cash investments consisted of the following (in thousands): 2015 2014 Deposits in FDIC and SIPC-insured institutions under insurance limits $ 617 $ 636 Deposits in FDIC and SIPC-insured institutions over insurance limits 130,330 1,420 Deposits in foreign banks 15,303 43,664 146,250 45,720 Less outstanding checks and other reconciling items (32,904 ) (2,708 ) Cash and cash equivalents $ 113,346 $ 43,012

Fair Values of Financial Inst42

Fair Values of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2015
Fair Value Disclosures [Abstract]
Estimated Fair Value of Outstanding Debt Balances	The estimated fair value of the Company’s outstanding debt balances (including current portion) as of December 31, 2015 and 2014 is set forth below (in thousands): December 31, 2015 December 31, 2014 Carrying Fair Carrying Fair Value Value Value Value Borrowings under Credit Agreement: Revolving credit facility $ — $ — $ 303,000 $ 303,000 Term loan facility 70,000 70,000 82,500 82,500 2015 Term Loan 185,000 185,000 — — 4.97% Series A Senior Notes 300,000 279,635 300,000 288,346 4.27% Series B Senior Notes 300,000 258,806 300,000 269,173 Total debt $ 855,000 $ 793,441 $ 985,500 $ 943,019

Quarterly Financial Informati43

Quarterly Financial Information (Tables)	12 Months Ended
	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Summary of Unaudited Quarterly Financial Information	1 st 2 nd 3 rd 4 th Quarter Quarter Quarter Quarter 2014 Operating revenues $ 678,168 $ 757,276 $ 845,628 $ 901,219 Operating income 58,776 87,226 30,291 106,833 Net income 34,822 54,283 15,976 57,583 Net income per common share: Basic $ 0.24 $ 0.37 $ 0.11 $ 0.39 Diluted $ 0.24 $ 0.37 $ 0.11 $ 0.39 2015 Operating revenues $ 657,699 $ 472,761 $ 422,251 $ 338,566 Operating income (loss) 24,103 (24,764 ) (329,515 ) (76,796 ) Net income (loss) 9,125 (18,975 ) (225,978 ) (58,658 ) Net income (loss) per common share: Basic $ 0.06 $ (0.13 ) $ (1.54 ) $ (0.40 ) Diluted $ 0.06 $ (0.13 ) $ (1.54 ) $ (0.40 )

Estimated Useful Lives of Prope

Estimated Useful Lives of Property and Equipment (Detail)	12 Months Ended
	Dec. 31, 2015
Drilling Rigs and Other Equipment | Minimum
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	1 year 3 months
Drilling Rigs and Other Equipment | Maximum
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	15 years
Buildings | Minimum
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	15 years
Buildings | Maximum
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	20 years
Other | Minimum
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	3 years
Other | Maximum
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	12 years

Description of Business and S45

Description of Business and Summary of Significant Accounting Policies - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015
Accounting Policies [Abstract]
Future net cash flow discount rate	10.00%

Calculation of Basic and Dilute

Calculation of Basic and Diluted Net Income (Loss) per Share (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ 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
BASIC EPS:
Net income (loss)	$ (58,658)	$ (225,978)	$ (18,975)	$ 9,125	$ 57,583	$ 15,976	$ 54,283	$ 34,822	$ (294,486)	$ 162,664	$ 188,009
Adjust for (income) loss attributed to holders of non-vested restricted stock									3,022	(1,663)	(1,859)
Income (loss) attributed to common stockholders									$ (291,464)	$ 161,001	$ 186,150
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock									145,416	144,066	144,356
Basic net income (loss) per common share	$ (0.40)	$ (1.54)	$ (0.13)	$ 0.06	$ 0.39	$ 0.11	$ 0.37	$ 0.24	$ (2)	$ 1.12	$ 1.29
DILUTED EPS:
Income (loss) attributed to common stockholders									$ (291,464)	$ 161,001	$ 186,150
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock									145,416	144,066	144,356
Add dilutive effect of potential common shares										1,310	947
Weighted average number of diluted common shares outstanding									145,416	145,376	145,303
Diluted net income (loss) per common share	$ (0.40)	$ (1.54)	$ (0.13)	$ 0.06	$ 0.39	$ 0.11	$ 0.37	$ 0.24	$ (2)	$ 1.11	$ 1.28
Potentially dilutive securities excluded as anti-dilutive									7,781	1,088	2,447

Acquisitions - Additional Infor

Acquisitions - Additional Information (Detail) $ in Millions	1 Months Ended		12 Months Ended
	Oct. 31, 2014hp	Jun. 30, 2014hp	Dec. 31, 2014USD ($)PressurePumpingEquipments
Business Acquisition [Line Items]
Hydraulic fracturing equipment purchased in the acquisition | hp	148,250	31,500
Payments to acquire businesses			$ 176
Revenue from acquired business			80.8
Operating income (loss) from acquired business			$ 13.7
Pressure Pumping
Business Acquisition [Line Items]
Number of pressure pumping acquisitions | PressurePumpingEquipments			2

Summary of Purchase Price Alloc

Summary of Purchase Price Allocation (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition [Line Items]
Goodwill	$ 86,234	$ 210,795	$ 153,809
Pressure Pumping Acquisitions
Business Acquisition [Line Items]
Inventory		1,357
Equipment		117,958
Goodwill		56,986
Total purchase price		$ 176,301

Business Acquisition Pro-forma

Business Acquisition Pro-forma Unaudited Financial Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2014	Dec. 31, 2013
Business Acquisition Pro Forma Information [Abstract]
Revenue	$ 3,302,492	$ 2,854,867
Net income	$ 169,831	$ 196,600
Basic net income per common share	$ 1.17	$ 1.35
Diluted net income per common share	$ 1.16	$ 1.34

Property and Equipment (Detail)

Property and Equipment (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Property Plant And Equipment [Line Items]
Total property and equipment	$ 7,282,911	$ 6,971,631
Less accumulated depreciation, depletion and impairment	(3,362,203)	(2,840,560)
Property and equipment, net	3,920,708	4,131,071
Equipment
Property Plant And Equipment [Line Items]
Total property and equipment	6,963,148	6,679,894
Oil and natural gas properties
Property Plant And Equipment [Line Items]
Total property and equipment	200,923	196,234
Buildings
Property Plant And Equipment [Line Items]
Total property and equipment	96,470	83,465
Land
Property Plant And Equipment [Line Items]
Total property and equipment	$ 22,370	$ 12,038

Depreciation, Depletion, Amorti

Depreciation, Depletion, Amortization and Impairment Expense Related to Property and Equipment and Intangible Assets (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Property Plant And Equipment [Abstract]
Depreciation and impairment expense	$ 845,543	$ 693,390	$ 573,106
Amortization expense	3,643	3,643	3,993
Depletion expense	15,573	21,697	20,370
Total	$ 864,759	$ 718,730	$ 597,469

Property and Equipment - Additi

Property and Equipment - Additional Information (Detail) $ in Millions	1 Months Ended		3 Months Ended			12 Months Ended
	Aug. 31, 2015$ / bbl	Mar. 31, 2015$ / bbl	Sep. 30, 2015USD ($)$ / bbl	Jun. 30, 2015$ / bbl	Mar. 31, 2015$ / bbl	Dec. 31, 2015USD ($)Rigs	Dec. 31, 2014USD ($)Rigs	Dec. 31, 2013USD ($)Rigs
Property Plant And Equipment [Line Items]
Impairment charges of fleets						$ 131
Expected cash flows from contract drilling segment			$ 801			710
Average oil price per barrel | $ / bbl	38.22	43.39	46.42	57.85	48.54
Impairment charges related to oil and natural gas properties						$ 10.7
Drilling Rigs That Would No Longer Be Marketed As Rigs
Property Plant And Equipment [Line Items]
Number of drilling rigs | Rigs						33	55	48
Impairment charges of fleets							$ 77.9	$ 37.8
Mechanically Powered Drilling Rigs That Would No Longer Be Marketed as Rigs
Property Plant And Equipment [Line Items]
Number of drilling rigs | Rigs						24
Non-APEX® electric Drilling Rigs That Would No Longer Be Marketed as Rigs
Property Plant And Equipment [Line Items]
Number of drilling rigs | Rigs						9
Mechanically powered drilling rigs that remain marketable but are not operating
Property Plant And Equipment [Line Items]
Number of drilling rigs | Rigs						15
Pressure Pumping
Property Plant And Equipment [Line Items]
Impairment charges of fleets						$ 22	$ 0	$ 0
Percentage of excepted cash flows on undiscounted basis exceeding the carrying values of long-lived assets			60.00%			100.00%
Contract Drilling
Property Plant And Equipment [Line Items]
Percentage of excepted cash flows on undiscounted basis exceeding the carrying values of long-lived assets			120.00%			120.00%

Goodwill by Operating Segment (

Goodwill by Operating Segment (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Goodwill [Line Items]
Beginning Balance	$ 210,795	$ 153,809
Changes to goodwill	(124,561)	56,986
Ending Balance	86,234	210,795
Contract Drilling
Goodwill [Line Items]
Beginning Balance	86,234	86,234
Ending Balance	86,234	86,234
Pressure Pumping
Goodwill [Line Items]
Beginning Balance	124,561	67,575
Changes to goodwill	$ (124,561)	56,986
Ending Balance		$ 124,561

Goodwill and Intangible Asset54

Goodwill and Intangible Assets - Additional Information (Detail)	1 Months Ended			3 Months Ended			12 Months Ended
	Aug. 31, 2015$ / bbl	Mar. 31, 2015$ / bbl	Oct. 31, 2010	Sep. 30, 2015USD ($)$ / bbl	Jun. 30, 2015$ / bbl	Mar. 31, 2015$ / bbl	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Goodwill And Intangible Assets Disclosure [Line Items]
Average oil price per barrel | $ / bbl	38.22	43.39		46.42	57.85	48.54
Goodwill impairment charge							$ 124,561,000
Amortization expense							$ 3,643,000	$ 3,643,000	$ 3,993,000
Non-compete Agreement
Goodwill And Intangible Assets Disclosure [Line Items]
Contract term			3 years
Amortization period (in years)									3 years
Amortization expense									$ 350,000
Customer Relationships
Goodwill And Intangible Assets Disclosure [Line Items]
Amortization period (in years)							7 years
Amortization expense							$ 3,600,000	3,600,000	$ 3,600,000
Impairment							0
Contract Drilling
Goodwill And Intangible Assets Disclosure [Line Items]
Accumulated impairment losses							$ 0	$ 0
Percentage fair value exceeds carrying value				15.00%			16.00%
Goodwill impairment charge				$ 0			$ 0
Pressure Pumping
Goodwill And Intangible Assets Disclosure [Line Items]
Goodwill impairment charge				$ 125,000,000

Gross Carrying Amount and Accum

Gross Carrying Amount and Accumulated Amortization of Intangible Assets (Detail) - Customer Relationships - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 25,500	$ 25,500
Accumulated Amortization	(19,125)	(15,482)
Net Carrying Amount	$ 6,375	$ 10,018

Summary of Accrued Expenses (De

Summary of Accrued Expenses (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Payables And Accruals [Abstract]
Salaries, wages, payroll taxes and benefits	$ 27,055	$ 52,956
Workers' compensation liability	75,358	77,348
Property, sales, use and other taxes	9,061	11,644
Insurance, other than workers' compensation	12,817	9,632
Accrued interest payable	7,668	7,427
Other	29,652	14,459
Accrued expenses	$ 161,611	$ 173,466

Changes to Company's Asset Reti

Changes to Company's Asset Retirement Obligations (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
Asset Retirement Obligation Disclosure [Abstract]
Balance at beginning of year	$ 5,301	$ 4,837
Liabilities incurred	340	473
Liabilities settled	(120)	(197)
Accretion expense	171	169
Revision in estimated costs of plugging oil and natural gas wells		19
Asset retirement obligation at end of year	$ 5,692	$ 5,301

Long Term Debt - Credit Facilit

Long Term Debt - Credit Facilities - Additional Information (Detail)	Mar. 18, 2015USD ($)Covenant	Mar. 16, 2015	Sep. 27, 2012USD ($)Covenant	Dec. 31, 2015USD ($)	Apr. 01, 2016	Jan. 01, 2016	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)
Debt Instrument [Line Items]
Proceeds from long-term debt				$ 200,000,000
Assets				4,533,317,000			$ 5,394,011,000	$ 4,687,127,000
Letters of credit outstanding				41,100,000
Maximum | Subsidiaries
Debt Instrument [Line Items]
Assets	$ 1,000,000
London Interbank Offered Rate (LIBOR) | Scenario Forecast
Debt Instrument [Line Items]
Applicable margin					2.75%
Base Rate | Scenario Forecast
Debt Instrument [Line Items]
Applicable margin					1.75%
Letter of Credit
Debt Instrument [Line Items]
Line of credit, amount outstanding				0
Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit, available borrowing capacity				$ 500,000,000
Credit Agreement
Debt Instrument [Line Items]
Credit agreement date			Sep. 27, 2012
Aggregate amount by which the revolving credit facility can be increased			$ 100,000,000
Credit facility, maximum borrowing capacity			$ 700,000,000
Debt maturity date			Sep. 27, 2017
Commitment fee payable to the lenders for the unused portion of the credit facility			0.50%
Credit agreement, financial covenant description				The Company must not permit its debt to capitalization ratio to exceed 45%. The Credit Agreement generally defines the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit the interest coverage ratio as of the last day of a fiscal quarter to be less than 3.00 to 1.00. The Credit Agreement generally defines the interest coverage ratio as the ratio of earnings before interest, taxes, depreciation and amortization (“EBITDA”) of the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at December 31, 2015.
Credit agreement, financial covenant compliance				The Company was in compliance with these covenants
Number of compliance covenants | Covenant			2
Credit Agreement | Minimum
Debt Instrument [Line Items]
Interest coverage ratio that the Company must exceed on the last day of the fiscal quarter			300.00%
Credit Agreement | Maximum
Debt Instrument [Line Items]
Debt to capitalization ratio, percentage the Company must not exceed at any time			45.00%
Credit Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate				2.25%
Credit Agreement | London Interbank Offered Rate (LIBOR) | Subsequent Event
Debt Instrument [Line Items]
Applicable margin						2.25%
Credit Agreement | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.25%
Credit Agreement | London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.25%
Credit Agreement | Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate				1.25%
Credit Agreement | Base Rate | Subsequent Event
Debt Instrument [Line Items]
Applicable margin						1.25%
Credit Agreement | Base Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.25%
Credit Agreement | Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.25%
Credit Agreement | Revolving Credit Facility
Debt Instrument [Line Items]
Current aggregate borrowing capacity			$ 500,000,000
Line of credit, amount outstanding				$ 0
Credit Agreement | Revolving Credit Facility | Letter of Credit
Debt Instrument [Line Items]
Current aggregate borrowing capacity			150,000,000
Credit Agreement | Revolving Credit Facility | Swing Line Facility
Debt Instrument [Line Items]
Current aggregate borrowing capacity			40,000,000
Credit Agreement | Term Loan Facility
Debt Instrument [Line Items]
Proceeds from long-term debt			$ 100,000,000
Line of credit facility, frequency of payment and payment terms				The term loan facility provides for a loan of $100 million, which was drawn on December 24, 2012. The term loan facility is payable in quarterly principal installments, which commenced December 27, 2012. The installment amounts vary from 1.25% of the original principal amount for each of the first four quarterly installments, 2.50% of the original principal amount for each of the subsequent eight quarterly installments, 5.00% of the original principal amount for the subsequent four quarterly installments and 13.75% of the original principal amount for the final four quarterly installments.
Line of credit facility, frequency of payments				Quarterly
Commencement date of principal payments			Dec. 27, 2012
Line of credit, amount outstanding				$ 70,000,000
Line of credit facility, interest rate				2.875%
Credit Agreement | Term Loan Facility | Debt Instrument, Redemption, Period One [Member]
Debt Instrument [Line Items]
Installment amounts percentage of the original principal amount			1.25%
Credit Agreement | Term Loan Facility | Debt Instrument, Redemption, Period Two [Member]
Debt Instrument [Line Items]
Installment amounts percentage of the original principal amount			2.50%
Credit Agreement | Term Loan Facility | Debt Instrument, Redemption, Period Three [Member]
Debt Instrument [Line Items]
Installment amounts percentage of the original principal amount			5.00%
Credit Agreement | Term Loan Facility | Debt Instrument, Redemption, Period Four [Member]
Debt Instrument [Line Items]
Installment amounts percentage of the original principal amount			13.75%
Reimbursement Agreement
Debt Instrument [Line Items]
Letters of credit outstanding				$ 41,100,000
Reimbursement Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate		2.25%
2015 Term Loan Agreement
Debt Instrument [Line Items]
Line of credit facility, frequency of payment and payment terms				The Term Loan Borrowing is payable in quarterly principal installments, together with accrued interest, on each June 30, September 30, December 31 and March 31, commencing on June 30, 2015. Each of the first four principal installments is in an amount equal to 2.5% of the Term Loan Borrowing and each successive quarterly installment, until and including June 30, 2017, is in an amount equal to 5.0% of the Term Loan Borrowing, with the outstanding principal balance of the Term Loan Borrowing due on the maturity date under the 2015 Term Loan Agreement. The maturity date under the 2015 Term Loan Agreement is September 27, 2017. Loans under the 2015 Term Loan Agreement bear interest, at the Company’s election, at the per annum rate of LIBOR rate plus 3.25% or base rate plus 2.25%.
Line of credit facility, frequency of payments				Quarterly
Commencement date of principal payments				Jun. 30, 2015
Debt maturity date				Sep. 27, 2017
Credit agreement, financial covenant description				The Company must not permit its debt to capitalization ratio to exceed 45%. The 2015 Term Loan Agreement generally defines the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the most recently ended fiscal quarter. The Company also must not permit the interest coverage ratio as of the last day of a fiscal quarter to be less than 3.00 to 1.00. The 2015 Term Loan Agreement generally defines the interest coverage ratio as the ratio of EBITDA of the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at December 31, 2015.
Credit agreement, financial covenant compliance				The Company was in compliance with these covenants
Number of compliance covenants | Covenant	2
Line of credit, amount outstanding	$ 200,000,000			$ 185,000,000
Line of credit facility, interest rate				3.875%
Quarterly interest payment, first payment date				June 30
Quarterly interest payment, second payment date				September 30
Quarterly interest payment, third payment date				December 31
Quarterly interest payment, fourth payment date				March 31
2015 Term Loan Agreement | Minimum
Debt Instrument [Line Items]
Interest coverage ratio that the Company must exceed on the last day of the fiscal quarter	300.00%
2015 Term Loan Agreement | Maximum
Debt Instrument [Line Items]
Debt to capitalization ratio, percentage the Company must not exceed at any time	45.00%
Pro forma ratio of debt to EBITDA	250.00%
2015 Term Loan Agreement | Maximum | Subsidiaries
Debt Instrument [Line Items]
Assets	$ 1,000,000
2015 Term Loan Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate				3.25%
2015 Term Loan Agreement | Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate				2.25%
2015 Term Loan Agreement | Debt Instrument, Redemption, Period One [Member]
Debt Instrument [Line Items]
Installment amounts percentage of the original principal amount				2.50%
2015 Term Loan Agreement | Debt Instrument, Redemption, Period Five [Member]
Debt Instrument [Line Items]
Installment amounts percentage of the original principal amount				5.00%

Long Term Debt - Senior Notes -

Long Term Debt - Senior Notes - Additional Information (Detail) $ in Millions	Jun. 14, 2012USD ($)Covenant	Oct. 05, 2010USD ($)Covenant	Dec. 31, 2015USD ($)	Dec. 31, 2014USD ($)	Dec. 31, 2013USD ($)	Dec. 31, 2012USD ($)	Dec. 31, 2010USD ($)
Debt Instrument [Line Items]
Interest expense related to amortization of debt issuance costs			$ 2.8	$ 2.2	$ 2.2
4.97% Series A Senior Notes, Due October 5th 2020
Debt Instrument [Line Items]
Debt maturity date		Oct. 5, 2020
Long-term debt, aggregate principal amount		$ 300
Debt interest rate		4.97%
Semi-annual interest payment, first payment date			April 5
Semi-annual interest payment, second payment date			October 5
Notes issuance date		Oct. 5, 2010
Description of the prepayment terms			Notes are prepayable at the Company’s option, in whole or in part, provided that in the case of a partial prepayment, prepayment must be in an amount not less than 5% of the aggregate principal amount of the notes then outstanding, at any time and from time to time at 100% of the principal amount prepaid, plus accrued and unpaid interest to the prepayment date, plus a “make-whole” premium as specified in the note purchase agreements. The Company must offer to prepay the notes upon the occurrence of any change of control. In addition, the Company must offer to prepay the notes upon the occurrence of certain asset dispositions if the proceeds therefrom are not timely reinvested in productive assets. If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.
Prepayment terms, percent of principal before accrued and unpaid interest and "make-whole" premium		100.00%
Description of the acceptance terms			If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.
Acceptance terms, percent of principal before accrued and unpaid interest		100.00%
Number of compliance covenants | Covenant		2
Note purchase agreement, financial covenant description			The Company must not permit its debt to capitalization ratio to exceed 50% at any time. The note purchase agreements generally define the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit the interest coverage ratio as of the last day of a fiscal quarter to be less than 2.50 to 1.00. The note purchase agreements generally define the interest coverage ratio as the ratio of EBITDA for the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at December 31, 2015.
Debt issuance costs							$ 10.8
4.97% Series A Senior Notes, Due October 5th 2020 | Minimum
Debt Instrument [Line Items]
Debt instrument, prepayment percentage of aggregate principal amount		5.00%
Interest coverage ratio that the Company must exceed on the last day of the fiscal quarter		2.50%
4.97% Series A Senior Notes, Due October 5th 2020 | Maximum
Debt Instrument [Line Items]
Debt to capitalization ratio, percentage the Company must not exceed at any time		50.00%
4.27% Series B Senior Notes, Due June 14th 2022
Debt Instrument [Line Items]
Debt maturity date	Jun. 14, 2022
Long-term debt, aggregate principal amount	$ 300
Debt interest rate	4.27%
Semi-annual interest payment, first payment date			April 5
Semi-annual interest payment, second payment date			October 5
Notes issuance date	Jun. 14, 2012
Description of the prepayment terms			Notes are prepayable at the Company’s option, in whole or in part, provided that in the case of a partial prepayment, prepayment must be in an amount not less than 5% of the aggregate principal amount of the notes then outstanding, at any time and from time to time at 100% of the principal amount prepaid, plus accrued and unpaid interest to the prepayment date, plus a “make-whole” premium as specified in the note purchase agreements. The Company must offer to prepay the notes upon the occurrence of any change of control. In addition, the Company must offer to prepay the notes upon the occurrence of certain asset dispositions if the proceeds therefrom are not timely reinvested in productive assets. If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.
Prepayment terms, percent of principal before accrued and unpaid interest and "make-whole" premium	100.00%
Description of the acceptance terms			If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.
Acceptance terms, percent of principal before accrued and unpaid interest	100.00%
Number of compliance covenants | Covenant	2
Note purchase agreement, financial covenant description			The Company must not permit its debt to capitalization ratio to exceed 50% at any time. The note purchase agreements generally define the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit the interest coverage ratio as of the last day of a fiscal quarter to be less than 2.50 to 1.00. The note purchase agreements generally define the interest coverage ratio as the ratio of EBITDA for the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at December 31, 2015.
Debt issuance costs						$ 7.6
4.27% Series B Senior Notes, Due June 14th 2022 | Minimum
Debt Instrument [Line Items]
Debt instrument, prepayment percentage of aggregate principal amount	5.00%
Interest coverage ratio that the Company must exceed on the last day of the fiscal quarter	2.50%
4.27% Series B Senior Notes, Due June 14th 2022 | Maximum
Debt Instrument [Line Items]
Debt to capitalization ratio, percentage the Company must not exceed at any time	50.00%
Reimbursement Agreement And Two Thousand Fifteen Term Loan Agreement
Debt Instrument [Line Items]
Debt issuance costs			$ 2

Schedule of Principal Repayment

Schedule of Principal Repayment Requirements of Long-Term Debt (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Debt Disclosure [Abstract]
2,016	$ 63,750
2,017	191,250
2,020	300,000
Thereafter	300,000
Total	$ 855,000	$ 985,500

Commitments Contingencies and O

Commitments Contingencies and Other Matters - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015USD ($)
Commitments and Contingencies Disclosure [Line Items]
Letters of credit, collateral for retrospective premiums and retained losses	$ 41,100,000
Commitments to purchase major equipment	73,500,000
Current obligation	26,500,000
Purchase obligations for 2016	9,500,000
Settlement of fund for eligible participants	12,300,000
Self-insured retention	2,000,000
Workers' compensation insurance policy, deductible per occurrence	1,500,000
Automobile liability insurance policy, deductible per occurrence	2,000,000
Equipment insurance policy, deductible per occurrence	$ 1,000,000
Key Employees | Change in Control Agreements
Commitments and Contingencies Disclosure [Line Items]
Automatic renewal period	12 months
New term notification period	90 days
Chairman of the Board and Chief Executive Officer | Change in Control Agreements
Commitments and Contingencies Disclosure [Line Items]
Employee entitlement ratio	2.5
Continued coverage entitlement of welfare plan period	3 years
Senior Vice Presidents | Change in Control Agreements
Commitments and Contingencies Disclosure [Line Items]
Employee entitlement ratio	2
Continued coverage entitlement of welfare plan period	2 years
General Counsel | Change in Control Agreements
Commitments and Contingencies Disclosure [Line Items]
Employee entitlement ratio	1.5
Continued coverage entitlement of welfare plan period	2 years
Advances to Vendor
Commitments and Contingencies Disclosure [Line Items]
Advance to non-affiliates	$ 11,800,000
Notes receivable interest rate	5.00%
Repayment of notes receivable	$ 10,600,000
Notes receivable outstanding	1,200,000
Maximum | Advances to Vendor
Commitments and Contingencies Disclosure [Line Items]
Advance to non-affiliates	12,000,000
Letter of Credit
Commitments and Contingencies Disclosure [Line Items]
Amount drawn under letters of credit	$ 0

Cash Dividends (Detail)

Cash Dividends (Detail) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Dividends Payable [Line Items]
Cash dividends paid, per share	$ 0.40	$ 0.40	$ 0.20
Cash dividends paid	$ 58,775	$ 58,288	$ 29,112
Installment 1, FY 2013
Dividends Payable [Line Items]
Cash dividends paid, date			Mar. 29, 2013
Cash dividends paid, per share			$ 0.05
Cash dividends paid			$ 7,312
Installment 2, FY 2013
Dividends Payable [Line Items]
Cash dividends paid, date			Jun. 28, 2013
Cash dividends paid, per share			$ 0.05
Cash dividends paid			$ 7,361
Installment 3, FY 2013
Dividends Payable [Line Items]
Cash dividends paid, date			Sep. 30, 2013
Cash dividends paid, per share			$ 0.05
Cash dividends paid			$ 7,231
Installment 4, FY 2013
Dividends Payable [Line Items]
Cash dividends paid, date			Dec. 31, 2013
Cash dividends paid, per share			$ 0.05
Cash dividends paid			$ 7,208
Installment 1, FY 2014
Dividends Payable [Line Items]
Cash dividends paid, date		Mar. 27, 2014
Cash dividends paid, per share		$ 0.10
Cash dividends paid		$ 14,456
Installment 2, FY 2014
Dividends Payable [Line Items]
Cash dividends paid, date		Jun. 26, 2014
Cash dividends paid, per share		$ 0.10
Cash dividends paid		$ 14,562
Installment 3, FY 2014
Dividends Payable [Line Items]
Cash dividends paid, date		Sep. 24, 2014
Cash dividends paid, per share		$ 0.10
Cash dividends paid		$ 14,634
Installment 4, FY 2014
Dividends Payable [Line Items]
Cash dividends paid, date		Dec. 24, 2014
Cash dividends paid, per share		$ 0.10
Cash dividends paid		$ 14,636
Installment 1, FY 2015
Dividends Payable [Line Items]
Cash dividends paid, date	Mar. 25, 2015
Cash dividends paid, per share	$ 0.10
Cash dividends paid	$ 14,640
Installment 2, FY 2015
Dividends Payable [Line Items]
Cash dividends paid, date	Jun. 24, 2015
Cash dividends paid, per share	$ 0.10
Cash dividends paid	$ 14,712
Installment 3, FY 2015
Dividends Payable [Line Items]
Cash dividends paid, date	Sep. 24, 2015
Cash dividends paid, per share	$ 0.10
Cash dividends paid	$ 14,712
Installment 4, FY 2015
Dividends Payable [Line Items]
Cash dividends paid, date	Dec. 24, 2015
Cash dividends paid, per share	$ 0.10
Cash dividends paid	$ 14,711

Stockholders' Equity - Addition

Stockholders' Equity - Additional Information (Detail) - USD ($)	Feb. 29, 2016	Dec. 31, 2015	Sep. 06, 2013	Jul. 25, 2012
2012 program | Maximum
Class Of Stock [Line Items]
Amount approved for repurchases under stock buyback program				$ 150,000,000
2013 program
Class Of Stock [Line Items]
Remaining Amount approved for repurchases under stock buyback program		$ 187,000,000
2013 program | Maximum
Class Of Stock [Line Items]
Amount approved for repurchases under stock buyback program			$ 200,000,000
Scenario Forecast | Dividend Declared
Class Of Stock [Line Items]
Dividend declaration date	Feb. 3, 2016
Dividend per share, declared	$ 0.10
Dividend payment date	Mar. 24, 2016
Dividend record date	Mar. 10, 2016

Treasury Stock Acquisition (Det

Treasury Stock Acquisition (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, Shares, Beginning balance	42,818,585	42,268,057	38,146,738
Treasury stock acquired, Shares, Ending balance	43,207,240	42,818,585	42,268,057
Treasury stock acquired, Values, Beginning balance	$ 899,035	$ 880,888	$ 795,051
Treasury stock acquired, Values	8,010	18,147	85,837
Treasury stock acquired, Values, Ending balance	$ 907,045	$ 899,035	$ 880,888
2012 program
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, Shares			2,567,266
Treasury stock acquired, Values			$ 51,107
2013 program
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, Shares	8,618	13,898	602,564
Treasury stock acquired, Values	$ 180	$ 466	$ 12,517
Long Term Incentive Plan
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, Shares	380,037	536,630	951,489
Treasury stock acquired, Values	$ 7,830	$ 17,681	$ 22,213

Company's Share-Based Compensat

Company's Share-Based Compensation Plans (Detail)	Dec. 31, 2015shares
Patterson-UTI Energy, Inc. 2014 Long-Term Incentive Plan
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares Authorized for Grant	9,100,000
Shares Underlying Awards Outstanding	2,509,623
Shares Available for Grant	4,018,824
Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares Underlying Awards Outstanding	5,271,563

Stock-based Compensation - Addi

Stock-based Compensation - Additional Information (Detail) shares in Millions, $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)shares
Employee Stock Option
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options outstanding, aggregate intrinsic value | $	$ 1.7
Options outstanding, weighted-average remaining contractual term	4 years 11 months 27 days
Options exercisable, aggregate intrinsic value | $	$ 1.7
Options exercisable, weighted-average remaining contractual term	4 years 1 month 28 days
Outstanding non-vested options | shares	1.1
Restricted Stock Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding non-vested restricted stock | shares	1.3
Performance Units Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Performance period	3 years
Award description	Generally, the recipients will receive a target number of shares if the Company’s total shareholder return is positive and, when compared to the peer group, is at the 50th percentile and two times the target if at the 75th percentile or higher.
Patterson-UTI Energy, Inc. 2014 Long-Term Incentive Plan | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Option term	10 years
Patterson-UTI Energy, Inc. 2014 Long-Term Incentive Plan | Non Employee Director
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	1 year
Patterson-UTI Energy, Inc. 2014 Long-Term Incentive Plan | Employees
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	3 years
Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended | Non Employee Director | Employee Stock Option
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	1 year
Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended | Non Employee Director | Restricted Stock Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	1 year
Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended | Employees | Employee Stock Option
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	3 years
Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended | Employees | Restricted Stock Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	3 years

Weighted-Average Assumptions Us

Weighted-Average Assumptions Used to Estimate Grant Date Fair Values for Stock Options Granted (Detail) - Employee Stock Option	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Volatility	37.95%	35.89%	41.36%
Expected term (in years)	5 years	5 years	5 years
Dividend yield	2.00%	1.17%	0.89%
Risk-free interest rate	1.37%	1.76%	0.70%

Stock Option Activity (Detail)

Stock Option Activity (Detail)	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Shares
Outstanding at beginning of year | shares	6,086,250
Granted | shares	831,000
Cancelled | shares	(10,000)
Expired | shares	(600,000)
Outstanding at end of year | shares	6,307,250
Exercisable at end of year | shares	5,224,082
Weighted-average exercise price
Outstanding at beginning of year | $ / shares	$ 22.32
Granted | $ / shares	20.06
Cancelled | $ / shares	16.59
Expired | $ / shares	26.06
Outstanding at end of year | $ / shares	21.68
Exercisable at end of year | $ / shares	$ 21.49

Additional Information with Res

Additional Information with Respect to Options Granted, Vested and Exercised (Detail) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Weighted-average grant date fair value of stock options granted (per share)	$ 5.79	$ 9.81	$ 7.59
Aggregate grant date fair value of stock options vested during the year	$ 5,077	$ 5,173	$ 5,240
Aggregate intrinsic value of stock options exercised		$ 21,862	$ 8,683

Additional Information with R70

Additional Information with Respect to Non-vested Shares (Detail) - Employee Stock Option $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Weighted-average remaining contractual term	8 years 11 months 27 days
Weighted-average remaining expected term	3 years 11 months 27 days
Weighted-average remaining vesting period	1 year 10 months 21 days
Unrecognized compensation cost	$ 5.8

Restricted Stock Activity (Deta

Restricted Stock Activity (Detail) - Restricted Stock Awards	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Shares
Outstanding at beginning of year | shares	1,493,059
Granted | shares	795,600
Vested | shares	(774,235)
Forfeited | shares	(82,174)
Outstanding at end of year | shares	1,432,250
Weighted-average Grant Date Fair Value
Outstanding at beginning of year | $ / shares	$ 26.93
Granted | $ / shares	20.58
Vested | $ / shares	24.89
Forfeited | $ / shares	25.89
Outstanding at end of year | $ / shares	$ 24.56

Additional Information on Non-v

Additional Information on Non-vested Restricted Stock (Detail) - Restricted Stock Awards $ in Millions	12 Months Ended
	Dec. 31, 2015USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate intrinsic value	$ 19.9
Weighted-average remaining vesting period	1 year 9 months 18 days
Unrecognized compensation cost	$ 25.1

Restricted Stock Unit Activity

Restricted Stock Unit Activity (Detail) - Restricted Stock Units (RSUs)	12 Months Ended
	Dec. 31, 2015$ / sharesshares
Shares
Outstanding at beginning of year | shares	34,085
Granted | shares	22,100
Vested | shares	(14,499)
Outstanding at end of year | shares	41,686
Weighted-average Grant Date Fair Value
Outstanding at beginning of year | $ / shares	$ 30.20
Granted | $ / shares	20.85
Vested | $ / shares	27.37
Outstanding at end of year | $ / shares	$ 26.22

Stock-Settled Performance Units

Stock-Settled Performance Units (Detail)	12 Months Ended
	Dec. 31, 2015shares
2,015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	190,600
2,014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	154,000
2,013
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	236,500
2,012
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	192,000
2,011
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	144,375
2,010
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	178,750

Stock-Settled Performance Uni75

Stock-Settled Performance Units, Total Shareholder Return Percentiles and Number of Shares Issued (Detail) - Performance Units Awards	12 Months Ended
	Dec. 31, 2015shares
2,012
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Total shareholder return percentile for performance period	87.00%
Shares issued	384,000
2,011
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Total shareholder return percentile for performance period	94.00%
Shares issued	288,750
2,010
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Total shareholder return percentile for performance period	93.00%
Shares issued	357,500

Fair Value of Stock-Settled Per

Fair Value of Stock-Settled Performance Units (Detail) - Performance Units Awards $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)
2,015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	$ 4,052
2,014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	5,388
2,013
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	5,564
2,012
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	3,065
2,011
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	5,569
2,010
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	$ 3,117

Compensation Expense Associated

Compensation Expense Associated with Stock-Settled Performance Units (Detail) - Performance Units Awards - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
2,015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Stock-Settled Performance Units	$ 1,013
2,014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Stock-Settled Performance Units	1,796	$ 1,347
2,013
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Stock-Settled Performance Units	1,855	1,855	$ 1,391
2,012
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Stock-Settled Performance Units	$ 255	1,022	1,022
2,011
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Stock-Settled Performance Units		$ 464	1,856
2,010
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Stock-Settled Performance Units			$ 260

Leases - Additional Information

Leases - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Leases [Abstract]
Rent expense	$ 37.6	$ 51.9	$ 47.4

Summary of Future Minimum Renta

Summary of Future Minimum Rental Payments Under Operating Leases (Detail) $ in Thousands	Dec. 31, 2015USD ($)
Leases [Abstract]
2,016	$ 10,522
2,017	4,969
2,018	4,053
2,019	3,229
2,020	2,734
Thereafter	4,655
Total	$ 30,162

Components of Income Tax Provis

Components of Income Tax Provision (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Federal income tax expense (benefit):
Current	$ (42,020)	$ 39,438	$ 41,558
Deferred	(83,812)	39,673	47,136
Federal Income Tax Expense (Benefit), Continuing Operations, Total	(125,832)	79,111	88,694
State income tax expense (benefit):
Current	(3,480)	3,987	11,733
Deferred	(12,433)	5,292	4,229
State and Local Income Tax Expense (Benefit), Continuing Operations, Total	(15,913)	9,279	15,962
Foreign income tax expense (benefit):
Current	(2,590)	4,521	4,572
Deferred	(3,628)	(1,292)	(796)
Foreign Income Tax Expense (Benefit), Continuing Operations, Total	(6,218)	3,229	3,776
Total income tax expense (benefit):
Current	(48,090)	47,946	57,863
Deferred	(99,873)	43,673	50,569
Total income tax expense (benefit)	$ (147,963)	$ 91,619	$ 108,432

Difference Between Statutory Fe

Difference Between Statutory Federal Income Tax Rate and Effective Income Rate (Detail)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Income Tax Disclosure [Abstract]
Statutory tax rate	35.00%	35.00%	35.00%
State income taxes	2.10%	2.50%	3.70%
Permanent differences	(1.30%)	(1.40%)	(1.50%)
Other differences, net	(2.40%)	(0.10%)	(0.60%)
Effective tax rate	33.40%	36.00%	36.60%

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	Jan. 01, 2010	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2010
Income Taxes [Line Items]
Domestic Production Activities Deduction					9.00%
Permanent difference, domestic production activities deduction		$ 0	$ 8,800,000	$ 10,000,000
Taxable income		$ 0
Other differences related to reconciliation of deferred tax liability		1.00%
Other differences related to reconciliation of tax returns to tax provisions		0.70%
Other deferred tax assets		$ 41,700,000
Federal net operating losses		257,000,000
State net operating losses		237,000,000
Unrecognized tax benefits		$ 0
Increase in deferred tax liabilities due to statutory tax rates in Canada being lower than those in the United States	$ 1,000,000
Increase in deferred tax liabilities due to statutory tax rates in Canada being lower than those in the United States, amortization period		This will be fully amortized by December 31, 2016.
Unremitted foreign earnings		$ 28,400,000
Unrecognized deferred tax liability associated with undistributed foreign earnings		3,800,000
State and Local Jurisdiction | Expire in 2016
Income Taxes [Line Items]
Net operating losses carried forward		603,000
State and Local Jurisdiction | Prior Years
Income Taxes [Line Items]
Net operating losses carried forward		111,000,000
State and Local Jurisdiction | Expire in 2025
Income Taxes [Line Items]
Net operating losses carried forward		2,800,000
State and Local Jurisdiction | Expire in 2026
Income Taxes [Line Items]
Net operating losses carried forward		17,100,000
State and Local Jurisdiction | Expire in 2027
Income Taxes [Line Items]
Net operating losses carried forward		75,000
State and Local Jurisdiction | Expire in 2029
Income Taxes [Line Items]
Net operating losses carried forward		33,200,000
State and Local Jurisdiction | Expire in 2030
Income Taxes [Line Items]
Net operating losses carried forward		27,500,000
State and Local Jurisdiction | Expire in 2031
Income Taxes [Line Items]
Net operating losses carried forward		88,000,000
State and Local Jurisdiction | Expire in 2034
Income Taxes [Line Items]
Net operating losses carried forward		2,000
State and Local Jurisdiction | Expire in 2035
Income Taxes [Line Items]
Net operating losses carried forward		$ 213,900,000
U.S.
Income Taxes [Line Items]
Tax periods open for examination		Tax years ended December 31, 2012 through December 31, 2014
U.S. | Earliest Tax Year
Income Taxes [Line Items]
Tax period open for examination		2,012
U.S. | Latest Tax Year
Income Taxes [Line Items]
Tax period open for examination		2,014
Canada
Income Taxes [Line Items]
Tax periods open for examination		Tax years ended December 31, 2011 through December 31, 2014
Canada | Earliest Tax Year
Income Taxes [Line Items]
Tax period open for examination		2,011
Canada | Latest Tax Year
Income Taxes [Line Items]
Tax period open for examination		2,014

Tax Effect of Significant Tempo

Tax Effect of Significant Temporary Differences Representing Deferred Tax Assets and Liabilities (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Ending Balance	$ 77,926	$ 50,706	$ 47,259
Net Change	27,220	3,447	(17,184)
Beginning Balance	50,706	47,259	64,443
Ending Balance	137,031	66,916	67,201
Net Change	70,115	(285)	3,621
Beginning Balance	66,916	67,201	63,580
Ending Balance	214,354	117,622	114,460
Net Change	96,732	3,162	(13,563)
Beginning Balance	117,622	114,460	128,023
Ending Balance	(1,000,261)	(1,002,576)	(955,065)
Net Change	2,315	(47,511)	(34,183)
Beginning Balance	(1,002,576)	(955,065)	(920,882)
Ending Balance	(1,013,066)	(1,016,207)	(969,372)
Net Change	3,141	(46,835)	(37,006)
Beginning Balance	(1,016,207)	(969,372)	(932,366)
Ending Balance	(798,712)	(898,585)	(854,912)
Net Change	99,873	(43,673)	(50,569)
Beginning Balance	(898,585)	(854,912)	(804,343)
Allowance to reduce deferred tax asset to expected realizable value, Net Change	(603)
December 31	(603)
Net Operating Loss Carryforwards
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Ending Balance	27,887
Net Change	27,887		(18,914)
Beginning Balance			18,914
Ending Balance	77,514	12,464	13,452
Net Change	65,050	(988)	1,690
Beginning Balance	12,464	13,452	11,762
Workers Compensation Allowance
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Ending Balance	28,734	28,310	27,612
Net Change	424	698	2,534
Beginning Balance	28,310	27,612	25,078
Other
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Ending Balance	21,305	22,396	19,647
Net Change	(1,091)	2,749	(804)
Beginning Balance	22,396	19,647	20,451
Ending Balance	20,441	16,047	14,703
Net Change	4,394	1,344	(421)
Beginning Balance	16,047	14,703	15,124
Ending Balance	(12,805)	(13,631)	(14,307)
Net Change	826	676	(2,823)
Beginning Balance	(13,631)	(14,307)	(11,484)
Ending Balance	(13,339)	(15,623)	(15,471)
Net Change	2,284	(152)	(186)
Beginning Balance	(15,623)	(15,471)	(15,285)
Expense associated with employee stock options
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Ending Balance	14,591	14,386	16,208
Net Change	205	(1,822)	1,536
Beginning Balance	14,386	16,208	14,672
Federal benefit of state deferred tax liabilities
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Ending Balance	24,485	24,019	22,838
Net Change	466	1,181	816
Beginning Balance	24,019	22,838	22,022
Property and equipment basis difference
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Ending Balance	(986,922)	(986,953)	(939,594)
Net Change	31	(47,359)	(33,997)
Beginning Balance	$ (986,953)	$ (939,594)	$ (905,597)

Employee Benefits - Additional

Employee Benefits - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Compensation And Retirement Disclosure [Abstract]
Cash contributions to 401(K) plan	$ 7.1	$ 7.2	$ 6.2

Business Segments - Additional

Business Segments - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2015USD ($)RigsSegmentCustomer	Dec. 31, 2014USD ($)Customer	Dec. 31, 2013USD ($)Customer
Segment Reporting Disclosure [Line Items]
Number of reportable business segments | Segment	3
Long-lived assets	$ 3,920,708	$ 4,131,071
Major Customer
Segment Reporting Disclosure [Line Items]
Revenues	$ 244,000		$ 286,000
Number of customers accounted for 10% or more of consolidated revenues | Customer	1	0	1
Major Customer | Revenues | Customer Concentration Risk
Segment Reporting Disclosure [Line Items]
Percentage of sales revenues	13.00%		10.50%
Contract Drilling
Segment Reporting Disclosure [Line Items]
Marketable land-based drilling rigs | Rigs	221
Oil and gas services	$ 1,153,892	$ 1,838,830	$ 1,679,611
Contract Drilling | Canada
Segment Reporting Disclosure [Line Items]
Oil and gas services	37,500	87,500	$ 86,600
Long-lived assets	$ 53,400	$ 57,600

Business Segments - Revenues (D

Business Segments - Revenues (Detail) - 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 Revenue Reconciling Item [Line Items]
Total operating revenues		$ 338,566	$ 422,251	$ 472,761	$ 657,699	$ 901,219	$ 845,628	$ 757,276	$ 678,168	$ 1,891,277	$ 3,182,291	$ 2,716,034
Operating Segments
Segment Reporting Revenue Reconciling Item [Line Items]
Total operating revenues										1,892,950	3,188,472	2,721,301
Operating Segments | Contract Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total operating revenues										1,155,565	1,843,707	1,684,878
Operating Segments | Pressure Pumping
Segment Reporting Revenue Reconciling Item [Line Items]
Total operating revenues										712,454	1,294,569	979,166
Operating Segments | Oil And Natural Gas
Segment Reporting Revenue Reconciling Item [Line Items]
Total operating revenues										24,931	50,196	57,257
Intersegment Elimination
Segment Reporting Revenue Reconciling Item [Line Items]
Total operating revenues	[1]									$ (1,673)	$ (6,181)	$ (5,267)
[1]	Consists of contract drilling and, in 2014, pressure pumping intercompany revenues for services provided to the oil and natural gas exploration and production segment.

Business Segments - Income (Los

Business Segments - Income (Loss) from Continuing Operations Before Income Taxes (Detail) - 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 Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		$ (76,796)	$ (329,515)	$ (24,764)	$ 24,103	$ 106,833	$ 30,291	$ 87,226	$ 58,776	$ (406,972)	$ 283,126	$ 322,191
Net gain on asset disposals	[1]									10,613	15,781	3,384
Interest income										964	979	918
Interest expense, net of amount capitalized										(36,475)	(29,825)	(28,359)
Other										34	3	1,691
Income (loss) before income taxes										(442,449)	254,283	296,441
Operating Segments
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(359,098)	325,450	373,454
Operating Segments | Contract Drilling
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(91,230)	241,851	266,262
Operating Segments | Pressure Pumping
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(254,998)	89,081	87,244
Operating Segments | Oil And Natural Gas
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(12,870)	(5,482)	19,948
Corporate and other
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										$ (58,487)	$ (58,105)	$ (54,647)
[1]	Net gains or losses associated with the disposal of assets relate to corporate strategy decisions of the executive management group. Accordingly, the related gains or losses have been separately presented and excluded from the results of specific segments.

Business Segments - Assets (Det

Business Segments - Assets (Detail) - USD ($) $ in Thousands		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Asset Reconciling Item [Line Items]
Assets		$ 4,533,317	$ 5,394,011	$ 4,687,127
Operating Segments | Contract Drilling
Segment Reporting Asset Reconciling Item [Line Items]
Assets		3,457,044	4,000,576	3,569,588
Operating Segments | Pressure Pumping
Segment Reporting Asset Reconciling Item [Line Items]
Assets		813,704	1,186,010	761,199
Operating Segments | Oil And Natural Gas
Segment Reporting Asset Reconciling Item [Line Items]
Assets		34,073	50,945	58,656
Corporate and other
Segment Reporting Asset Reconciling Item [Line Items]
Assets	[1]	$ 228,496	$ 156,480	$ 297,684
[1]	Corporate and other assets primarily include cash on hand, income tax receivables and certain deferred tax assets.

Business Segments - Depreciatio

Business Segments - Depreciation, Amortization and Improvement (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	$ 864,759	$ 718,730	$ 597,469
Operating Segments | Contract Drilling
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	618,434	524,023	438,728
Operating Segments | Pressure Pumping
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	214,552	147,595	129,984
Operating Segments | Oil And Natural Gas
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	26,301	42,576	24,400
Corporate and other
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	$ 5,472	$ 4,536	$ 4,357

Business Segments - Capital Exp

Business Segments - Capital Expenditures (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Segment Reporting Information [Line Items]
Capital expenditures	$ 743,776	$ 1,052,341	$ 662,461
Operating Segments | Contract Drilling
Segment Reporting Information [Line Items]
Capital expenditures	527,054	771,593	504,508
Operating Segments | Pressure Pumping
Segment Reporting Information [Line Items]
Capital expenditures	197,577	241,359	122,782
Operating Segments | Oil And Natural Gas
Segment Reporting Information [Line Items]
Capital expenditures	16,625	36,683	31,245
Corporate and other
Segment Reporting Information [Line Items]
Capital expenditures	$ 2,520	$ 2,706	$ 3,926

Company's Demand Deposits and T

Company's Demand Deposits and Temporary Cash Investments (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013	Dec. 31, 2012
Risks And Uncertainties [Abstract]
Deposits in FDIC and SIPC-insured institutions under insurance limits	$ 617	$ 636
Deposits in FDIC and SIPC-insured institutions over insurance limits	130,330	1,420
Deposits in foreign banks	15,303	43,664
Total cash and cash equivalents	146,250	45,720
Less outstanding checks and other reconciling items	(32,904)	(2,708)
Cash and cash equivalents	$ 113,346	$ 43,012	$ 249,509	$ 110,723

Concentrations of Credit Risk -

Concentrations of Credit Risk - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Risks And Uncertainties [Abstract]
Provision for bad debts	$ 0	$ 0	$ 0

Estimated Fair Value of Outstan

Estimated Fair Value of Outstanding Debt Balances (Detail) - USD ($) $ in Thousands	Dec. 31, 2015	Dec. 31, 2014
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Carrying value of Debt	$ 855,000	$ 985,500
Fair value of Debt	793,441	943,019
Revolving Credit Facility
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Carrying value of Debt		303,000
Fair value of Debt		303,000
Term Loan Facility
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Carrying value of Debt	70,000	82,500
Fair value of Debt	70,000	82,500
2015 Term Loan
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Carrying value of Debt	185,000
Fair value of Debt	185,000
4.97% Series A Senior Notes, Due October 5th 2020
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Carrying value of Debt	300,000	300,000
Fair value of Debt	279,635	288,346
4.27% Series B Senior Notes, Due June 14th 2022
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Carrying value of Debt	300,000	300,000
Fair value of Debt	$ 258,806	$ 269,173

Fair Values of Financial Inst94

Fair Values of Financial Instruments - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2015	Dec. 31, 2014
4.97% Series A Senior Notes, Due October 5th 2020
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Current market rates used in measuring fair value	6.66%	5.77%
4.27% Series B Senior Notes, Due June 14th 2022
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Current market rates used in measuring fair value	6.95%	6.00%

Quarterly Financial Informati95

Quarterly Financial Information (Detail) - 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
Quarterly Financial Information Disclosure [Abstract]
Operating revenues	$ 338,566	$ 422,251	$ 472,761	$ 657,699	$ 901,219	$ 845,628	$ 757,276	$ 678,168	$ 1,891,277	$ 3,182,291	$ 2,716,034
Operating income (loss)	(76,796)	(329,515)	(24,764)	24,103	106,833	30,291	87,226	58,776	(406,972)	283,126	322,191
Net income (loss)	$ (58,658)	$ (225,978)	$ (18,975)	$ 9,125	$ 57,583	$ 15,976	$ 54,283	$ 34,822	$ (294,486)	$ 162,664	$ 188,009
Net income (loss) per common share:
Basic	$ (0.40)	$ (1.54)	$ (0.13)	$ 0.06	$ 0.39	$ 0.11	$ 0.37	$ 0.24	$ (2)	$ 1.12	$ 1.29
Diluted	$ (0.40)	$ (1.54)	$ (0.13)	$ 0.06	$ 0.39	$ 0.11	$ 0.37	$ 0.24	$ (2)	$ 1.11	$ 1.28

Valuation and Qualifying Acco96

Valuation and Qualifying Accounts (Detail) - Allowance for Doubtful Accounts - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2015	Dec. 31, 2014	Dec. 31, 2013
Valuation And Qualifying Accounts Disclosure [Line Items]
Beginning Balance		$ 3,546	$ 3,674	$ 3,513
Deductions	[1]	(1)	(128)	161
Ending Balance		$ 3,545	$ 3,546	$ 3,674
[1]	Consists of uncollectible accounts (written off) or recovered