Patterson-UTI Energy (PTEN) 10-K 20 Feb 18 2017 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2017	Feb. 16, 2018	Jun. 30, 2017
Document And Entity Information [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2017
Document Fiscal Year Focus	2,017
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		222,286,372
Entity Public Float			$ 4.2

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Current assets:
Cash and cash equivalents	$ 42,828	$ 35,152
Accounts receivable, net of allowance for doubtful accounts of $2,323 and $3,191 at December 31, 2017 and 2016, respectively	580,354	148,091
Federal and state income taxes receivable	1,152	2,126
Inventory	69,167	20,191
Other	53,354	41,322
Total current assets	746,855	246,882
Property and equipment, net	4,254,730	3,408,963
Goodwill and intangible assets	687,072	88,966
Deposits on equipment purchases	16,351	16,050
Deferred tax assets, net	3,875	4,124
Other	49,973	7,306
Total assets	5,758,856	3,772,291
Current liabilities:
Accounts payable	319,621	125,667
Accrued expenses	226,629	139,148
Total current liabilities	546,250	264,815
Borrowings under revolving credit facility	268,000
Long-term debt, net of debt issuance cost of $1,217 and $1,563 at December 31, 2017 and 2016, respectively	598,783	598,437
Deferred tax liabilities, net	350,836	650,661
Other	12,494	9,654
Total liabilities	1,776,363	1,523,567
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 266,259,083 and 191,525,872 issued and 222,456,472 and 148,133,255 outstanding at December 31, 2017 and 2016, respectively	2,662	1,915
Additional paid-in capital	2,785,823	1,042,696
Retained earnings	2,105,897	2,116,341
Accumulated other comprehensive income (loss)	6,822	(1,134)
Treasury stock, at cost, 43,802,611 shares and 43,392,617 shares at December 31, 2017 and 2016, respectively	(918,711)	(911,094)
Total stockholders’ equity	3,982,493	2,248,724
Total liabilities and stockholders’ equity	$ 5,758,856	$ 3,772,291

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Statement Of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 2,323	$ 3,191
Long-term debt, debt issuance cost	$ 1,217	$ 1,563
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	266,259,083	191,525,872
Common stock, outstanding	222,456,472	148,133,255
Treasury stock, shares	43,802,611	43,392,617

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Operating revenues:
Other		$ 70,760,000	$ 18,133,000	$ 24,931,000
Total operating revenues		2,356,684,000	915,866,000	1,891,277,000
Operating costs and expenses:
Contract drilling		667,105,000	305,804,000	608,848,000
Pressure pumping		966,835,000	334,588,000	612,021,000
Directional drilling		32,172,000
Other		51,428,000	8,384,000	11,500,000
Depreciation, depletion, amortization and impairment		783,341,000	668,434,000	864,759,000
Impairment of goodwill				124,561,000
Selling, general and administrative		105,847,000	69,205,000	74,913,000
Merger and integration expenses		74,451,000
Other operating (income) expense, net	[1]	(31,957,000)	(14,323,000)	1,647,000
Total operating costs and expenses		2,649,222,000	1,372,092,000	2,298,249,000
Operating loss		(292,538,000)	(456,226,000)	(406,972,000)
Other income (expense):
Interest income		1,866,000	327,000	964,000
Interest expense, net of amount capitalized		(37,472,000)	(40,366,000)	(36,475,000)
Other		343,000	69,000	34,000
Total other expense		(35,263,000)	(39,970,000)	(35,477,000)
Loss before income taxes		(327,801,000)	(496,196,000)	(442,449,000)
Income tax benefit		(333,711,000)	(177,562,000)	(147,963,000)
Net income (loss)		$ 5,910,000	$ (318,634,000)	$ (294,486,000)
Net income (loss) per common share:
Basic		$ 0.03	$ (2.18)	$ (2)
Diluted		$ 0.03	$ (2.18)	$ (2)
Weighted average number of common shares outstanding:
Basic		198,447	146,178	145,416
Diluted		199,882	146,178	145,416
Cash dividends per common share		$ 0.08	$ 0.16	$ 0.40
Contract Drilling
Operating revenues:
Oil and gas services		$ 1,040,033,000	$ 543,663,000	$ 1,153,892,000
Operating costs and expenses:
Impairment of goodwill				0
Pressure Pumping
Operating revenues:
Oil and gas services		1,200,311,000	$ 354,070,000	$ 712,454,000
Directional Drilling
Operating revenues:
Oil and gas services		$ 45,580,000
[1]	Other operating income (expense), net includes 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. This caption also includes expenses related to certain legal settlements net of insurance reimbursements.

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement Of Income And Comprehensive Income [Abstract]
Net income (loss)	$ 5,910	$ (318,634)	$ (294,486)
Other comprehensive income (loss), net of taxes of $0 for 2017, $0 for 2016 and $0 for 2015:
Foreign currency translation adjustment	7,956	2,959	(10,556)
Total comprehensive income (loss)	$ 13,866	$ (315,675)	$ (305,042)

CONSOLIDATED STATEMENTS OF COM6

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
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 (Loss)	Treasury Stock
Beginning Balance at Dec. 31, 2014	$ 2,905,810	$ 1,893	$ 984,674	$ 2,811,815	$ 6,463	$ (899,035)
Beginning Balance (in shares) at Dec. 31, 2014		189,263,000
Net income (loss)	(294,486)			(294,486)
Foreign currency translation adjustment	(10,556)				(10,556)
Issuance of restricted stock		$ 12	(12)
Issuance of restricted stock (in shares)		1,180,000
Vesting of restricted stock units (in shares)		14,000
Forfeitures of restricted stock		$ (1)	1
Forfeitures of restricted stock (in shares)		(82,000)
Stock-based compensation	28,510		28,510
Tax 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		190,375,000
Net income (loss)	(318,634)			(318,634)
Foreign currency translation adjustment	2,959				2,959
Shares issued for acquisitions	6,733	$ 3	6,730
Shares issued for acquisitions (in shares)		354,000
Issuance of restricted stock		$ 8	(8)
Issuance of restricted stock (in shares)		785,000
Vesting of restricted stock units (in shares)		15,000
Forfeitures of restricted stock (in shares)		(43,000)
Exercise of stock options	707		707
Exercise of stock options (in shares)		40,000
Stock-based compensation	28,324		28,324
Tax expense related to stock-based compensation	(4,868)		(4,868)
Payment of cash dividends	(23,579)			(23,579)
Purchase of treasury stock	(4,049)					(4,049)
Ending Balance at Dec. 31, 2016	$ 2,248,724	$ 1,915	1,042,696	2,116,341	(1,134)	(911,094)
Ending Balance (in shares) at Dec. 31, 2016	191,525,872	191,526,000
Net income (loss)	$ 5,910			5,910
Foreign currency translation adjustment	7,956				7,956
Equity offering	471,570	$ 182	471,388
Equity offering (in shares)		18,170,000
Shares issued for acquisitions	1,226,890	$ 551	1,226,339
Shares issued for acquisitions (in shares)		55,097,000
Issuance of restricted stock		$ 9	(9)
Issuance of restricted stock (in shares)		891,000
Vesting of restricted stock units		$ 5	(5)
Vesting of restricted stock units (in shares)		549,000
Forfeitures of restricted stock (in shares)		(24,000)
Exercise of stock options	$ 931		931
Exercise of stock options (in shares)	50,000	50,000
Stock-based compensation	$ 44,483		44,483
Payment of cash dividends	(16,315)			(16,315)
Dividend equivalents	(39)			(39)
Purchase of treasury stock	(7,617)					(7,617)
Ending Balance at Dec. 31, 2017	$ 3,982,493	$ 2,662	$ 2,785,823	$ 2,105,897	$ 6,822	$ (918,711)
Ending Balance (in shares) at Dec. 31, 2017	266,259,083	266,259,000

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Cash flows from operating activities:
Net income (loss)	$ 5,910	$ (318,634)	$ (294,486)
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion, amortization and impairment	783,341	668,434	864,759
Impairment of goodwill			124,561
Dry holes and abandonments	1,929	58	1,224
Deferred income tax benefit	(330,346)	(152,160)	(99,873)
Stock-based compensation expense	44,483	28,324	28,510
Net gain on asset disposals	(33,510)	(14,771)	(10,613)
Tax expense related to stock-based compensation		(4,868)	(1,362)
Amortization of debt issuance costs	346	2,270	1,245
Changes in operating assets and liabilities:
Accounts receivable	(239,482)	72,327	440,884
Income taxes receivable/payable	990	30,379	49,895
Inventory and other assets	(23,449)	5,664	38,993
Accounts payable	104,072	12,024	(131,649)
Accrued expenses	(14,190)	(24,573)	(10,303)
Other liabilities	617	560	(2,348)
Net cash provided by operating activities	300,711	305,034	999,437
Cash flows from investing activities:
Acquisitions, net of cash acquired	(501,954)	155
Purchases of property and equipment	(567,087)	(119,799)	(743,776)
Proceeds from disposal of assets	60,945	21,889	20,814
Other investments	(2,520)
Net cash used in investing activities	(1,010,616)	(97,755)	(722,962)
Cash flows from financing activities:
Proceeds from equity offering	471,570
Purchases of treasury stock	(6,809)	(3,610)	(8,010)
Dividends paid	(16,315)	(23,579)	(58,775)
Proceeds from long-term debt			200,000
Repayment of long-term debt		(255,000)	(27,500)
Proceeds from borrowings under revolving credit facility	599,000	200,500	54,000
Repayment of borrowings under revolving credit facility	(331,000)	(200,500)	(357,000)
Debt issuance costs		(3,357)	(1,979)
Proceeds from exercise of stock options	123	268
Net cash provided by (used in) financing activities	716,569	(285,278)	(199,264)
Effect of foreign exchange rate changes on cash	1,012	(195)	(6,877)
Net increase (decrease) in cash and cash equivalents	7,676	(78,194)	70,334
Cash and cash equivalents at beginning of year	35,152	113,346	43,012
Cash and cash equivalents at end of year	42,828	35,152	113,346
Net cash (paid) received during the year for:
Interest, net of capitalized interest of $1,175 in 2017, $398 in 2016 and $6,332 in 2015	(34,953)	(36,551)	(33,452)
Income taxes	3,947	52,716	97,333
Non-cash investing and financing activities:
Net increase (decrease) in payables for purchases of property and equipment	17,228	28,926	(167,308)
Issuance of common stock for business acquisition	1,226,890	6,733
Net decrease (increase) in deposits on equipment purchases	$ (301)	$ 6,317	$ 90,012

CONSOLIDATED STATEMENTS OF CAS9

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Statement Of Cash Flows [Abstract]
Interest expense, capitalized interest	$ 1,175	$ 398	$ 6,332

Description of Business and Sum

Description of Business and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2017
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 oil and natural gas operators in the continental United States and western Canada. The Company provides pressure pumping services to oil and natural gas operators primarily in Texas and the Mid-Continent and Appalachian regions. The Company provides directional drilling services in most major producing onshore oil and gas basins in the United States. The Company also provides oilfield rental equipment in many of the major producing onshore oil and gas basins in the United States and manufactures and sells pipe handling components and related technology to drilling contractors in North America and other select markets. In addition, the Company owns and invests, as a non-operating working interest owner, in oil and natural gas assets that are primarily located in Texas and New Mexico. 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 subsidiaries, which use the Canadian dollar as their functional currency. The effects of exchange rate changes are reflected in accumulated other comprehensive income, which is a separate component of stockholders’ equity. In 2017, the Company adopted new guidance for the presentation of deferred tax liabilities and assets and such guidance was applied retrospectively, resulting in the reclassification of $36.4 million from current deferred tax assets as of December 31, 2016. Of this amount, $4.1 million was reclassified to long-term deferred tax assets and $32.3 million was reclassified to long-term deferred tax liabilities. During 2016, the Company determined that certain income and expense items should be classified as “other operating (income) expense, net” in the consolidated statements of operations. This caption now includes gains and losses on asset disposals and expenses related to certain legal settlements. Gains and losses on asset disposals were previously presented as a separate line in the consolidated statements of operations. Expenses related to certain legal settlements were previously included in operating costs of the respective operating segment or within selling, general and administrative expense. For comparative purposes, all such prior period amounts were reclassified to conform to the current presentation, including the Company’s previously disclosed $12.3 million legal settlement that was previously included within selling, general and administrative expense for the year ended December 31, 2015. In addition, the Company changed its reporting segment presentation in 2016, as the Company no longer considers its oil and natural gas exploration and production activities to be significant to an understanding of the Company’s results. The Company now presents the oil and natural gas exploration and production activities, oilfield rental business, pipe handling components and related technology business and Middle East/North Africa activities as “Other” and “Corporate” reflects only corporate activities. This change in segment presentation was applied retrospectively to all periods presented herein (See Note 14). On December 12, 2016, the Company entered into an Agreement and Plan of Merger (the “merger agreement”) with Seventy Seven Energy Inc. (“SSE”), and the merger closed on April 20, 2017 (the “merger date”). The Company’s results include the results of operations of SSE since the merger date (See Note 2). On October 11, 2017, the Company acquired all of the issued and outstanding limited liability company interests of MS Directional, LLC (f/k/a Multi-Shot, LLC) (“MS Directional”). The Company’s results include the results of operations of MS Directional since October 11, 2017 (See Note 2). The acquisition of MS Directional created a new directional drilling reporting segment for the Company (See Note 14). 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 (“U.S. GAAP”) 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 our contract drilling, pressure pumping, directional drilling, oilfield rental and pipe handling components and related technology activities are recognized as services are performed. All of the wells the Company drilled in 2017, 2016 and 2015 were drilled under daywork contracts. Revenue from sales of products are recognized upon customer acceptance. Revenue is presented net of any sales tax charged to the customer that the Company is required to remit to local or state governmental taxing authorities. Reimbursements for the purchase of supplies, equipment, personnel services, shipping and other services that are provided at the request of the Company’s customers are recorded as revenue when incurred. The related costs are recorded as operating expenses when incurred. 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 and materials used in its directional drilling and drilling technology business. Such inventories are stated at the lower of cost or market, with cost determined using the average cost method. Other current assets — Other current assets includes reimbursement from the Company’s workers compensation insurance carrier for claims in excess of the Company’s deductible in the amount of $30.0 million and $21.1 million at December 31, 2017 and 2016, respectively. 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 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. 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. 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 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. 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, 2017, 2016 and 2015, 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): 2017 2016 2015 BASIC EPS: Net income (loss) $ 5,910 $ (318,634 ) $ (294,486 ) Adjust for (income) loss attributed to holders of non-vested restricted stock (170 ) — 3,022 Income (loss) attributed to common stockholders $ 5,740 $ (318,634 ) $ (291,464 ) Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 198,447 146,178 145,416 Basic net income (loss) per common share $ 0.03 $ (2.18 ) $ (2.00 ) DILUTED EPS: Income (loss) attributed to common stockholders $ 5,740 $ (318,634 ) $ (291,464 ) Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 198,447 146,178 145,416 Add dilutive effect of potential common shares 1,435 — — Weighted average number of diluted common shares outstanding 199,882 146,178 145,416 Diluted net income (loss) per common share $ 0.03 $ (2.18 ) $ (2.00 ) Potentially dilutive securities excluded as anti-dilutive 3,289 9,057 7,781 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. On December 22, 2017, significant changes were enacted to U.S. tax law (“tax reform”). One of the provisions of tax reform is the introduction of a new U.S. tax on certain off-shore earnings referred to as Global Intangible Low-Taxed Income (“GILTI”) at an effective tax rate of 10.5% (in the case of a corporation) for tax years beginning after December 31, 2017 (increasing to 13.125% for tax years beginning after December 31, 2025) with a partial offset for any related foreign tax credits. The Company is still evaluating the GILTI provisions of tax reform and its impact, if any, on the Company’s consolidated financial statements at December 31, 2017. The Financial Accounting Standards Board (“FASB”) staff allowed companies to adopt an accounting policy to either provide deferred taxes for GILTI or treat it as a tax cost in the year incurred. The Company has not yet determined its accounting policy because determining the impact of the GILTI provisions requires analysis of its existing legal entity structure, the reversal of its U.S. GAAP and U.S. tax basis differences in the assets and liabilities of its foreign subsidiaries, and its ability to offset any tax with foreign tax credits. As such, the Company did not record a deferred income tax expense or benefit related to the GILTI provisions in its consolidated statement of operations for the year ended December 31, 2017 and will finalize its evaluation of the GILTI provisions during the measurement period provided under Staff Accounting Bulletin (“SAB”) 118. 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). As share-based compensation expense recognized in the consolidated statements of operations is based on awards ultimately expected to vest, it has been reduced for estimated forfeitures, based on historical experience. Forfeitures are estimated at the time of grant and revised in subsequent periods if actual forfeitures differ from those estimates. 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 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, 2017. The Company adopted this new revenue guidance effective January 1, 2018, utilizing the modified retrospective method, and will expand its consolidated financial statement disclosures in order to comply with the update. The adoption of this update did not have a material impact on the Company’s consolidated financial statements. In February 2016, the FASB issued an accounting standards update to provide guidance for the accounting for leasing transactions. The standard requires the lessee to recognize a lease liability along with a right-of-use asset for all leases with a term longer than one year. A lessee is permitted to make an accounting policy election by class of underlying asset to not recognize the lease liability and related right-of-use asset for leases with a term of one year or less. The provisions of this standard also apply to situations where the Company is the lessor. The requirements in this update are effective during interim and annual periods beginning after December 15, 2018. The Company previously disclosed its intention to adopt this standard at the same time as it adopted the new revenue standard discussed above; however, the Company now expects to adopt this new guidance in the first quarter of 2019. The Company is currently evaluating the impact that this new guidance will have on its 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. This guidance became effective for the Company during the three months ended March 31, 2017. The adoption of this update was applied retrospectively, resulting in the reclassification of $36.4 million from current deferred tax assets as of December 31, 2016. Of this amount, $4.1 million was reclassified to long-term deferred tax assets and $32.3 million was reclassified to long-term deferred tax liabilities. In March 2016, the FASB issued an accounting standards update to provide guidance for the accounting for share-based payment transactions, including the related income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. This guidance became effective for the Company during the three months ended March 31, 2017. The Company believes this guidance has caused and will continue to cause volatility in its effective tax rates and diluted earnings per share due to the tax effects related to share-based payments being recorded in the statement of operations. The volatility in future periods will depend on the Company’s stock price and the number of shares that vest in the case of restricted stock, restricted stock units and performance stock units, or the number of shares that are exercised in the case of stock options. In August 2016, the FASB issued an accounting standard to clarify the presentation of cash receipts and payments in specific situations on the statement of cash flows. The requirements in this update are effective during interim and annual periods beginning after December 15, 2017. The adoption of this update on January 1, 2018 did not have a material impact on the Company’s consolidated financial statements. In January 2017, the FASB issued an accounting standards update to eliminate Step 2 from the goodwill impairment test. An entity will now perform its annual or interim goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value, but the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. The requirements in this update are effective during interim and annual periods in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates on or after January 1, 2017. The Company adopted this update in 2017, which did not have a material impact on the Company’s consolidated financial statements. In May 2017, the FASB issued an accounting standards update that provided clarity on which changes to the terms or conditions of share-based payment awards require an entity to apply modification accounting provisions. The requirements in this update are effective during interim and annual periods in fiscal years beginning after December 15, 2017. The adoption of this update on January 1, 2018 did not have a material impact on the Company’s consolidated financial statements.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2017
Business Combinations [Abstract]
Acquisitions	2. Acquisitions SSE On April 20, 2017, pursuant to the merger agreement, a subsidiary of the Company was merged with and into SSE, with SSE continuing as the surviving entity and one of the Company’s wholly owned subsidiaries (the “SSE merger”). Pursuant to the terms of the merger agreement, the Company acquired all of the issued and outstanding shares of common stock of SSE, in exchange for approximately 46.3 million shares of common stock of the Company. Concurrent with the closing of the merger, the Company repaid all of the outstanding debt of SSE totaling $472 million. Based on the closing price of the Company’s common stock on April 20, 2017, the total fair value of the consideration transferred to effect the acquisition of SSE was approximately $1.5 billion. On April 20, 2017, following the SSE merger, SSE was merged with and into a newly-formed subsidiary of the Company named Seventy Seven Energy LLC (“SSE LLC”), with SSE LLC continuing as the surviving entity and one of the Company’s wholly owned subsidiaries. Through the SSE merger, the Company acquired a fleet of 91 drilling rigs, 36 of which the Company considers to be APEX® rigs. Additionally, through the SSE merger, the Company acquired approximately 500,000 horsepower of modern, efficient fracturing equipment. The oilfield rentals business acquired through the SSE merger has a modern, well-maintained fleet of premium rental tools, and it provides specialized services for land-based oil and natural gas drilling, completion and workover activities. The merger has been accounted for as a business combination using the acquisition method. Under the acquisition method of accounting, the fair value of the consideration transferred is allocated to the tangible and intangible assets acquired and the liabilities assumed based on their estimated fair values as of the acquisition date, with the remaining unallocated amount recorded as goodwill. Merger and integration expenses incurred by the Company related to the SSE merger were $69.5 million. The total fair value of the consideration transferred was determined as follows (in thousands, except stock price): Shares of Company common stock issued to SSE shareholders 46,298 Company common stock price on April 20, 2017 $ 22.45 Fair value of common stock issued $ 1,039,396 Plus SSE long-term debt repaid by Company $ 472,000 Total fair value of consideration transferred $ 1,511,396 The final determination of the fair value of assets acquired and liabilities assumed at the merger date will be completed as soon as possible, but no later than one year from the merger date (the “measurement period”). The Company’s preliminary purchase price allocation is subject to revision as additional information about the fair value of assets and liabilities becomes available. Additional information that existed as of the merger date, but at the time was unknown to the Company, may become known to the Company during the remainder of the measurement period. The final determination of fair value may differ materially from these preliminary estimates. The following table represents the preliminary allocation of the total purchase price of SSE to the assets acquired and the liabilities assumed based on the fair value at the merger date, with the excess of the purchase price over the estimated fair value of the identifiable net assets acquired recorded as goodwill (in thousands): Identifiable assets acquired Cash and cash equivalents $ 37,806 Accounts receivable 149,659 Inventory 8,518 Other current assets 19,038 Property and equipment 984,433 Other long-term assets 20,918 Intangible assets 22,500 Total identifiable assets acquired 1,242,872 Liabilities assumed Accounts payable and accrued liabilities 133,415 Deferred income taxes 32,881 Other long-term liabilities 1,734 Total liabilities assumed 168,030 Net identifiable assets acquired 1,074,842 Goodwill 436,554 Total net assets acquired $ 1,511,396 The goodwill reflected above has decreased $1.9 million from the original preliminary purchase price allocation as a result of measurement period adjustments, primarily related to a valuation adjustment to a long-term asset offset by valuation adjustments to accounts payable and accrued liabilities and deferred income taxes. The acquired goodwill is not deductible for tax purposes. Among the factors that contributed to a purchase price resulting in the recognition of goodwill was SSE’s reputation as an experienced provider of high-quality contract drilling and pressure pumping services in a safe and efficient manner. See Note 5 for a breakdown of goodwill acquired by operating segment. A portion of the fair value consideration transferred has been provisionally assigned to identifiable intangible assets as follows: Fair Value Weighted Average Useful Life (in thousands) (in years) Assets Favorable drilling contracts $ 22,500 0.83 MS Directional On October 11, 2017, the Company acquired all of the issued and outstanding limited liability company interests of MS Directional. The aggregate consideration paid by the Company consisted of $69.8 million in cash and approximately 8.8 million shares of the Company’s common stock. The purchase price is subject to customary post-closing adjustments relating to cash, net working capital and indebtedness of MS Directional as of the closing. Based on the closing price of the Company’s common stock on the closing date of the transaction, the total fair value of the consideration transferred to effect the acquisition of MS Directional was approximately $257 million. MS Directional is a leading directional drilling services company in the United States, with operations in most major producing onshore oil and gas basins. MS Directional provides a comprehensive suite of directional drilling services, including directional drilling, downhole performance motors, directional surveying, measurement while drilling, and wireline steering tools. The acquisition has been accounted for as a business combination using the acquisition method. Under the acquisition method of accounting, the fair value of the consideration transferred is allocated to the tangible and intangible assets acquired and the liabilities assumed based on their estimated fair values as of the acquisition date, with the remaining unallocated amount recorded as goodwill. Merger and integration expenses incurred by the Company related to this acquisition amounted to $5.0 million. The total fair value of the consideration transferred was determined as follows (in thousands, except stock price): Shares of Company common stock issued to MS Directional shareholders 8,798 Company common stock price on October 11, 2017 $ 21.31 Fair value of common stock issued $ 187,494 Plus MS Directional long-term debt repaid by Company $ 63,000 Plus cash to sellers $ 6,781 Total fair value of consideration transferred $ 257,275 The final determination of the fair value of assets acquired and liabilities assumed at the acquisition date will be completed as soon as possible, but no later than one year from the acquisition date (the “measurement period”). The Company’s preliminary purchase price allocation is subject to revision as additional information about the fair value of assets and liabilities becomes available. Additional information that existed as of the acquisition date, but at the time was unknown to the Company, may become known to the Company during the remainder of the measurement period. The final determination of fair value may differ materially from these preliminary estimates. The following table represents the preliminary allocation of the total purchase price of MS Directional to the assets acquired and the liabilities assumed based on the fair value at the merger date, with the excess of the purchase price over the estimated fair value of the identifiable net assets acquired recorded as goodwill (in thousands): Identifiable assets acquired Cash and cash equivalents $ 2,021 Accounts receivable 42,782 Inventory 28,060 Other current assets 155 Property and equipment 63,998 Other long-term assets 318 Intangible assets 74,682 Total identifiable assets acquired 212,016 Liabilities assumed Accounts payable and accrued liabilities 43,099 Other long-term liabilities 327 Total liabilities assumed 43,426 Net identifiable assets acquired 168,590 Goodwill 88,685 Total net assets acquired $ 257,275 The acquired goodwill is deductible for tax purposes. Among the factors that contributed to a purchase price resulting in the recognition of goodwill was MS Directional’s reputation as an experienced provider of high-quality directional drilling services in a safe and efficient manner. All of the goodwill acquired is attributable to the direction drilling operating segment (See Note 5). A portion of the fair value consideration transferred has been provisionally assigned to identifiable intangible assets as follows: Fair Value Weighted Average Useful Life (in thousands) (in years) Assets Developed technology $ 48,000 10.00 Customer relationships 26,200 3.00 Internal use software 482 5.00 $ 74,682 7.51 Pro Forma The results of SSE’s operations since the SSE merger date of April 20, 2017 and the results of MS Directional since the acquisition date of October 11, 2017 are included in our consolidated statement of operations. It is impractical to quantify the contribution of the SSE operations since the merger, as the contract drilling and pressure pumping businesses were fully integrated into the Company’s existing operations in 2017. The contribution of MS Directional since the date of the acquisition is reflected as the Company’s directional drilling segment, as disclosed in Note 14. The following pro forma condensed combined financial information was derived from the historical financial statements of the Company, SSE and MS Directional and gives effect to the acquisitions as if they had occurred on January 1, 2016. The below information reflects pro forma adjustments based on available information and certain assumptions the Company believes are reasonable, including (i) adjustments related to the depreciation and amortization of the fair value of acquired intangibles and fixed assets, (ii) removal of the historical interest expense of the acquired entities, (iii) the tax benefit of the aforementioned pro forma adjustments, and (iv) adjustments related to the common shares outstanding to reflect the impact of the consideration exchanged in the acquisitions. Additionally, the pro forma loss for the year ended December 31, 2017 was adjusted to exclude the Company’s merger and integration-related costs of $74.5 million and SSE’s merger related costs of $36.7 million with a corresponding inclusion in the net loss for the year ended December 31, 2016 to give effect as if the acquisitions had occurred on January 1, 2016. The pro forma results of operations do not include any cost savings or other synergies that may result from the SSE merger or MS Directional acquisition. The pro forma results of operations also do not include any estimated costs that have been or will be incurred by the Company to integrate the SSE and MS Directional operations. The pro forma condensed combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the SSE merger and MS Directional acquisition taken place on January 1, 2016; furthermore, the financial information is not intended to be a projection of future results. The following table summarizes selected financial information of the Company on a pro forma basis (in thousands, except per share data): 2017 2016 (Unaudited) Revenues $ 2,738,579 $ 1,567,141 Net income (loss) $ 29,584 $ (505,413 ) Net income (loss) per share Basic $ 0.13 $ (2.30 ) Diluted $ 0.13 $ (2.30 ) Warrior Rig Ltd During September 2016, the Company issued 353,804 shares of its common stock, valued at $6.7 million, in connection with the acquisition of Warrior Rig Ltd. and certain related entities (“Warrior”). Based in Calgary, Warrior manufactures and sells pipe handling components and related technology for drilling contractors in North America and other select markets. This acquisition was not material to the Company’s consolidated financial statements.

Inventory

Inventory	12 Months Ended
	Dec. 31, 2017
Inventory Disclosure [Abstract]
Inventory	3. Inventory Inventory consisted of the following at December 31, 2017 and 2016 (in thousands). 2017 2016 Finished goods $ 2,270 $ — Work-in-process 529 1,803 Raw materials and supplies 66,368 18,388 Inventory $ 69,167 $ 20,191

Property and Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2017
Property Plant And Equipment [Abstract]
Property and Equipment	4. Property and Equipment Property and equipment consisted of the following at December 31, 2017 and 2016 (in thousands): 2017 2016 Equipment $ 8,066,404 $ 6,809,129 Oil and natural gas properties 211,566 201,568 Buildings 185,475 97,029 Land 26,593 22,270 Total property and equipment 8,490,038 7,129,996 Less accumulated depreciation, depletion and impairment (4,235,308 ) (3,721,033 ) Property and equipment, net $ 4,254,730 $ 3,408,963 Depreciation, depletion, amortization and impairment — The following table summarizes depreciation, depletion, amortization and impairment expense related to property and equipment and intangible assets and liabilities for 2017, 2016 and 2015 (in thousands): 2017 2016 2015 Depreciation and impairment expense $ 753,510 $ 657,571 $ 845,543 Amortization expense 21,764 3,643 3,643 Depletion expense 8,067 7,220 15,573 Total $ 783,341 $ 668,434 $ 864,759 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 are retired. In 2017, the Company r ecorded an impairment charge of $29.0 million for the write-down of drilling equipment with no continuing utility as a result of the upgrade of certain rigs to super-spec capability. 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 2017 or 2016. The Company reviews its long-lived assets, including property and equipment, for impairment whenever events or changes in circumstances indicate that their carrying amounts of certain assets may not be recovered over their estimated remaining useful lives (“triggering events”). In connection with this review, assets are grouped at the lowest level at which identifiable cash flows are largely independent of other asset groupings. The Company estimates future cash flows over the life of the respective assets or asset groupings in its assessment of impairment. These estimates of cash flows are based on historical cyclical trends in the industry as well as the Company’s expectations regarding the continuation of these trends in the future. Provisions for asset impairment are charged against income when estimated future cash flows, on an undiscounted basis, are less than the asset’s net book value. Any provision for impairment is measured at fair value. Based on current commodity prices, the Company’s results of operations for the year ended December 31, 2017 and management’s expectations of operating results in future periods, the Company concluded that no triggering events occurred during the year ended December 31, 2017 with respect to its reporting segments. The Company’s expectations of future operating results were based on the assumption that activity levels in all segments and in the Company’s other operations will remain relatively stable or improve in response to relatively stable or increasing oil prices. The Company concluded that no triggering events occurred during the year ended December 31, 2016 with respect to its reporting segments based on the Company’s results of operations for the year ended December 31, 2016, management’s expectations of operating results in future periods and the prevailing commodity prices at the time. During the third quarter of 2015, oil prices declined and averaged $46.42 per barrel, reaching a new low for 2015 of $38.22 per barrel in August 2015. In light of these lower oil prices in August 2015, 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 once again assess the recoverability of long-lived assets groups for both contract drilling and pressure pumping. The Company performed a Step 1 analysis 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 would 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.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2017
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	5. Goodwill and Intangible Assets Goodwill — Goodwill by operating segment as of December 31, 2017 and 2016 and changes for the years then ended are as follows (in thousands): Contract Pressure Directional Oilfield Drilling Pumping Drilling Rental Total Balance December 31, 2015 and 2016 $ 86,234 $ — $ — $ — $ 86,234 Goodwill acquired 308,826 121,444 88,685 6,284 525,239 Balance December 31, 2017 $ 395,060 $ 121,444 $ 88,685 $ 6,284 $ 611,473 There were no accumulated impairment losses related to goodwill as of December 31, 2017 or 2016. 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 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 this is the case, any necessary goodwill impairment is determined using a quantitative impairment test. From time to time, the Company may perform quantitative testing for goodwill impairment in lieu of performing the qualitative assessment. 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 such shortfall. In January 2017, the FASB issued an accounting standards update to eliminate Step 2 from the goodwill impairment test. An entity will now perform its annual or interim goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value, but the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. The Company adopted this update in 2017. Prior to adoption the Company first determined whether it was more likely than not that the fair value of a reporting unit was less than its carrying value after considering qualitative, market and other factors, and if so, the resulting goodwill impairment was determined using a two-step quantitative impairment test. The first step of the quantitative testing was 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 exceeded its fair value, the second step of the quantitative testing was performed whereby the fair value of the reporting unit was 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 was less than the carrying value of goodwill, an impairment loss was recognized in the amount of such shortfall. In connection with its annual goodwill impairment assessment as of December 31, 2017 and 2016, the Company determined based on an assessment of qualitative factors that it was more likely than not that the fair values of its reporting units were greater than the respective carrying amount. In making this determination, the Company considered the current and expected levels of commodity prices for oil and natural gas, which influence the overall level of business activity in its reporting units, as well as the Company’s operating results for 2017 and 2016 and forecasted operating results for the respective succeeding year. Management also considered the Company’s overall market capitalization at December 31, 2017 and 2016. During the third quarter of 2015, oil prices declined and averaged $46.42 per barrel, reaching a new low for 2015 of $38.22 per barrel in August 2015. In light of these 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. As a result 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 its contract drilling and pressure pumping services, the Company performed a quantitative Step 1 impairment assessment of its goodwill as of September 30, 2015. In completing the Step 1 assessment, the fair value of each reporting unit was estimated using both the income and market valuation methods. The estimate of fair value for 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 Step 1 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 third quarter of 2015, the Company recognized an impairment charge of $125 million associated with the impairment of all of the goodwill in its pressure pumping reporting unit. In connection with its annual impairment asset at December 31, 2015, the Company performed a quantitative Step 1 impairment assessment of the goodwill in its contract drilling reporting unit. In completing the Step 1 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 quantitative Step 1 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. Intangible Assets — In 2017, intangible assets were recorded in the Company’s directional drilling operating segment with the acquisition of MS Directional and in the contract drilling operating segment with the SSE merger (See Note 2). In addition, intangible assets were recorded in the pressure pumping operating segment in connection with the 2010 acquisition of the assets of a pressure pumping business. The Company’s intangible assets were recorded at fair value on the date of acquisition and are amortized on a straight line basis. The following table identifies the segment and weighted average useful life of each of the Company’s intangible assets: Weighted Average Segment Useful Life (in years) Customer relationships Pressure pumping 7.00 Customer relationships Directional drilling 3.00 Developed technology Directional drilling 10.00 Favorable drilling contracts Contract drilling 0.83 Internal use software Directional drilling 5.00 The Company concluded that no triggering events necessitating an impairment assessment of the intangible assets had occurred in 2017, 2016 or 2015. The assessment of the recoverability of the respective operating segments asset group included the respective intangible assets, and no impairment was indicated. The gross carrying amount and accumulated amortization of intangible assets as of December 31, 2017 and 2016 are as follows (in thousands): 2017 2016 Gross Carrying Accumulated Net Carrying Gross Carrying Accumulated Net Carrying Amount Amortization Amount Amount Amortization Amount Customer relationships $ 26,200 $ (1,943 ) $ 24,257 $ 25,500 $ (22,768 ) $ 2,732 Developed technology 48,000 (1,137 ) 46,863 — — — Favorable drilling contracts 22,500 (18,482 ) 4,018 — — — Internal use software 482 (21 ) 461 — — — $ 97,182 $ (21,583 ) $ 75,599 $ 25,500 $ (22,768 ) $ 2,732 Amortization expense on intangible assets of approximately $24.3 million, $3.6 million and $3.6 million for the years ended December 31, 2017, 2016 and 2015, respectively. The remaining amortization expense associated with finite-lived intangible assets is expected to be as follows (in thousands): Year ending December 31, 2018 $ 17,580 2019 13,630 2020 11,686 2021 4,896 2022 4,875 Thereafter 22,932 Total $ 75,599

Accrued Expenses

Accrued Expenses	12 Months Ended
	Dec. 31, 2017
Payables And Accruals [Abstract]
Accrued Expenses	6. Accrued Expenses Accrued expenses consisted of the following at December 31, 2017 and 2016 (in thousands): 2017 2016 Salaries, wages, payroll taxes and benefits $ 50,443 $ 21,138 Workers’ compensation liability 80,751 67,775 Property, sales, use and other taxes 29,332 6,766 Insurance, other than workers’ compensation 10,816 9,566 Accrued interest payable 7,558 6,740 Accrued merger and integration 16,101 — Other 31,628 27,163 $ 226,629 $ 139,148

Long Term Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2017
Debt Disclosure [Abstract]
Long Term Debt	7. Long-Term Debt 2012 Credit Agreement — On September 27, 2012, the Company entered into a Credit Agreement (“Base 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 Base Credit Agreement (as amended, the “Credit Agreement”) is a committed senior unsecured credit facility that includes a revolving credit facility. On July 8, 2016, the Company entered into Amendment No. 2 to the Credit Agreement (Amendment No. 2”), which amended the Base Credit Agreement to, among other things, make borrowings under the revolving credit facility subject to a borrowing base calculated by reference to the Company’s and certain of its subsidiaries’ eligible equipment, inventory, accounts receivable and unencumbered cash as described in Amendment No. 2. The revolving credit facility contains a letter of credit facility that is limited to $50 million and a swing line facility that is limited to $20 million, in each case outstanding at any time. The maturity date under the Base Credit Agreement was September 27, 2017 for the revolving credit facility; however, Amendment No. 2 extended the maturity date of $357.9 million in revolving credit commitments of certain lenders to March 27, 2019. On January 17, 2017, the Company entered into Amendment No. 3 to Credit Agreement, which amended the Credit Agreement by restating the definition of Consolidated EBITDA to provide for the add-back of transaction expenses related to the SSE merger. On January 24, 2017, the Company entered into an agreement with certain lenders under its revolving credit facility to increase the aggregate commitments under its revolving credit facility to approximately $595.8 million, subject to the satisfaction of certain conditions. The aggregate commitment increase became effective on April 20, 2017 upon the consummation of the SSE merger and the repayment and termination of the SSE credit facility. On April 20, 2017, the Company entered into Amendment No. 4 to Credit Agreement which permitted outstanding letters of credit under the SSE credit facility to be deemed to be incurred under the Company’s credit facility and increased the amount of the accordion feature of the Company’s revolving credit facility to permit aggregate commitments to be increased to an amount not to exceed $700 million (subject to satisfaction of certain conditions and the procurement of additional commitments from new or existing lenders). On April 20, 2017, the Company also entered into an additional commitment increase agreement with certain of its lenders pursuant to which total commitments available under the Company’s revolving credit facility (after giving effect to both commitment increases) increased to $632 million through September 2017 and to $490 million through March 2019. On October 27, 2017, the Company entered into an additional commitment increase agreement with certain of its lenders pursuant to which total commitments available under the Company’s revolving credit facility increased to $500 million through March 27, 2019. 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. Until September 27, 2017, the applicable margin on LIBOR rate loans varied from 2.75% to 3.25% and the applicable margin on base rate loans varied from 1.75% to 2.25%, in each case determined based upon the Company’s debt to capitalization ratio. Beginning September 27, 2017, the applicable margin on LIBOR rate loans varies from 3.25% to 3.75% and the applicable margin on base rate loans varies from 2.25% to 2.75%, in each case determined based on the Company’s excess availability under the credit facility. At December 31, 2017, the applicable margin on LIBOR rate loans was 3.50% and the applicable margin on base rate loans was 2.50%. A letter of credit fee is payable by the Company equal to the applicable margin for LIBOR rate loans times the amount available to be drawn under outstanding letters of credit. The commitment fee rate payable to the lenders for the unused portion of the credit facility is 0.50%. Each domestic subsidiary of the Company unconditionally guarantees 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 40%. 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 its 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, 2017. The Credit Agreement limits the Company’s ability to make investments in foreign subsidiaries or joint ventures such that, if the book value of all such investments since September 27, 2012 is above 20% of the total consolidated book value of the assets of the Company and its subsidiaries on a pro forma basis, the Company will not be able to make such investment. The Credit Agreement also restricts the Company’s ability to pay dividends and make equity repurchases, subject to certain exceptions, including an exception allowing such restricted payments if before and immediately after giving effect to such restricted payment, the Pro Forma Debt Service Coverage Ratio (as defined in the Credit Agreement) is at least 1.50 to 1.00. In addition, the Credit Agreement requires that, if the consolidated cash balance of the Company and its subsidiaries, subject to certain exclusions, is more than $100 million at the end of the day on which a borrowing is made, the Company can only use the proceeds from such borrowing to fund acquisitions, capital expenditures and the repurchase of indebtedness, and if such proceeds are not used in such manner within three business days, the Company must repay such unused proceeds on the fourth business day following such borrowings. 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, 2017, the Company had $268 million outstanding under the revolving credit facility at a weighted average interest rate of 5.71%. The Company had $4.6 million in letters of credit outstanding under its revolving credit facility at December 31, 2017 and, as a result, had available borrowing capacity of $227 million at that date. 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, 2017, the Company had $54.9 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. Series A & B 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 its 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, 2017. 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. 2028 Senior Notes – On January 19, 2018, the Company completed its offering of $525 million aggregate principal amount of the Company’s 2028 Notes initially guaranteed on a senior unsecured basis by certain of its subsidiaries. The net proceeds before offering expenses were approximately $521 million of which the Company used $239 million to repay amounts outstanding under its revolving credit facility. The Company intends to use the remainder of the net proceeds for general corporate purposes. The Company pays interest on the 2028 Notes on February 1 and August 1 of each year. The 2028 Notes will mature on February 1, 2028. The 2028 Notes bear interest at a rate of 3.95% per annum. The 2028 Notes are The Company, at its option, may redeem the Notes in whole or part, at any time or from time to time at a redemption price equal to 100% of the principal amount The indenture pursuant to which the 2028 Notes were issued includes covenants that, among other things, limit the Company and its subsidiaries’ ability to incur Upon the occurrence of a change of control, as defined in the indenture, each holder of the 2028 Notes may require the Company to purchase all or a portion The indenture The Company incurred approximately $6.0 million in debt issuance costs in connection with the Credit Agreement. The Company incurred approximately $1.9 million in debt issuance costs in connection with the Series A Notes and approximately $1.6 million in debt issuance costs in connection with the Series B Notes Presented below is a schedule of the principal repayment requirements of long-term debt by fiscal year as of December 31, 2017 (in thousands): Year ending December 31, 2018 $ — 2019 268,000 2020 300,000 2021 — 2022 300,000 Thereafter — Total $ 868,000

Commitments, Contingencies and

Commitments, Contingencies and Other Matters	12 Months Ended
	Dec. 31, 2017
Commitments And Contingencies Disclosure [Abstract]
Commitments, Contingencies and Other Matters	8. Commitments, Contingencies and Other Matters Commitments – As of December 31, 2017, the Company maintained letters of credit in the aggregate amount of $59.5 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, 2017, no amounts had been drawn under the letters of credit. As of December 31, 2017, the Company had commitments to purchase approximately $172 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. As of December 31, 2017, the remaining obligation under these agreements was approximately $140 million, of which materials with a total purchase price of approximately $35.9 million are required to be purchased during 2018. 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. Contingencies – 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. In addition, certain states, including Louisiana, New Mexico, Texas and Wyoming, have enacted statutes generally referred to as “oilfield anti-indemnity acts” expressly prohibiting certain indemnity agreements contained in or related to oilfield service agreements. Such oilfield anti-indemnity acts may restrict or void a party’s indemnification of the Company. 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 deductible on its general liability coverage and a $2.0 million per occurrence deductible on its automobile liability insurance coverage. The Company also self-insures a number of other risks, including loss of earnings and business interruption and cyber risks, and does not carry a significant amount of insurance to cover risks of underground reservoir damage. On January 22, 2018, an accident at a drilling site in Pittsburg County, Oklahoma resulted in the losses of life of five people, including three of the Company’s employees. Based on the information the Company has available as of the date of this Report, the Company believes that it has adequate insurance to cover any losses, excluding the applicable insurance deductibles and investigation-related expenses. However, if this accident is not, or another 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. 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 and one of its Executive Vice Presidents (the “Specified Employees”). Each Change in Control Agreement generally has an initial term with automatic twelve-month renewals unless the Company notifies the Specified 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 Specified 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 Specified Employee for good reason (as those terms are defined in the Change in Control Agreements), then the Specified 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 Specified 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) or 2 times (in the case of the Executive Vice President) of the sum of (i) the highest annual salary in effect for such Specified Employee and (ii) the average of the three annual bonuses earned by the Specified 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) or two years (in the case of the Executive Vice President). Each Change in Control Agreement provides the Specified 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. The Company has Employment Agreements with its Chief Executive Officer, Chief Financial Officer, General Counsel and the President of the Company’s subsidiary, Patterson-UTI Drilling Company LLC (“Patterson-UTI Drilling”). In the case of the Chief Executive Officer and the General Counsel, the Employment Agreement supersedes the prior Change in Control Agreement with each executive and, in the case of the President of Patterson-UTI Drilling, the Employment Agreement supersedes his prior employment agreement. Each Employment Agreement generally has an initial three-year term, subject to automatic annual renewal. The executive may terminate his employment under his Employment Agreement by providing written notice of such termination at least 30 days before the effective date of such termination. Under specified circumstances, the Company may terminate the executive’s employment under his Employment Agreement for Cause (as defined in the Employment Agreement) by either (i) providing written notice 10 days before the effective date of such termination and by granting at least 10 days to cure the cause for such termination or (ii) by providing written notice of such termination at least 30 days before the effective date of such termination and by granting at least 20 days to cure the cause for such termination, provided that if the matter is reasonably determined by the Company to not be capable of being cured, the executive may be terminated for cause on the date the written notice is delivered. The Employment Agreement also provides for, among other things, severance payments and the continuation of certain benefits following termination by the Company of the executive other than for Cause, or termination by the executive for Good Reason (as defined in each Employment Agreement). Under these provisions, if the executive’s employment is terminated by the Company without Cause, or the executive terminates his employment for Good Reason: • the executive will have the right to receive a lump-sum payment consisting of 3 times (in the case of the Chief Executive Officer) or 2.5 times (in the case of the Chief Financial Officer, General Counsel and President of Patterson-UTI Drilling) the sum of (i) his base salary and (ii) the average annual cash bonus received by him for the three years prior to the date of termination; • the executive will have the right to receive a pro-rated lump-sum payment equal to his annual cash bonus based on actual results for the year, payable at the same time as annual cash bonuses are paid to active employees, • the Company will accelerate vesting of all options and restricted stock awards on the 60th day following the executive’s termination, and • the Company will pay the executive certain accrued obligations and certain obligations pursuant to the terms of employee benefit plans. If a termination by the Company other than for Cause or by the executive for Good Reason occurs following a Change in Control (as defined in his Employment Agreement, which for the President of Patterson-UTI Drilling includes a change in control of the Company or, in certain circumstances, of Patterson-UTI Drilling), the executive will generally be entitled to the same severance payments and benefits described above except that the pro-rated lump-sum payment for annual cash bonuses will be based on his highest annual cash bonus for the last three years, and the executive will be entitled to 36 months (in the case of the Chief Executive Officer) or 30 months (in the case of the Chief Financial Officer, General Counsel and President of Patterson-UTI Drilling) of subsidized benefits continuation coverage.

Stockholders' Equity

Stockholders' Equity	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Stockholders' Equity	9. Stockholders’ Equity Stock Offering – On January 27, 2017, the Company completed an offering of 18.2 million shares of its common stock and raised net proceeds of $472 million. The Company used the net proceeds of the offering to repay SSE’s outstanding indebtedness of approximately $472 million. Cash Dividends – The Company paid cash dividends during the years ended December 31, 2017, 2016 and 2015 as follows: Per Share Total (in thousands) 2017 Paid on March 22, 2017 $ 0.02 $ 3,326 Paid on June 22, 2017 0.02 4,269 Paid on September 21, 2017 0.02 4,271 Paid on December 21, 2017 0.02 4,449 Total cash dividends $ 0.08 $ 16,315 2016 Paid on March 24, 2016 $ 0.10 $ 14,712 Paid on June 23, 2016 0.02 2,953 Paid on September 22, 2016 0.02 2,953 Paid on December 22, 2016 0.02 2,961 Total cash dividends $ 0.16 $ 23,579 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 7, 2018, the Company’s Board of Directors approved a cash dividend on its common stock in the amount of $0.02 per share to be paid on March 22, 2018 to holders of record as of March 8, 2018. 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 September 6, 2013, the Company’s Board of Directors approved a stock buyback program that authorizes purchase of up to $200 million of the Company’s common stock in open market or privately negotiated transactions. All purchases to date have been through open market transactions. Purchases under the program are made at management’s discretion, at prevailing prices, subject to market conditions and other factors. Purchases may be made at any time without prior notice. Shares of stock purchased under the plan are held as treasury shares. There is no expiration date associated with the buyback program. As of December 31, 2017, the Company had remaining authorization to purchase approximately $187 million of the Company’s outstanding common stock under the 2013 stock buyback program. The Company acquired shares of stock from directors during 2017 and 2016 and from employees during 2017, 2016 and 2015 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. The remainder of these shares was acquired to satisfy payroll withholding obligations upon 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. 2014 Long-Term Incentive Plan (the “2014 Plan”) and not pursuant to the stock buyback program. Treasury stock acquisitions during the years ended December 31, 2017, 2016 and 2015 were as follows (dollars in thousands): 2017 2016 2015 Shares Cost Shares Cost Shares Cost Treasury shares at beginning of period 43,392,617 $ 911,094 43,207,240 $ 907,045 42,818,585 $ 899,035 Purchases pursuant to 2013 stock buyback program 5,503 109 8,488 183 8,618 180 Acquisitions pursuant to long-term incentive plan 404,491 7,508 176,889 3,866 380,037 7,830 Treasury shares at end of period 43,802,611 $ 918,711 43,392,617 $ 911,094 43,207,240 $ 907,045

Stock-based Compensation

Stock-based Compensation	12 Months Ended
	Dec. 31, 2017
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 2014 Plan was originally approved by the Company’s stockholders effective as of April 17, 2014, 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. On June 29, 2017, the Company’s stockholders approved the amendment and restatement of the 2014 Plan (the “Amended and Restated Plan”) to increase the number of shares available under the plan to 10,049,156 shares. The aggregate number of shares of the Company’s common stock authorized for grant under the Amended and Restated Plan is 18.9 million, which includes 9.1 million shares previously authorized under the 2014 Plan. The Company’s share-based compensation plans at December 31, 2017 are as follows: Shares Shares Underlying Shares Authorized Awards Available Plan Name for Grant Outstanding for Grant Amended and Restated Plan 18,900,000 5,286,459 7,647,874 Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended — 3,804,500 — A summary of the Amended and Restated 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, 2017, non-incentive stock options, restricted stock awards, restricted stock units and performance unit awards had been granted under the plan. Options granted under the Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan (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. No options were granted during the year ended December 31, 2017. Weighted-average assumptions used to estimate grant date fair values for stock options granted during the years ended December 31, 2016 and 2015 are as follows: 2016 2015 Volatility 35.11 % 37.95 % Expected term (in years) 5.00 5.00 Dividend yield 2.05 % 2.00 % Risk-free interest rate 1.40 % 1.37 % Stock option activity for the year ended December 31, 2017 follows: Weighted-average Shares exercise price Outstanding at beginning of year 6,687,150 $ 20.68 Exercised (50,000 ) $ 18.63 Expired (600,000 ) $ 24.17 Outstanding at end of year 6,037,150 $ 20.35 Exercisable at end of year 5,515,968 $ 20.49 Options outstanding at December 31, 2017 have an aggregate intrinsic value of approximately $25.9 million and a weighted-average remaining contractual term of 4.65 years. Options exercisable at December 31, 2017 have an aggregate intrinsic value of approximately $23.7 million and a weighted-average remaining contractual term of 4.31 years. Additional information with respect to options granted, vested and exercised during the years ended December 31, 2017, 2016 and 2015 follows: 2017 2016 2015 Weighted-average grant date fair value of stock options granted (per share) NA $ 4.90 $ 5.79 Aggregate grant date fair value of stock options vested during the year (in thousands) $ 4,565 $ 4,729 $ 5,077 Aggregate intrinsic value of stock options exercised (in thousands) $ 209 $ 366 $ — As of December 31, 2017, options to purchase 521,182 shares were outstanding and not vested. All of these non-vested options are expected to ultimately vest. Additional information as of December 31, 2017 with respect to these non-vested options follows: Aggregate intrinsic value $2.1 million Weighted-average remaining contractual term 8.2 years Weighted-average remaining expected term 3.2 years Weighted-average remaining vesting period 1.4 years Unrecognized compensation cost $2.6 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, 2017 follows: Weighted- average Grant Shares Date Fair Value Non-vested restricted stock outstanding at beginning of year 1,427,455 $ 22.26 Granted 890,904 $ 21.78 Vested (764,213 ) $ 23.40 Forfeited (23,808 ) $ 22.34 Non-vested restricted stock outstanding at end of year 1,530,338 $ 21.41 As of December 31, 2017, approximately 1.5 million shares of non-vested restricted stock outstanding are expected to vest. Additional information as of December 31, 2017 with respect to these non-vested shares follows: Aggregate intrinsic value $34.0 million Weighted-average remaining vesting period 1.3 years Unrecognized compensation cost $19.6 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 and, in certain cases, performance conditions. Non-forfeitable cash dividend equivalents are paid on certain non-vested restricted stock units, and forfeitable dividend equivalents are accrued on certain other restricted stock units that will be paid upon vesting. 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, 2017 follows: Weighted-average Grant Date Fair Shares Value Non-vested restricted stock units outstanding at beginning of year 191,655 $ 19.85 Granted 1,238,692 $ 19.85 Assumed (1) 505,551 $ 22.45 Vested (549,451 ) $ 22.24 Forfeited (49,174 ) $ 21.26 Non-vested restricted stock units outstanding at end of year 1,337,273 $ 19.80 (1) Restricted stock unit awards under the Seventy Seven Energy Inc. 2016 Omnibus Incentive Plan, which was adopted, assumed, amended and renamed by the Company in connection with the SSE merger. No additional awards will be made under this plan. Performance Unit Awards. The Company has granted share-settled performance unit awards to certain executive officers (the “Performance Units”) on an annual basis since 2010. The Performance Units provide for the recipients to receive a grant of shares of common stock upon the achievement of certain performance goals during a specified period established by the Compensation Committee. The performance period for the Performance Units is the three year period commencing on April 1 of the year of grant, except that for the Performance Units granted in 2013 the performance period was extended pursuant to its terms, as described below, and for the Performance Units granted in 2017 the three-year performance period commenced on May 1. The performance goals for the 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 during the performance period, when compared to the peer group, is at the 50 th th th th th For the Performance Units awarded prior to 2016, 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 th For the Performance Units granted in April 2016, if the Company’s total shareholder return is negative, and, when compared to the peer group is at or above the 25th percentile, then the recipients will receive one-half of the number of shares they would have received had the Company’s total shareholder return been positive. For the Performance Units granted in May 2017, the payout is based on relative performance and does not have an absolute performance requirement. The total target number of shares with respect to the Performance Units for the years 2012-2017 is set forth below: 2017 2016 2015 2014 2013 2012 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Target number of shares 186,198 185,000 190,600 154,000 236,500 192,000 The 2012 Performance Units settled with an 87th total shareholder return percentile and 384,000 shares were issued. The 2014 Performance Units settled with an 89 th Because the 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 Performance Units is set forth below (in thousands): 2017 2016 2015 2014 2013 2012 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 $ 5,780 $ 3,854 $ 4,052 $ 5,388 $ 5,564 $ 3,065 These fair value amounts are charged to expense on a straight-line basis over the performance period. Compensation expense associated with the Performance Units is set forth below (in thousands): 2017 2016 2015 2014 2013 2012 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Year ended December 31, 2017 $ 1,284 $ 1,285 $ 1,351 $ 449 NA NA Year ended December 31, 2016 NA $ 963 $ 1,351 $ 1,796 $ 464 NA Year ended December 31, 2015 NA NA 1,013 $ 1,796 $ 1,855 $ 255 Dividends on Equity Awards – Non-forfeitable cash dividends are paid on restricted stock awards and dividend equivalents are paid or accrued on certain restricted stock units. These dividends 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 reductions of retained earnings for the portion of restricted stock units expected to vest. • Dividend equivalents are recognized as additional compensation cost for the portion of restricted stock units that are not expected to vest or that ultimately do not vest.

Leases

Leases	12 Months Ended
	Dec. 31, 2017
Leases [Abstract]
Leases	11. Leases The Company incurred rent expense of $48.9 million, $25.3 million and $37.6 million for the years ended December 31, 2017, 2016 and 2015, 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, 2017 are as follows (in thousands): Year ending December 31, 2018 $ 13,616 2019 9,368 2020 7,112 2021 5,165 2022 3,844 Thereafter 8,917 Total $ 48,022

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2017
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, 2017, 2016 and 2015 are as follows (in thousands): 2017 2016 2015 Federal income tax benefit: Current $ (42 ) $ (24,777 ) $ (42,020 ) Deferred (335,106 ) (134,592 ) (83,812 ) (335,148 ) (159,369 ) (125,832 ) State income tax expense (benefit): Current (215 ) (257 ) (3,480 ) Deferred 4,511 (14,163 ) (12,433 ) 4,296 (14,420 ) (15,913 ) Foreign income tax expense (benefit): Current (3,108 ) (368 ) (2,590 ) Deferred 249 (3,405 ) (3,628 ) (2,859 ) (3,773 ) (6,218 ) Total income tax benefit: Current (3,365 ) (25,402 ) (48,090 ) Deferred (330,346 ) (152,160 ) (99,873 ) Total income tax benefit: $ (333,711 ) $ (177,562 ) $ (147,963 ) The difference between the statutory federal income tax rate and the effective income tax rate for the years ended December 31, 2017, 2016 and 2015 is summarized as follows: 2017 2016 2015 Statutory tax rate 35.0 % 35.0 % 35.0 % State income taxes - net of the federal income tax benefit 1.9 2.0 2.1 Permanent differences (1.3 ) (0.1 ) (1.3 ) One-time tax effects of tax reform 66.7 — — Share-based payments 3.6 — — Acquisition related differences (3.3 ) — — Other differences, net (0.8 ) (1.1 ) (2.4 ) Effective tax rate 101.8 % 35.8 % 33.4 % The effective tax rate increased by approximately 66.0% to 101.8% for 2017 compared to 2016, primarily due to a 66.7% increase related to tax reform enacted on December 22, 2017 and a 3.6% increase for excess tax benefits from employee stock compensation deductions. These increases were partially offset by a 3.3% decrease in the effective tax rate for acquisitions that resulted in the revaluation of deferred tax assets and liabilities at the new state tax rates at which they are expected to reverse. The lower 2015 effective tax rate is primarily related to the impact of goodwill impairment charges in 2015, along with an adjustment to the Company’s deferred tax liability associated with the 2010 conversion of its Canadian operations to a controlled foreign corporation. Tax reform reduces the U.S. federal corporate tax rate from 35% to 21% beginning in 2018, requires companies to pay a one-time transition tax on foreign earnings that were previously tax deferred, creates new taxes on future foreign earnings, places a new limitation on the tax deductibility of interest expense, accelerates the expensing of certain business assets, and reduces the amount of executive pay that will be tax deductible, among other changes. Based on a reduced U.S. federal corporate tax rate of 21% from tax reform, the Company remeasured certain deferred tax assets and liabilities at the tax rates at which they are expected to reverse in the future. Due to the limited time to consider tax reform and its various interpretations, the Company is still analyzing and refining its calculations, which could potentially affect the measurement of these balances or give rise to new deferred tax amounts, however, in certain cases, the Company has made a reasonable estimate of the effects on its existing deferred tax balances and the one-time transition tax. For the items for which the Company was able to determine a reasonable estimate, it recognized a provisional amount, in accordance with SAB 118, of approximately $219 million of tax benefit, which is included as a component of income tax expense from continuing operations resulting in the above impact to the Company’s 2017 effective income tax rate. The one-time transition tax is based on the total post-1986 earnings and profits (E&P) of the Company’s foreign operation which it has previously deferred from U.S. income taxes. Based on its current analysis, the Company has estimated an E&P deficit and therefore has not recorded any additional taxes for the one-time transition tax. The Company notes that its analysis of the transition tax is provisional and represents a reasonable estimate resulting from the mandatory deemed repatriation of its post-1986 untaxed foreign E&P. Determining the provisional transition tax required a significant number of steps, including determining the composition of the Company’s post-1986 untaxed foreign E&P that is held in cash or liquid assets and other assets at several measurement dates, as a different rate is applied to each when determining the transition tax liability, and analyzing the Company’s accumulated foreign post-1986 E&P, including historical practices and assertions. As a result of these factors, as well as the proximity of the enactment of tax reform to its year-end, the Company had limited time to consider tax reform and its various interpretations and has not completed its calculation of the total post-1986 E&P amounts of its foreign operations. Adjustments to the Company’s estimates may occur once it finalizes these calculations. Prior to tax reform, the Company had elected to permanently reinvest unremitted earnings in Canada effective January 1, 2010, and it intended to do so for the foreseeable future. As a result, no deferred United States federal or state income taxes had been provided on such unremitted foreign earnings. With the enactment of tax reform, there is a new territorial tax system that provides for a 100% dividends received deduction on future earnings, if remitted. However, the Company will need to continue to evaluate its reinvestment intentions on future earnings and any other residual basis differences in order to determine whether it can continue to assert indefinite reinvestment or whether it will be required to provide for additional taxes that would be due on future earnings if remitted, such as foreign withholding taxes or state and local taxes. The Company will also need to determine whether it will be required to provide for additional taxes on any other outside basis differences in its foreign operations. Due to the limited time to consider these provisions, the Company is still evaluating how tax reform will affect its existing accounting position to indefinitely reinvest unremitted foreign earnings. The Company will continue to assert permanent reinvestment with respect to future unremitted earnings and has not recorded any deferred federal or state income taxes that would be provided on future unremitted earnings. The Company will finalize its intentions on whether it will permanently reinvest its foreign unremitted earnings within the measurement period provided under SAB 118. Tax reform also introduced a new GILTI U.S. tax on certain off-shore earnings at an effective tax rate of 10.5% for tax years beginning after December 31, 2017 (increasing to 13.125% for tax years beginning after December 31, 2025) with a partial offset for any related foreign tax credits. The Company is still evaluating the GILTI provisions of tax reform and its impact, if any, on the Company’s consolidated financial statements at December 31, 2017. The FASB staff allowed companies to adopt an accounting policy to either provide deferred taxes for GILTI or treat it as a tax cost in the year incurred. The Company has not yet determined its accounting policy because determining the impact of the GILTI provisions requires analysis of its existing legal entity structure, the reversal of differences in the assets and liabilities of its foreign subsidiaries, and its ability to offset any tax with foreign tax credits. As such, the Company did not record a deferred income tax expense or benefit related to the GILTI provisions in its consolidated statement of operations for the year ended December 31, 2017 and will finalize its evaluation of the GILTI provisions during the measurement period provided under SAB 118. In addition to the provisions above, the tax reform also changed the individuals whose compensation is subject to a $1 million cap on deductibility under Section 162(m) and includes performance-based compensation such as stock options and stock appreciation rights in the calculation. For taxable years beginning before December 31, 2017, a public company had been able to deduct up to $1 million of compensation paid to covered employees consisting of the chief executive officer and the next three highest compensated officers, but not the chief financial officer (CFO). However, the limit did not apply to performance-based compensation. The new law expands the definition of covered employees to include the CFO and any individual who has been considered a covered employee, even if that individual is no longer a covered employee. Thus, once an individual is a covered employee, the deduction limitation applies to compensation paid to that individual at any point in the future, including after a separation from service. Any individual who is a covered employee for a tax year after December 31, 2016 will remain a covered employee for all future years. The law also eliminates the exception for performance-based compensation. The provision generally applies to taxable years beginning after December 31, 2017 and provides a transition for compensation paid pursuant to a written binding contract that is in effect on November 2, 2017. The Company will need to carefully review the terms of its compensation plans and agreements to assess whether such plans and agreements are considered to be written binding contracts in effect on November 2, 2017. Due to the complexity of applying this new provision and the limited time to consider tax reform, the Company has not yet completed its analysis of these new provisions and will finalize its analysis during the measurement period provided under SAB 118. In March 2016, the FASB issued Accounting Standards Update No. 2016-09, "Compensation-Stock Compensation". The new standard was effective for the Company on January 1, 2017. Among other provisions, the new standard requires that excess tax benefits and tax deficiencies that arise upon vesting or exercise of share-based payments be recognized as income tax benefits and expenses in the income statement. Previously, such amounts were recorded to additional paid-in-capital. This aspect of the new guidance was required to be adopted prospectively. The effective income tax rate for the year ended December 31, 2017 includes approximately $12 million of excess tax benefits from share-based compensation awards that vested or were exercised during the period. During 2017, there was significant merger and acquisition activity by the Company. Based on this activity, an evaluation was made of the Company’s overall state deferred tax rate, resulting in a slightly increased rate. The Company remeasured certain deferred tax assets and liabilities at the tax rates at which they are expected to reverse in the future and recorded additional taxes of approximately $11 million, impacting the 2017 effective income tax rate. The tax effect of significant temporary differences representing deferred tax assets and liabilities at December 31, 2017 and 2016 are as follows (in thousands): 2017 2016 Deferred tax assets: Net operating loss carryforwards $ 285,542 $ 203,485 Alternative minimum tax credit 7,907 7,907 Scientific research and experimental development tax credit 898 — Expense associated with stock options and restricted stock 12,338 17,116 Workers' compensation allowance 19,662 26,157 Federal benefit of state deferred tax liabilities 5,660 5,310 Other 27,066 14,998 Total deferred tax assets 359,073 274,973 Deferred tax liabilities: Property and equipment basis difference (695,111 ) (911,972 ) Other (10,923 ) (9,538 ) Total deferred tax liabilities (706,034 ) (921,510 ) Net deferred tax liability $ (346,961 ) $ (646,537 ) 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 Company’s carryback availability, the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment. The Company expects the full carrying value of its deferred tax assets at December 31, 2017 and 2016 to be realized as a result of the timing of the reversals of its existing taxable temporary differences, which will give rise to taxable income and offset deductible temporary differences in the permitted carryforward periods. As of December 31, 2017, the Company does not consider a valuation allowance necessary. 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 $27.1 million. Other deferred tax liabilities of approximately $10.9 million consists 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 $1.1 billion of gross federal net operating losses, approximately $19.2 million of Canadian net operating losses and approximately $678 million of post-apportionment state net operating losses as of December 31, 2017. Of these amounts, approximately $11 million of Canadian and $1 million of state losses 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: 2023—$137,000; 2024—$2.4 million; 2025—$2.8 million; 2026—$17.4 million; 2027—$102,000; 2029—$33.2 million; 2030—$28.6 million; 2031—$101.9 million; 2032—$9.7 million; 2034—$30,000; 2035—$302.7 million, 2036 - $644.6 million; and 2037—$647.1 million. As of December 31, 2017, 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, 2017, the tax years ended December 31, 2013 through December 31, 2016 are open for examination by U.S. taxing authorities. As of December 31, 2017, the tax years ended December 31, 2013 through December 31, 2016 are open for examination by Canadian taxing authorities.

Employee Benefits

Employee Benefits	12 Months Ended
	Dec. 31, 2017
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 $8.7 million in 2017, $4.4 million in 2016 and $7.1 million in 2015 for the Company’s contributions to the plan.

Business Segments

Business Segments	12 Months Ended
	Dec. 31, 2017
Segment Reporting [Abstract]
Business Segments	14. Business Segments At December 31, 2017, the Company had three business segments: (i) contract drilling of oil and natural gas wells, (ii) pressure pumping services and (iii) directional drilling services. 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, 2017, the Company had 295 marketed land-based drilling rigs in the continental United States and western Canada. For the years ended December 31, 2017, 2016 and, 2015, contract drilling revenue earned in Canada was $13.7 million, $15.6 million and $37.5 million, respectively. Additionally, long-lived assets within the contract drilling segment located in Canada totaled $52.0 million and $44.0 million as of December 31, 2017 and 2016, respectively. Pressure Pumping — The Company provides pressure pumping services to oil and natural gas operators primarily in Texas and the Mid-Continent and Appalachian regions. 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 wall of the well bore and the casing to support and stabilize the casing. Directional Drilling — The Company provides a comprehensive suite of directional drilling services in most major producing onshore oil and gas basins in the United States. Major Customer — During 2017, no single customer accounted for more than 10% of the Company’s consolidated operating revenues. During 2016, one customer accounted for approximately $124 million or 14% of the Company’s consolidated operating revenues. During 2015, one customer accounted for approximately $244 million or 13% of the Company’s consolidated operating revenues. These revenues in 2015 and 2016 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): Year Ended December 31, 2017 2016 2015 Revenues: Contract drilling $ 1,041,492 $ 544,196 $ 1,155,565 Pressure pumping 1,200,311 354,070 712,454 Directional drilling 45,580 — — Other operations(a) 76,781 18,299 24,931 Elimination of intercompany revenues(b) (7,480 ) (699 ) (1,673 ) Total revenues $ 2,356,684 $ 915,866 $ 1,891,277 Income (loss) before income taxes: Contract drilling $ (171,897 ) $ (235,858 ) $ (78,970 ) Pressure pumping 21,028 (176,628 ) (254,998 ) Directional drilling (21 ) — — Other operations (20,813 ) (3,391 ) (14,269 ) Corporate (152,792 ) (54,672 ) (57,088 ) Other operating income (expense), net (c) 31,957 14,323 (1,647 ) Interest income 1,866 327 964 Interest expense (37,472 ) (40,366 ) (36,475 ) Other 343 69 34 Loss before income taxes $ (327,801 ) $ (496,196 ) $ (442,449 ) Identifiable assets: Contract drilling $ 3,931,994 $ 3,032,819 $ 3,457,044 Pressure pumping 1,209,424 653,630 813,704 Directional drilling 301,275 — — Other operations 172,094 48,885 38,726 Corporate(d) 144,069 36,957 155,574 Total assets $ 5,758,856 $ 3,772,291 $ 4,465,048 Depreciation, depletion, amortization and impairment: Contract drilling $ 538,891 $ 467,974 $ 618,434 Pressure pumping 198,006 184,872 214,552 Directional drilling 9,347 — — Other operations 29,402 10,114 26,301 Corporate 7,695 5,474 5,472 Total depreciation, depletion, amortization and impairment $ 783,341 $ 668,434 $ 864,759 Capital expenditures: Contract drilling $ 354,425 $ 72,508 $ 527,054 Pressure pumping 171,436 39,584 197,577 Directional drilling 7,795 — — Other operations 31,547 6,116 16,625 Corporate 1,884 1,591 2,520 Total capital expenditures $ 567,087 $ 119,799 $ 743,776 ( a) Other operations includes the Company’s oilfield rental tools business, pipe handling components and related technology business, the oil and natural gas working interests and the Middle East/North Africa activities. (b) In 2017, intercompany revenues consists of contract drilling and revenues from other operations for services provided to contract drilling, pressure pumping and within other operations. In 2016, intercompany revenues consists of contract drilling and revenues within other operations. In 2015, intercompany revenues only consisted of contract drilling. (c) Other operating income (expense), net includes 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. This caption also includes expenses related to certain legal settlements net of insurance reimbursements. (d) Corporate assets primarily include cash on hand, income tax receivables, certain property and equipment, and certain deferred tax assets.

Concentrations of Credit Risk

Concentrations of Credit Risk	12 Months Ended
	Dec. 31, 2017
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, 2017 and 2016, the Company’s demand deposits and temporary cash investments consisted of the following (in thousands): 2017 2016 Deposits in FDIC and SIPC-insured institutions under insurance limits $ 13,860 $ 846 Deposits in FDIC and SIPC-insured institutions over insurance limits 106,849 12,866 Deposits in foreign banks 21,479 27,557 142,188 41,269 Less outstanding checks and other reconciling items (99,360 ) (6,117 ) Cash and cash equivalents $ 42,828 $ 35,152 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, 2017, 2016 or 2015. No expense for bad debts was recognized in 2017, 2016 or 2015.

Fair Values of Financial Instru

Fair Values of Financial Instruments	12 Months Ended
	Dec. 31, 2017
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 as of December 31, 2017 and 2016 is set forth below (in thousands): December 31, 2017 December 31, 2016 Carrying Fair Carrying Fair Value Value Value Value Borrowings under Credit Agreement: Revolving credit facility $ 268,000 $ 268,000 $ — $ — 4.97% Series A Senior Notes 300,000 303,966 300,000 283,534 4.27% Series B Senior Notes 300,000 295,616 300,000 263,194 Total debt $ 868,000 $ 867,582 $ 600,000 $ 546,728 The carrying value of the balances outstanding under the revolving credit facility approximates its fair values as this instrument has floating interest rates. The fair values of the Series A Notes and Series B Notes at December 31, 2017 and 2016 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 4.46% at December 31, 2017 and 6.65% at December 31, 2016. For the Series B Notes, the current market rates used in measuring this fair value were 4.64% at December 31, 2017 and 7.02% at December 31, 2016. 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, 2017
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 2017 Operating revenues $ 305,175 $ 579,186 $ 684,989 $ 787,334 Operating loss (92,639 ) (140,236 ) (38,016 ) (21,647 ) Net income (loss) (63,539 ) (92,184 ) (33,769 ) 195,402 Net income (loss) per common share: Basic $ (0.40 ) $ (0.46 ) $ (0.16 ) $ 0.88 Diluted $ (0.40 ) $ (0.46 ) $ (0.16 ) $ 0.88 2016 Operating revenues $ 268,939 $ 193,907 $ 206,133 $ 246,887 Operating loss (95,259 ) (124,332 ) (123,409 ) (113,226 ) Net loss (70,503 ) (85,866 ) (84,143 ) (78,122 ) Net loss per common share: Basic $ (0.48 ) $ (0.58 ) $ (0.58 ) $ (0.53 ) Diluted $ (0.48 ) $ (0.58 ) $ (0.58 ) $ (0.53 )

Valuation And Qualifying Accoun

Valuation And Qualifying Accounts	12 Months Ended
	Dec. 31, 2017
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, 2017 Deducted from asset accounts: Allowance for doubtful accounts $ 3,191 $ — $ (868 ) $ 2,323 Year Ended December 31, 2016 Deducted from asset accounts: Allowance for doubtful accounts $ 3,545 $ — $ (354 ) $ 3,191 Year Ended December 31, 2015 Deducted from asset accounts: Allowance for doubtful accounts $ 3,546 $ — $ (1 ) $ 3,545 (1) Consists of uncollectible accounts written off.

Description of Business and S28

Description of Business and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2017
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 (“U.S. GAAP”) 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 our contract drilling, pressure pumping, directional drilling, oilfield rental and pipe handling components and related technology activities are recognized as services are performed. All of the wells the Company drilled in 2017, 2016 and 2015 were drilled under daywork contracts. Revenue from sales of products are recognized upon customer acceptance. Revenue is presented net of any sales tax charged to the customer that the Company is required to remit to local or state governmental taxing authorities. Reimbursements for the purchase of supplies, equipment, personnel services, shipping and other services that are provided at the request of the Company’s customers are recorded as revenue when incurred. The related costs are recorded as operating expenses when incurred.
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 and materials used in its directional drilling and drilling technology business. Such inventories are stated at the lower of cost or market, with cost determined using the average cost method.
Other Current Assets	Other current assets — Other current assets includes reimbursement from the Company’s workers compensation insurance carrier for claims in excess of the Company’s deductible in the amount of $ 30.0 million and $21.1 million at December 31, 2017 and 2016, respectively.
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 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.
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.
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 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.
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, 2017, 2016 and 2015, 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): 2017 2016 2015 BASIC EPS: Net income (loss) $ 5,910 $ (318,634 ) $ (294,486 ) Adjust for (income) loss attributed to holders of non-vested restricted stock (170 ) — 3,022 Income (loss) attributed to common stockholders $ 5,740 $ (318,634 ) $ (291,464 ) Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 198,447 146,178 145,416 Basic net income (loss) per common share $ 0.03 $ (2.18 ) $ (2.00 ) DILUTED EPS: Income (loss) attributed to common stockholders $ 5,740 $ (318,634 ) $ (291,464 ) Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 198,447 146,178 145,416 Add dilutive effect of potential common shares 1,435 — — Weighted average number of diluted common shares outstanding 199,882 146,178 145,416 Diluted net income (loss) per common share $ 0.03 $ (2.18 ) $ (2.00 ) Potentially dilutive securities excluded as anti-dilutive 3,289 9,057 7,781
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. On December 22, 2017, significant changes were enacted to U.S. tax law (“tax reform”). One of the provisions of tax reform is the introduction of a new U.S. tax on certain off-shore earnings referred to as Global Intangible Low-Taxed Income (“GILTI”) at an effective tax rate of 10.5% (in the case of a corporation) for tax years beginning after December 31, 2017 (increasing to 13.125% for tax years beginning after December 31, 2025) with a partial offset for any related foreign tax credits. The Company is still evaluating the GILTI provisions of tax reform and its impact, if any, on the Company’s consolidated financial statements at December 31, 2017. The Financial Accounting Standards Board (“FASB”) staff allowed companies to adopt an accounting policy to either provide deferred taxes for GILTI or treat it as a tax cost in the year incurred. The Company has not yet determined its accounting policy because determining the impact of the GILTI provisions requires analysis of its existing legal entity structure, the reversal of its U.S. GAAP and U.S. tax basis differences in the assets and liabilities of its foreign subsidiaries, and its ability to offset any tax with foreign tax credits. As such, the Company did not record a deferred income tax expense or benefit related to the GILTI provisions in its consolidated statement of operations for the year ended December 31, 2017 and will finalize its evaluation of the GILTI provisions during the measurement period provided under Staff Accounting Bulletin (“SAB”) 118.
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). As share-based compensation expense recognized in the consolidated statements of operations is based on awards ultimately expected to vest, it has been reduced for estimated forfeitures, based on historical experience. Forfeitures are estimated at the time of grant and revised in subsequent periods if actual forfeitures differ from those estimates.
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 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, 2017. The Company adopted this new revenue guidance effective January 1, 2018, utilizing the modified retrospective method, and will expand its consolidated financial statement disclosures in order to comply with the update. The adoption of this update did not have a material impact on the Company’s consolidated financial statements. In February 2016, the FASB issued an accounting standards update to provide guidance for the accounting for leasing transactions. The standard requires the lessee to recognize a lease liability along with a right-of-use asset for all leases with a term longer than one year. A lessee is permitted to make an accounting policy election by class of underlying asset to not recognize the lease liability and related right-of-use asset for leases with a term of one year or less. The provisions of this standard also apply to situations where the Company is the lessor. The requirements in this update are effective during interim and annual periods beginning after December 15, 2018. The Company previously disclosed its intention to adopt this standard at the same time as it adopted the new revenue standard discussed above; however, the Company now expects to adopt this new guidance in the first quarter of 2019. The Company is currently evaluating the impact that this new guidance will have on its 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. This guidance became effective for the Company during the three months ended March 31, 2017. The adoption of this update was applied retrospectively, resulting in the reclassification of $36.4 million from current deferred tax assets as of December 31, 2016. Of this amount, $4.1 million was reclassified to long-term deferred tax assets and $32.3 million was reclassified to long-term deferred tax liabilities. In March 2016, the FASB issued an accounting standards update to provide guidance for the accounting for share-based payment transactions, including the related income tax consequences, classification of awards as either equity or liabilities, and classification on the statement of cash flows. This guidance became effective for the Company during the three months ended March 31, 2017. The Company believes this guidance has caused and will continue to cause volatility in its effective tax rates and diluted earnings per share due to the tax effects related to share-based payments being recorded in the statement of operations. The volatility in future periods will depend on the Company’s stock price and the number of shares that vest in the case of restricted stock, restricted stock units and performance stock units, or the number of shares that are exercised in the case of stock options. In August 2016, the FASB issued an accounting standard to clarify the presentation of cash receipts and payments in specific situations on the statement of cash flows. The requirements in this update are effective during interim and annual periods beginning after December 15, 2017. The adoption of this update on January 1, 2018 did not have a material impact on the Company’s consolidated financial statements. In January 2017, the FASB issued an accounting standards update to eliminate Step 2 from the goodwill impairment test. An entity will now perform its annual or interim goodwill impairment test by comparing the fair value of a reporting unit with its carrying amount. An entity should recognize an impairment charge for the amount by which the carrying amount exceeds the reporting unit’s fair value, but the loss recognized should not exceed the total amount of goodwill allocated to that reporting unit. The requirements in this update are effective during interim and annual periods in fiscal years beginning after December 15, 2019. Early adoption is permitted for interim or annual goodwill impairment tests performed on testing dates on or after January 1, 2017. The Company adopted this update in 2017, which did not have a material impact on the Company’s consolidated financial statements. In May 2017, the FASB issued an accounting standards update that provided clarity on which changes to the terms or conditions of share-based payment awards require an entity to apply modification accounting provisions. The requirements in this update are effective during interim and annual periods in fiscal years beginning after December 15, 2017. The adoption of this update on January 1, 2018 did not 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, 2017
Accounting Policies [Abstract]
Estimated Useful Lives of Property and Equipment	The estimated useful lives, in years, are shown below: Useful Lives 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, 2017, 2016 and 2015, 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): 2017 2016 2015 BASIC EPS: Net income (loss) $ 5,910 $ (318,634 ) $ (294,486 ) Adjust for (income) loss attributed to holders of non-vested restricted stock (170 ) — 3,022 Income (loss) attributed to common stockholders $ 5,740 $ (318,634 ) $ (291,464 ) Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 198,447 146,178 145,416 Basic net income (loss) per common share $ 0.03 $ (2.18 ) $ (2.00 ) DILUTED EPS: Income (loss) attributed to common stockholders $ 5,740 $ (318,634 ) $ (291,464 ) Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 198,447 146,178 145,416 Add dilutive effect of potential common shares 1,435 — — Weighted average number of diluted common shares outstanding 199,882 146,178 145,416 Diluted net income (loss) per common share $ 0.03 $ (2.18 ) $ (2.00 ) Potentially dilutive securities excluded as anti-dilutive 3,289 9,057 7,781

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2017
Summary of Selected Financial Information of the Company on a Pro Forma Basis	The following table summarizes selected financial information of the Company on a pro forma basis (in thousands, except per share data): 2017 2016 (Unaudited) Revenues $ 2,738,579 $ 1,567,141 Net income (loss) $ 29,584 $ (505,413 ) Net income (loss) per share Basic $ 0.13 $ (2.30 ) Diluted $ 0.13 $ (2.30 )
Seventy Seven Energy Inc.
Total Fair Value of Consideration Transferred	The total fair value of the consideration transferred was determined as follows (in thousands, except stock price): Shares of Company common stock issued to SSE shareholders 46,298 Company common stock price on April 20, 2017 $ 22.45 Fair value of common stock issued $ 1,039,396 Plus SSE long-term debt repaid by Company $ 472,000 Total fair value of consideration transferred $ 1,511,396
Schedule of Total Purchase Price of Assets Acquired and Liabilities Assumed Based on Fair Value	The final determination of the fair value of assets acquired and liabilities assumed at the merger date will be completed as soon as possible, but no later than one year from the merger date (the “measurement period”). The Company’s preliminary purchase price allocation is subject to revision as additional information about the fair value of assets and liabilities becomes available. Additional information that existed as of the merger date, but at the time was unknown to the Company, may become known to the Company during the remainder of the measurement period. The final determination of fair value may differ materially from these preliminary estimates. The following table represents the preliminary allocation of the total purchase price of SSE to the assets acquired and the liabilities assumed based on the fair value at the merger date, with the excess of the purchase price over the estimated fair value of the identifiable net assets acquired recorded as goodwill (in thousands): Identifiable assets acquired Cash and cash equivalents $ 37,806 Accounts receivable 149,659 Inventory 8,518 Other current assets 19,038 Property and equipment 984,433 Other long-term assets 20,918 Intangible assets 22,500 Total identifiable assets acquired 1,242,872 Liabilities assumed Accounts payable and accrued liabilities 133,415 Deferred income taxes 32,881 Other long-term liabilities 1,734 Total liabilities assumed 168,030 Net identifiable assets acquired 1,074,842 Goodwill 436,554 Total net assets acquired $ 1,511,396
Portion of Fair Value Consideration Transferred Provisionally Assigned to Identifiable Intangible Assets	A portion of the fair value consideration transferred has been provisionally assigned to identifiable intangible assets as follows: Fair Value Weighted Average Useful Life (in thousands) (in years) Assets Favorable drilling contracts $ 22,500 0.83
Multi Shot L L C
Total Fair Value of Consideration Transferred	The total fair value of the consideration transferred was determined as follows (in thousands, except stock price): Shares of Company common stock issued to MS Directional shareholders 8,798 Company common stock price on October 11, 2017 $ 21.31 Fair value of common stock issued $ 187,494 Plus MS Directional long-term debt repaid by Company $ 63,000 Plus cash to sellers $ 6,781 Total fair value of consideration transferred $ 257,275
Schedule of Total Purchase Price of Assets Acquired and Liabilities Assumed Based on Fair Value	The final determination of the fair value of assets acquired and liabilities assumed at the acquisition date will be completed as soon as possible, but no later than one year from the acquisition date (the “measurement period”). The Company’s preliminary purchase price allocation is subject to revision as additional information about the fair value of assets and liabilities becomes available. Additional information that existed as of the acquisition date, but at the time was unknown to the Company, may become known to the Company during the remainder of the measurement period. The final determination of fair value may differ materially from these preliminary estimates. The following table represents the preliminary allocation of the total purchase price of MS Directional to the assets acquired and the liabilities assumed based on the fair value at the merger date, with the excess of the purchase price over the estimated fair value of the identifiable net assets acquired recorded as goodwill (in thousands): Identifiable assets acquired Cash and cash equivalents $ 2,021 Accounts receivable 42,782 Inventory 28,060 Other current assets 155 Property and equipment 63,998 Other long-term assets 318 Intangible assets 74,682 Total identifiable assets acquired 212,016 Liabilities assumed Accounts payable and accrued liabilities 43,099 Other long-term liabilities 327 Total liabilities assumed 43,426 Net identifiable assets acquired 168,590 Goodwill 88,685 Total net assets acquired $ 257,275
Portion of Fair Value Consideration Transferred Provisionally Assigned to Identifiable Intangible Assets	A portion of the fair value consideration transferred has been provisionally assigned to identifiable intangible assets as follows: Fair Value Weighted Average Useful Life (in thousands) (in years) Assets Developed technology $ 48,000 10.00 Customer relationships 26,200 3.00 Internal use software 482 5.00 $ 74,682 7.51

Inventory (Tables)

Inventory (Tables)	12 Months Ended
	Dec. 31, 2017
Inventory Disclosure [Abstract]
Inventory	Inventory consisted of the following at December 31, 2017 and 2016 (in thousands). 2017 2016 Finished goods $ 2,270 $ — Work-in-process 529 1,803 Raw materials and supplies 66,368 18,388 Inventory $ 69,167 $ 20,191

Property and Equipment (Tables)

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2017
Property Plant And Equipment [Abstract]
Property and Equipment	Property and equipment consisted of the following at December 31, 2017 and 2016 (in thousands): 2017 2016 Equipment $ 8,066,404 $ 6,809,129 Oil and natural gas properties 211,566 201,568 Buildings 185,475 97,029 Land 26,593 22,270 Total property and equipment 8,490,038 7,129,996 Less accumulated depreciation, depletion and impairment (4,235,308 ) (3,721,033 ) Property and equipment, net $ 4,254,730 $ 3,408,963
Summary of Depreciation, Depletion, Amortization and Impairment Expense related to Property and Equipment and Intangible Assets and Liabilities	Depreciation, depletion, amortization and impairment — The following table summarizes depreciation, depletion, amortization and impairment expense related to property and equipment and intangible assets and liabilities for 2017, 2016 and 2015 (in thousands): 2017 2016 2015 Depreciation and impairment expense $ 753,510 $ 657,571 $ 845,543 Amortization expense 21,764 3,643 3,643 Depletion expense 8,067 7,220 15,573 Total $ 783,341 $ 668,434 $ 864,759

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2017
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill by Operating Segment	Goodwill — Goodwill by operating segment as of December 31, 201 7 and 2016 and changes for the years then ended are as follows (in thousands): Contract Pressure Directional Oilfield Drilling Pumping Drilling Rental Total Balance December 31, 2015 and 2016 $ 86,234 $ — $ — $ — $ 86,234 Goodwill acquired 308,826 121,444 88,685 6,284 525,239 Balance December 31, 2017 $ 395,060 $ 121,444 $ 88,685 $ 6,284 $ 611,473
Summary of Segment and Weighted Average Useful Life of Intangible Assets	The following table identifies the segment and weighted average useful life of each of the Company’s intangible assets: Weighted Average Segment Useful Life (in years) Customer relationships Pressure pumping 7.00 Customer relationships Directional drilling 3.00 Developed technology Directional drilling 10.00 Favorable drilling contracts Contract drilling 0.83 Internal use software Directional drilling 5.00
Gross Carrying Amount and Accumulated Amortization of Intangible Assets	The gross carrying amount and accumulated amortization of intangible assets as of December 31, 2017 and 2016 are as follows (in thousands): 2017 2016 Gross Carrying Accumulated Net Carrying Gross Carrying Accumulated Net Carrying Amount Amortization Amount Amount Amortization Amount Customer relationships $ 26,200 $ (1,943 ) $ 24,257 $ 25,500 $ (22,768 ) $ 2,732 Developed technology 48,000 (1,137 ) 46,863 — — — Favorable drilling contracts 22,500 (18,482 ) 4,018 — — — Internal use software 482 (21 ) 461 — — — $ 97,182 $ (21,583 ) $ 75,599 $ 25,500 $ (22,768 ) $ 2,732
Remaining Amortization Expense Associated with Finite-Lived Intangible Assets	The remaining amortization expense associated with finite-lived intangible assets is expected to be as follows (in thousands): Year ending December 31, 2018 $ 17,580 2019 13,630 2020 11,686 2021 4,896 2022 4,875 Thereafter 22,932 Total $ 75,599

Accrued Expenses (Tables)

Accrued Expenses (Tables)	12 Months Ended
	Dec. 31, 2017
Payables And Accruals [Abstract]
Summary of Accrued Expenses	Accrued expenses consisted of the following at December 31, 2017 and 2016 (in thousands): 2017 2016 Salaries, wages, payroll taxes and benefits $ 50,443 $ 21,138 Workers’ compensation liability 80,751 67,775 Property, sales, use and other taxes 29,332 6,766 Insurance, other than workers’ compensation 10,816 9,566 Accrued interest payable 7,558 6,740 Accrued merger and integration 16,101 — Other 31,628 27,163 $ 226,629 $ 139,148

Long Term Debt (Tables)

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 (in thousands): Year ending December 31, 2018 $ — 2019 268,000 2020 300,000 2021 — 2022 300,000 Thereafter — Total $ 868,000

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2017
Equity [Abstract]
Cash Dividends	Cash Dividends – The Company paid cash dividends during the years ended December 31, 2017, 2016 and 2015 as follows: Per Share Total (in thousands) 2017 Paid on March 22, 2017 $ 0.02 $ 3,326 Paid on June 22, 2017 0.02 4,269 Paid on September 21, 2017 0.02 4,271 Paid on December 21, 2017 0.02 4,449 Total cash dividends $ 0.08 $ 16,315 2016 Paid on March 24, 2016 $ 0.10 $ 14,712 Paid on June 23, 2016 0.02 2,953 Paid on September 22, 2016 0.02 2,953 Paid on December 22, 2016 0.02 2,961 Total cash dividends $ 0.16 $ 23,579 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, 2017, 2016 and 2015 were as follows (dollars in thousands): 2017 2016 2015 Shares Cost Shares Cost Shares Cost Treasury shares at beginning of period 43,392,617 $ 911,094 43,207,240 $ 907,045 42,818,585 $ 899,035 Purchases pursuant to 2013 stock buyback program 5,503 109 8,488 183 8,618 180 Acquisitions pursuant to long-term incentive plan 404,491 7,508 176,889 3,866 380,037 7,830 Treasury shares at end of period 43,802,611 $ 918,711 43,392,617 $ 911,094 43,207,240 $ 907,045

Stock-based Compensation (Table

Stock-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 are as follows: Shares Shares Underlying Shares Authorized Awards Available Plan Name for Grant Outstanding for Grant Amended and Restated Plan 18,900,000 5,286,459 7,647,874 Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended — 3,804,500 —
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 during the years ended December 31, 2016 and 2015 are as follows: 2016 2015 Volatility 35.11 % 37.95 % Expected term (in years) 5.00 5.00 Dividend yield 2.05 % 2.00 % Risk-free interest rate 1.40 % 1.37 %
Stock Option Activity	Stock option activity for the year ended December 31, 2017 follows: Weighted-average Shares exercise price Outstanding at beginning of year 6,687,150 $ 20.68 Exercised (50,000 ) $ 18.63 Expired (600,000 ) $ 24.17 Outstanding at end of year 6,037,150 $ 20.35 Exercisable at end of year 5,515,968 $ 20.49
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, 2017, 2016 and 2015 follows: 2017 2016 2015 Weighted-average grant date fair value of stock options granted (per share) NA $ 4.90 $ 5.79 Aggregate grant date fair value of stock options vested during the year (in thousands) $ 4,565 $ 4,729 $ 5,077 Aggregate intrinsic value of stock options exercised (in thousands) $ 209 $ 366 $ —
Restricted Stock Activity	Restricted stock activity for the year ended December 31, 2017 follows: Weighted- average Grant Shares Date Fair Value Non-vested restricted stock outstanding at beginning of year 1,427,455 $ 22.26 Granted 890,904 $ 21.78 Vested (764,213 ) $ 23.40 Forfeited (23,808 ) $ 22.34 Non-vested restricted stock outstanding at end of year 1,530,338 $ 21.41
Restricted Stock Unit Activity	Restricted stock unit activity for the year ended December 31, 2017 follows: Weighted-average Grant Date Fair Shares Value Non-vested restricted stock units outstanding at beginning of year 191,655 $ 19.85 Granted 1,238,692 $ 19.85 Assumed (1) 505,551 $ 22.45 Vested (549,451 ) $ 22.24 Forfeited (49,174 ) $ 21.26 Non-vested restricted stock units outstanding at end of year 1,337,273 $ 19.80 (1) Restricted stock unit awards under the Seventy Seven Energy Inc. 2016 Omnibus Incentive Plan, which was adopted, assumed, amended and renamed by the Company in connection with the SSE merger. No additional awards will be made under this plan.
Performance Units	The total target number of shares with respect to the Performance Units for the years 2012-2017 is set forth below: 2017 2016 2015 2014 2013 2012 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Target number of shares 186,198 185,000 190,600 154,000 236,500 192,000
Fair Value of Performance Units	The fair value of the Performance Units is set forth below (in thousands): 2017 2016 2015 2014 2013 2012 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 $ 5,780 $ 3,854 $ 4,052 $ 5,388 $ 5,564 $ 3,065
Compensation Expense Associated with Performance Units	Compensation expense associated with the Performance Units is set forth below (in thousands): 2017 2016 2015 2014 2013 2012 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Year ended December 31, 2017 $ 1,284 $ 1,285 $ 1,351 $ 449 NA NA Year ended December 31, 2016 NA $ 963 $ 1,351 $ 1,796 $ 464 NA Year ended December 31, 2015 NA NA 1,013 $ 1,796 $ 1,855 $ 255
Employee Stock Option
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Additional Information with Respect to Non-vested Options	Additional information as of December 31, 2017 with respect to these non-vested options follows: Aggregate intrinsic value $2.1 million Weighted-average remaining contractual term 8.2 years Weighted-average remaining expected term 3.2 years Weighted-average remaining vesting period 1.4 years Unrecognized compensation cost $2.6 million
Restricted Stock Awards
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, 2017 with respect to these non-vested shares follows: Aggregate intrinsic value $34.0 million Weighted-average remaining vesting period 1.3 years Unrecognized compensation cost $19.6 million

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017 are as follows (in thousands): Year ending December 31, 2018 $ 13,616 2019 9,368 2020 7,112 2021 5,165 2022 3,844 Thereafter 8,917 Total $ 48,022

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2017
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, 2017, 2016 and 2015 are as follows (in thousands): 2017 2016 2015 Federal income tax benefit: Current $ (42 ) $ (24,777 ) $ (42,020 ) Deferred (335,106 ) (134,592 ) (83,812 ) (335,148 ) (159,369 ) (125,832 ) State income tax expense (benefit): Current (215 ) (257 ) (3,480 ) Deferred 4,511 (14,163 ) (12,433 ) 4,296 (14,420 ) (15,913 ) Foreign income tax expense (benefit): Current (3,108 ) (368 ) (2,590 ) Deferred 249 (3,405 ) (3,628 ) (2,859 ) (3,773 ) (6,218 ) Total income tax benefit: Current (3,365 ) (25,402 ) (48,090 ) Deferred (330,346 ) (152,160 ) (99,873 ) Total income tax benefit: $ (333,711 ) $ (177,562 ) $ (147,963 )
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, 2017, 2016 and 2015 is summarized as follows: 2017 2016 2015 Statutory tax rate 35.0 % 35.0 % 35.0 % State income taxes - net of the federal income tax benefit 1.9 2.0 2.1 Permanent differences (1.3 ) (0.1 ) (1.3 ) One-time tax effects of tax reform 66.7 — — Share-based payments 3.6 — — Acquisition related differences (3.3 ) — — Other differences, net (0.8 ) (1.1 ) (2.4 ) Effective tax rate 101.8 % 35.8 % 33.4 %
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 at December 31, 2017 and 2016 are as follows (in thousands): 2017 2016 Deferred tax assets: Net operating loss carryforwards $ 285,542 $ 203,485 Alternative minimum tax credit 7,907 7,907 Scientific research and experimental development tax credit 898 — Expense associated with stock options and restricted stock 12,338 17,116 Workers' compensation allowance 19,662 26,157 Federal benefit of state deferred tax liabilities 5,660 5,310 Other 27,066 14,998 Total deferred tax assets 359,073 274,973 Deferred tax liabilities: Property and equipment basis difference (695,111 ) (911,972 ) Other (10,923 ) (9,538 ) Total deferred tax liabilities (706,034 ) (921,510 ) Net deferred tax liability $ (346,961 ) $ (646,537 )

Business Segments (Tables)

Business Segments (Tables)	12 Months Ended
	Dec. 31, 2017
Segment Reporting [Abstract]
Business Segments - Financial Information	The following tables summarize selected financial information relating to the Company’s business segments (in thousands): Year Ended December 31, 2017 2016 2015 Revenues: Contract drilling $ 1,041,492 $ 544,196 $ 1,155,565 Pressure pumping 1,200,311 354,070 712,454 Directional drilling 45,580 — — Other operations(a) 76,781 18,299 24,931 Elimination of intercompany revenues(b) (7,480 ) (699 ) (1,673 ) Total revenues $ 2,356,684 $ 915,866 $ 1,891,277 Income (loss) before income taxes: Contract drilling $ (171,897 ) $ (235,858 ) $ (78,970 ) Pressure pumping 21,028 (176,628 ) (254,998 ) Directional drilling (21 ) — — Other operations (20,813 ) (3,391 ) (14,269 ) Corporate (152,792 ) (54,672 ) (57,088 ) Other operating income (expense), net (c) 31,957 14,323 (1,647 ) Interest income 1,866 327 964 Interest expense (37,472 ) (40,366 ) (36,475 ) Other 343 69 34 Loss before income taxes $ (327,801 ) $ (496,196 ) $ (442,449 ) Identifiable assets: Contract drilling $ 3,931,994 $ 3,032,819 $ 3,457,044 Pressure pumping 1,209,424 653,630 813,704 Directional drilling 301,275 — — Other operations 172,094 48,885 38,726 Corporate(d) 144,069 36,957 155,574 Total assets $ 5,758,856 $ 3,772,291 $ 4,465,048 Depreciation, depletion, amortization and impairment: Contract drilling $ 538,891 $ 467,974 $ 618,434 Pressure pumping 198,006 184,872 214,552 Directional drilling 9,347 — — Other operations 29,402 10,114 26,301 Corporate 7,695 5,474 5,472 Total depreciation, depletion, amortization and impairment $ 783,341 $ 668,434 $ 864,759 Capital expenditures: Contract drilling $ 354,425 $ 72,508 $ 527,054 Pressure pumping 171,436 39,584 197,577 Directional drilling 7,795 — — Other operations 31,547 6,116 16,625 Corporate 1,884 1,591 2,520 Total capital expenditures $ 567,087 $ 119,799 $ 743,776 ( a) Other operations includes the Company’s oilfield rental tools business, pipe handling components and related technology business, the oil and natural gas working interests and the Middle East/North Africa activities. (b) In 2017, intercompany revenues consists of contract drilling and revenues from other operations for services provided to contract drilling, pressure pumping and within other operations. In 2016, intercompany revenues consists of contract drilling and revenues within other operations. In 2015, intercompany revenues only consisted of contract drilling. (c) Other operating income (expense), net includes 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. This caption also includes expenses related to certain legal settlements net of insurance reimbursements. (d) Corporate assets primarily include cash on hand, income tax receivables, certain property and equipment, and certain deferred tax assets.

Concentrations of Credit Risk (

Concentrations of Credit Risk (Tables)	12 Months Ended
	Dec. 31, 2017
Risks And Uncertainties [Abstract]
Company's Demand Deposits and Temporary Cash Investments	At December 31, 2017 and 2016, the Company’s demand deposits and temporary cash investments consisted of the following (in thousands): 2017 2016 Deposits in FDIC and SIPC-insured institutions under insurance limits $ 13,860 $ 846 Deposits in FDIC and SIPC-insured institutions over insurance limits 106,849 12,866 Deposits in foreign banks 21,479 27,557 142,188 41,269 Less outstanding checks and other reconciling items (99,360 ) (6,117 ) Cash and cash equivalents $ 42,828 $ 35,152

Fair Values of Financial Inst42

Fair Values of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2017
Fair Value Disclosures [Abstract]
Estimated Fair Value of Outstanding Debt Balances	The estimated fair value of the Company’s outstanding debt balances as of December 31, 2017 and 2016 is set forth below (in thousands): December 31, 2017 December 31, 2016 Carrying Fair Carrying Fair Value Value Value Value Borrowings under Credit Agreement: Revolving credit facility $ 268,000 $ 268,000 $ — $ — 4.97% Series A Senior Notes 300,000 303,966 300,000 283,534 4.27% Series B Senior Notes 300,000 295,616 300,000 263,194 Total debt $ 868,000 $ 867,582 $ 600,000 $ 546,728

Quarterly Financial Informati43

Quarterly Financial Information (Tables)	12 Months Ended
	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Summary of Unaudited Quarterly Financial Information	1 st 2 nd 3 rd 4 th Quarter Quarter Quarter Quarter 2017 Operating revenues $ 305,175 $ 579,186 $ 684,989 $ 787,334 Operating loss (92,639 ) (140,236 ) (38,016 ) (21,647 ) Net income (loss) (63,539 ) (92,184 ) (33,769 ) 195,402 Net income (loss) per common share: Basic $ (0.40 ) $ (0.46 ) $ (0.16 ) $ 0.88 Diluted $ (0.40 ) $ (0.46 ) $ (0.16 ) $ 0.88 2016 Operating revenues $ 268,939 $ 193,907 $ 206,133 $ 246,887 Operating loss (95,259 ) (124,332 ) (123,409 ) (113,226 ) Net loss (70,503 ) (85,866 ) (84,143 ) (78,122 ) Net loss per common share: Basic $ (0.48 ) $ (0.58 ) $ (0.58 ) $ (0.53 ) Diluted $ (0.48 ) $ (0.58 ) $ (0.58 ) $ (0.53 )

Description of Business and S44

Description of Business and Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($) $ in Millions	Dec. 22, 2017	Dec. 31, 2017	Dec. 31, 2015	Dec. 31, 2016
Basis Of Consolidation And Presentation [Line Items]
Current deferred tax assets				$ 36.4
Long-term deferred tax assets				4.1
Long-term deferred tax liabilities				32.3
Settlement of fund for eligible participants			$ 12.3
Reimbursement of workers compensation insurance claims included in other current assets		$ 30		21.1
Tax Years Beginning After December 31, 2017
Basis Of Consolidation And Presentation [Line Items]
Global Intangible Low-Taxed Income (GILTI) at an effective tax rate	10.50%
Tax Years Beginning After December 31, 2025
Basis Of Consolidation And Presentation [Line Items]
Global Intangible Low-Taxed Income (GILTI) at an effective tax rate	13.125%
Seventy Seven Energy Inc.
Basis Of Consolidation And Presentation [Line Items]
Merger date		Apr. 20, 2017
Multi Shot L L C
Basis Of Consolidation And Presentation [Line Items]
Merger date		Oct. 11, 2017
Scenario Previously Reported | Accounting Standards Update 2015-17
Basis Of Consolidation And Presentation [Line Items]
Current deferred tax assets				36.4
Restatement Adjustment | Accounting Standards Update 2015-17
Basis Of Consolidation And Presentation [Line Items]
Long-term deferred tax assets				4.1
Long-term deferred tax liabilities				$ 32.3

Estimated Useful Lives of Prope

Estimated Useful Lives of Property and Equipment (Detail)	12 Months Ended
	Dec. 31, 2017
Equipment | Minimum
Property, Plant and Equipment [Line Items]
Property, Plant and Equipment, Useful Life	1 year 3 months
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

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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
BASIC EPS:
Net income (loss)	$ 195,402	$ (33,769)	$ (92,184)	$ (63,539)	$ (78,122)	$ (84,143)	$ (85,866)	$ (70,503)	$ 5,910	$ (318,634)	$ (294,486)
Adjust for (income) loss attributed to holders of non-vested restricted stock									(170)		3,022
Income (loss) attributed to common stockholders									$ 5,740	$ (318,634)	$ (291,464)
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock									198,447	146,178	145,416
Basic net income (loss) per common share	$ 0.88	$ (0.16)	$ (0.46)	$ (0.40)	$ (0.53)	$ (0.58)	$ (0.58)	$ (0.48)	$ 0.03	$ (2.18)	$ (2)
DILUTED EPS:
Income (loss) attributed to common stockholders									$ 5,740	$ (318,634)	$ (291,464)
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock									198,447	146,178	145,416
Add dilutive effect of potential common shares									1,435
Weighted average number of diluted common shares outstanding									199,882	146,178	145,416
Diluted net income (loss) per common share	$ 0.88	$ (0.16)	$ (0.46)	$ (0.40)	$ (0.53)	$ (0.58)	$ (0.58)	$ (0.48)	$ 0.03	$ (2.18)	$ (2)
Potentially dilutive securities excluded as anti-dilutive									3,289	9,057	7,781

Acquisitions - Additional Infor

Acquisitions - Additional Information (Detail) $ in Thousands	Oct. 11, 2017USD ($)shares	Apr. 20, 2017USD ($)Rigshpshares	Jan. 27, 2017USD ($)	Sep. 30, 2016USD ($)shares	Dec. 31, 2017USD ($)shares	Dec. 31, 2016USD ($)shares
Business Acquisition [Line Items]
Merger and integration expenses					$ 74,451
Shares issued for acquisition, value					$ 1,226,890	$ 6,733
Common Stock
Business Acquisition [Line Items]
Shares issued for acquisition | shares					55,097,000	354,000
Shares issued for acquisition, value					$ 551	$ 3
Seventy Seven Energy Inc.
Business Acquisition [Line Items]
Shares of common stock exchange in business acquisition | shares		46,298,000
Repayment of outstanding debt		$ 472,000	$ 472,000
Merger date					Apr. 20, 2017
Total fair value of the consideration transferred		$ 1,511,396
Number of drilling rigs acquired | Rigs		91
Number of horsepower of modern, efficient fracturing equipment | hp		500,000
Merger and integration expenses		$ 69,500			$ 36,700
Decrease in goodwill due to measurement period adjustments		$ 1,900
Seventy Seven Energy Inc. | APEX Class Rigs
Business Acquisition [Line Items]
Number of rigs | Rigs		36
MS Directional
Business Acquisition [Line Items]
Shares of common stock exchange in business acquisition | shares	8,798,000
Repayment of outstanding debt	$ 63,000
Merger date					Oct. 11, 2017
Total fair value of the consideration transferred	257,275
Merger and integration expenses	5,000
Aggregate consideration paid by the company	$ 69,800
Warrior Rig Ltd. | Common Stock
Business Acquisition [Line Items]
Shares issued for acquisition | shares				353,804
Shares issued for acquisition, value				$ 6,700

Total Fair Value of Considerati

Total Fair Value of Consideration Transferred (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	Oct. 11, 2017	Apr. 20, 2017	Jan. 27, 2017
Seventy Seven Energy Inc.
Business Acquisition [Line Items]
Shares of Company common stock issued to shareholders		46,298
Company common stock price		$ 22.45
Fair value of common stock issued		$ 1,039,396
Plus long-term debt repaid by Company		472,000	$ 472,000
Total fair value of consideration transferred		$ 1,511,396
MS Directional
Business Acquisition [Line Items]
Shares of Company common stock issued to shareholders	8,798
Company common stock price	$ 21.31
Fair value of common stock issued	$ 187,494
Plus long-term debt repaid by Company	63,000
Plus cash to sellers	6,781
Total fair value of consideration transferred	$ 257,275

Schedule of Total Purchase Pric

Schedule of Total Purchase Price of Assets Acquired and Liabilities Assumed Based on Fair Value (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Oct. 11, 2017	Apr. 20, 2017	Dec. 31, 2016	Dec. 31, 2015
Liabilities assumed
Goodwill	$ 611,473			$ 86,234	$ 86,234
Seventy Seven Energy Inc.
Identifiable assets acquired
Cash and cash equivalents			$ 37,806
Accounts receivable			149,659
Inventory			8,518
Other current assets			19,038
Property and equipment			984,433
Other long-term assets			20,918
Intangible assets			22,500
Total identifiable assets acquired			1,242,872
Liabilities assumed
Accounts payable and accrued liabilities			133,415
Deferred income taxes			32,881
Other long-term liabilities			1,734
Total liabilities assumed			168,030
Net identifiable assets acquired			1,074,842
Goodwill			436,554
Total net assets acquired			$ 1,511,396
MS Directional
Identifiable assets acquired
Cash and cash equivalents		$ 2,021
Accounts receivable		42,782
Inventory		28,060
Other current assets		155
Property and equipment		63,998
Other long-term assets		318
Intangible assets		74,682
Total identifiable assets acquired		212,016
Liabilities assumed
Accounts payable and accrued liabilities		43,099
Other long-term liabilities		327
Total liabilities assumed		43,426
Net identifiable assets acquired		168,590
Goodwill		88,685
Total net assets acquired		$ 257,275

Portion of Fair Value Considera

Portion of Fair Value Consideration Transferred Provisionally Assigned to Identifiable Intangible Assets (Detail) - USD ($) $ in Thousands	Oct. 11, 2017	Apr. 20, 2017
Seventy Seven Energy Inc.
Business Acquisition [Line Items]
Fair Value, Assets, Portion of the fair value consideration transferred		$ 22,500
Seventy Seven Energy Inc. | Favorable Drilling Contracts
Business Acquisition [Line Items]
Fair Value, Assets, Portion of the fair value consideration transferred		$ 22,500
Weighted Average Useful Life, Identifiable intangible assets		9 months 29 days
MS Directional
Business Acquisition [Line Items]
Fair Value, Assets, Portion of the fair value consideration transferred	$ 74,682
Weighted Average Useful Life, Identifiable intangible assets	7 years 6 months 3 days
MS Directional | Developed Technology
Business Acquisition [Line Items]
Fair Value, Assets, Portion of the fair value consideration transferred	$ 48,000
Weighted Average Useful Life, Identifiable intangible assets	10 years
MS Directional | Customer Relationships
Business Acquisition [Line Items]
Fair Value, Assets, Portion of the fair value consideration transferred	$ 26,200
Weighted Average Useful Life, Identifiable intangible assets	3 years
MS Directional | Internal Use Software
Business Acquisition [Line Items]
Fair Value, Assets, Portion of the fair value consideration transferred	$ 482
Weighted Average Useful Life, Identifiable intangible assets	5 years

Summary of Selected Financial I

Summary of Selected Financial Information of the Company on a Pro Forma Basis (Detail) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
Business Acquisition Pro Forma Information [Abstract]
Revenues	$ 2,738,579	$ 1,567,141
Net income (loss)	$ 29,584	$ (505,413)
Net income (loss) per share
Basic	$ 0.13	$ (2.30)
Diluted	$ 0.13	$ (2.30)

Inventory (Detail)

Inventory (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Inventory Net [Abstract]
Finished goods	$ 2,270
Work-in-process	529	$ 1,803
Raw materials and supplies	66,368	18,388
Inventory	$ 69,167	$ 20,191

Property and Equipment (Detail)

Property and Equipment (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Property Plant And Equipment [Line Items]
Total property and equipment	$ 8,490,038	$ 7,129,996
Less accumulated depreciation, depletion and impairment	(4,235,308)	(3,721,033)
Property and equipment, net	4,254,730	3,408,963
Equipment
Property Plant And Equipment [Line Items]
Total property and equipment	8,066,404	6,809,129
Oil and natural gas properties
Property Plant And Equipment [Line Items]
Total property and equipment	211,566	201,568
Buildings
Property Plant And Equipment [Line Items]
Total property and equipment	185,475	97,029
Land
Property Plant And Equipment [Line Items]
Total property and equipment	$ 26,593	$ 22,270

Depreciation, Depletion, Amorti

Depreciation, Depletion, Amortization and Impairment Expense Related to Property and Equipment and Intangible Assets and Liabilities (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Property Plant And Equipment [Abstract]
Depreciation and impairment expense	$ 753,510	$ 657,571	$ 845,543
Amortization expense	21,764	3,643	3,643
Depletion expense	8,067	7,220	15,573
Total	$ 783,341	$ 668,434	$ 864,759

Property and Equipment - Additi

Property and Equipment - Additional Information (Detail)	1 Months Ended	3 Months Ended	12 Months Ended
	Aug. 31, 2015$ / bbl	Sep. 30, 2015USD ($)$ / bbl	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)Rigs	Dec. 31, 2015USD ($)Rigs
Property Plant And Equipment [Line Items]
Impairment charge for the write-down of drilling equipment | $			$ 29,000,000	$ 0	$ 131,000,000
Expected cash flows from contract drilling segment | $		$ 801,000,000			$ 710,000,000
Average oil price per barrel | $ / bbl	38.22	46.42
Drilling Rigs That Would No Longer Be Marketed As Rigs
Property Plant And Equipment [Line Items]
Number of drilling rigs					33
Mechanically Powered Drilling Rigs That Would No Longer Be Marketed as Rigs
Property Plant And Equipment [Line Items]
Number of drilling 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					9
Mechanically powered drilling rigs that remain marketed but are not operating
Property Plant And Equipment [Line Items]
Number of drilling rigs				19	15
Pressure Pumping
Property Plant And Equipment [Line Items]
Impairment charge for the write-down of drilling equipment | $			$ 0	$ 0	$ 22,000,000
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, 2017	Dec. 31, 2016
Goodwill [Line Items]
Balance at beginning of period	$ 86,234	$ 86,234
Goodwill acquired	525,239	0
Balance at end of period	611,473	86,234
Contract Drilling
Goodwill [Line Items]
Balance at beginning of period	86,234	86,234
Goodwill acquired	308,826	0
Balance at end of period	395,060	86,234
Pressure Pumping
Goodwill [Line Items]
Balance at beginning of period	0	0
Goodwill acquired	121,444	0
Balance at end of period	121,444	0
Directional Drilling
Goodwill [Line Items]
Balance at beginning of period	0	0
Goodwill acquired	88,685	0
Balance at end of period	88,685	0
Oilfield Rental
Goodwill [Line Items]
Balance at beginning of period	0	0
Goodwill acquired	6,284	0
Balance at end of period	$ 6,284	$ 0

Goodwill and Intangible Asset57

Goodwill and Intangible Assets - Additional Information (Detail)	1 Months Ended	3 Months Ended	12 Months Ended
	Aug. 31, 2015$ / bbl	Sep. 30, 2015USD ($)$ / bbl	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Goodwill And Intangible Assets Disclosure [Line Items]
Average oil price per barrel | $ / bbl	38.22	46.42
Goodwill impairment charge					$ 124,561,000
Impairment			$ 0	$ 0	0
Amortization expense on intangible assets			24,300,000	3,600,000	$ 3,600,000
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

Summary of Segment and Weighted

Summary of Segment and Weighted Average Useful Life of Intangible Assets (Detail)	12 Months Ended
	Dec. 31, 2017
Customer Relationships | Pressure Pumping
Acquired Finite Lived Intangible Assets [Line Items]
Weighted Average Useful Life, Identifiable intangible assets	7 years
Customer Relationships | Directional Drilling
Acquired Finite Lived Intangible Assets [Line Items]
Weighted Average Useful Life, Identifiable intangible assets	3 years
Developed Technology | Directional Drilling
Acquired Finite Lived Intangible Assets [Line Items]
Weighted Average Useful Life, Identifiable intangible assets	10 years
Favorable Drilling Contracts | Contract Drilling
Acquired Finite Lived Intangible Assets [Line Items]
Weighted Average Useful Life, Identifiable intangible assets	9 months 29 days
Internal Use Software | Directional Drilling
Acquired Finite Lived Intangible Assets [Line Items]
Weighted Average Useful Life, Identifiable intangible assets	5 years

Gross Carrying Amount and Accum

Gross Carrying Amount and Accumulated Amortization of Intangible Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 97,182	$ 25,500
Accumulated Amortization	(21,583)	(22,768)
Net Carrying Amount	75,599	2,732
Customer Relationships
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	26,200	25,500
Accumulated Amortization	(1,943)	(22,768)
Net Carrying Amount	24,257	$ 2,732
Developed Technology
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	48,000
Accumulated Amortization	(1,137)
Net Carrying Amount	46,863
Favorable Drilling Contracts
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	22,500
Accumulated Amortization	(18,482)
Net Carrying Amount	4,018
Internal Use Software
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	482
Accumulated Amortization	(21)
Net Carrying Amount	$ 461

Remaining Amortization Expense

Remaining Amortization Expense Associated with Finite-Lived Intangible Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Goodwill And Intangible Assets Disclosure [Abstract]
2,018	$ 17,580
2,019	13,630
2,020	11,686
2,021	4,896
2,022	4,875
Thereafter	22,932
Net Carrying Amount	$ 75,599	$ 2,732

Summary of Accrued Expenses (De

Summary of Accrued Expenses (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Payables And Accruals [Abstract]
Salaries, wages, payroll taxes and benefits	$ 50,443	$ 21,138
Workers' compensation liability	80,751	67,775
Property, sales, use and other taxes	29,332	6,766
Insurance, other than workers' compensation	10,816	9,566
Accrued interest payable	7,558	6,740
Accrued merger and integration	16,101
Other	31,628	27,163
Accrued expenses	$ 226,629	$ 139,148

Long Term Debt - Credit Facilit

Long Term Debt - Credit Facilities - Additional Information (Detail)	Jul. 08, 2016USD ($)	Mar. 16, 2015	Dec. 31, 2017USD ($)Covenant	Oct. 27, 2017USD ($)	Apr. 20, 2017USD ($)	Jan. 24, 2017USD ($)	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)
Debt Instrument [Line Items]
Debt maturity date			Sep. 27, 2017
Total assets			$ 5,758,856,000				$ 3,772,291,000	$ 4,465,048,000
Letters of credit outstanding			59,500,000
Maximum | Subsidiaries
Debt Instrument [Line Items]
Total assets			1,000,000
Letter of Credit
Debt Instrument [Line Items]
Line of credit, amount outstanding			$ 0
Credit Agreement
Debt Instrument [Line Items]
Credit agreement date			Sep. 27, 2012
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 40%. 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 its 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, 2017.
Credit agreement, financial covenant compliance			The Company was in compliance with these covenants
Number of compliance covenants | Covenant			2
Maximum percentage allowed to invest in foreign subsidiaries or joint ventures on book value basis	20.00%
Maximum cash balance allowed	$ 100,000,000
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%
Debt service coverage ratio	150.00%
Credit Agreement | Maximum
Debt Instrument [Line Items]
Debt to capitalization ratio, percentage the Company must not exceed at any time			40.00%
Credit Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.50%
Credit Agreement | Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.50%
Credit Agreement | Until September 27, 2017 | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.75%
Credit Agreement | Until September 27, 2017 | London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.25%
Credit Agreement | Until September 27, 2017 | Base Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.75%
Credit Agreement | Until September 27, 2017 | Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.25%
Credit Agreement | Beginning September 27, 2017 | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.25%
Credit Agreement | Beginning September 27, 2017 | London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			3.75%
Credit Agreement | Beginning September 27, 2017 | Base Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.25%
Credit Agreement | Beginning September 27, 2017 | Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.75%
Credit Agreement | Revolving Credit Facility | Through September 2017
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity					$ 632,000,000
Credit Agreement | Revolving Credit Facility | Through March 2019
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity				$ 500,000,000	490,000,000
Credit Agreement | Revolving Credit Facility | Letter of Credit
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity	$ 50,000,000
Credit Agreement | Revolving Credit Facility | Swing Line Facility
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity	20,000,000
Amended Credit Agreement Two
Debt Instrument [Line Items]
Credit agreement amendment date			Jul. 8, 2016
Debt maturity date			Mar. 27, 2019
Aggregate commitments under the revolving credit facility	$ 357,900,000
Line of credit, amount outstanding			$ 268,000,000
Amended Credit Agreement Two | Revolving Credit Facility
Debt Instrument [Line Items]
Aggregate commitments under the revolving credit facility						$ 595,800,000
Weighted average interest rate			5.71%
Letters of credit outstanding			$ 4,600,000
Line of credit, available borrowing capacity			$ 227,000,000
Amended Credit Agreement Four
Debt Instrument [Line Items]
Credit agreement amendment date			Apr. 20, 2017
Amended Credit Agreement Four | Through March 2019
Debt Instrument [Line Items]
Credit agreement amendment date			Oct. 27, 2017
Amended Credit Agreement Four | Revolving Credit Facility
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity					$ 700,000,000
Reimbursement Agreement
Debt Instrument [Line Items]
Letters of credit outstanding			$ 54,900,000
Reimbursement Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate		2.25%

Long Term Debt - Senior Notes -

Long Term Debt - Senior Notes - Additional Information (Detail) $ in Thousands	Jan. 19, 2018USD ($)	Jun. 14, 2012USD ($)Covenant	Oct. 05, 2010USD ($)Covenant	Dec. 31, 2017USD ($)Covenant	Dec. 31, 2016USD ($)	Dec. 31, 2015USD ($)	Sep. 27, 2012USD ($)
Debt Instrument [Line Items]
Debt maturity date				Sep. 27, 2017
Repayment of borrowings				$ 331,000	$ 200,500	$ 357,000
Proceeds from borrowings, before offering expenses				599,000	200,500	54,000
Interest expense related to amortization of debt issuance costs				$ 2,600	4,100	$ 2,800
Revolving Credit Facility | Subsequent Event
Debt Instrument [Line Items]
Repayment of borrowings	$ 239,000
Proceeds from borrowings, before offering expenses	$ 521,000
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			$ 300,000
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.
Debt instrument, redemption percentage			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 its 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, 2017.
Debt issuance costs			$ 1,900
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		$ 300,000
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.
Debt instrument, redemption percentage		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 its 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, 2017.
Debt issuance costs		$ 1,600
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%
3.95% Senior Notes Due 2028
Debt Instrument [Line Items]
Debt payment term				The Company pays interest on the 2028 Notes on February 1 and August 1 of each year.
Debt instrument redemption description				The Company, at its option, may redeem the Notes in whole or part, at any time or from time to time at a redemption price equal to 100% of the principal amount of such 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date, plus a make-whole premium. Additionally, commencing on November 1, 2027, the Company, at its option, may redeem the 2028 Notes in whole or part, at a redemption price equal to 100% of the principal amount of the 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date.
Debt instrument redemption upon the occurrence of change of control, description				Upon the occurrence of a change of control, as defined in the indenture, each holder of the 2028 Notes may require the Company to purchase all or a portion of such holder’s 2028 Notes at a price equal to 101% of their principal amount, plus accrued and unpaid interest, if any, to, but excluding, the repurchase date.
3.95% Senior Notes Due 2028 | Subsequent Event
Debt Instrument [Line Items]
Debt maturity date	Feb. 1, 2028
Long-term debt, aggregate principal amount	$ 525,000
Debt interest rate	3.95%
Debt instrument, redemption percentage	100.00%
Redemption price percentage of principal amount of debt instrument on change of control	101.00%
Credit Agreement
Debt Instrument [Line Items]
Number of compliance covenants | Covenant				2
Debt issuance costs							$ 6,000
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				40.00%
Previous Term Loan
Debt Instrument [Line Items]
Early termination of term loan agreements					$ 1,400

Schedule of Principal Repayment

Schedule of Principal Repayment Requirements of Long-Term Debt (Detail) $ in Thousands	Dec. 31, 2017USD ($)
Debt Disclosure [Abstract]
2,019	$ 268,000
2,020	300,000
2,022	300,000
Total	$ 868,000

Commitments Contingencies and O

Commitments Contingencies and Other Matters - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017USD ($)
Commitments and Contingencies Disclosure [Line Items]
Letters of credit, collateral for retrospective premiums and retained losses	$ 59,500,000
Commitments to purchase major equipment	172,000,000
Current obligation	140,000,000
Purchase obligations for 2018	35,900,000
General liability insurance policy, deductible per occurrence	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
Employment Agreements
Commitments and Contingencies Disclosure [Line Items]
Initial agreement term	3 years
Agreement termination description	Under specified circumstances, the Company may terminate the executive’s employment under his Employment Agreement for Cause (as defined in the Employment Agreement) by either (i) providing written notice 10 days before the effective date of such termination and by granting at least 10 days to cure the cause for such termination or (ii) by providing written notice of such termination at least 30 days before the effective date of such termination and by granting at least 20 days to cure the cause for such termination, provided that if the matter is reasonably determined by the Company to not be capable of being cured, the executive may be terminated for cause on the date the written notice is delivered.
Accelerated vesting period description	Company will accelerate vesting of all options and restricted stock awards on the 60th day following the executive’s termination
Termination benefits description	If a termination by the Company other than for Cause or by the executive for Good Reason occurs following a Change in Control (as defined in his Employment Agreement, which for the President of Patterson-UTI Drilling includes a change in control of the Company or, in certain circumstances, of Patterson-UTI Drilling), the executive will generally be entitled to the same severance payments and benefits described above except that the pro-rated lump-sum payment for annual cash bonuses will be based on his highest annual cash bonus for the last three years, and the executive will be entitled to 36 months (in the case of the Chief Executive Officer) or 30 months (in the case of the Chief Financial Officer, General Counsel and President of Patterson-UTI Drilling) of subsidized benefits continuation coverage.
Period considered for calculating annual cash bonus payment	3 years
Employment Agreements | Minimum
Commitments and Contingencies Disclosure [Line Items]
Agreement termination notice period	30 days
Specified 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 | Change in Control Agreements
Commitments and Contingencies Disclosure [Line Items]
Employee entitlement ratio	2.5
Continued coverage entitlement of welfare plan period	3 years
Executive Vice President | Change in Control Agreements
Commitments and Contingencies Disclosure [Line Items]
Employee entitlement ratio	2
Continued coverage entitlement of welfare plan period	2 years
Chief Executive Officer | Employment Agreements
Commitments and Contingencies Disclosure [Line Items]
Employee entitlement ratio on sum of base salary and average cash bonus	3
Period for subsidized benefit continuation coverage	36 months
Chief Financial Officer, General Counsel and President | Employment Agreements
Commitments and Contingencies Disclosure [Line Items]
Employee entitlement ratio on sum of base salary and average cash bonus	2.5
Period for subsidized benefit continuation coverage	30 months
Letter of Credit
Commitments and Contingencies Disclosure [Line Items]
Amount drawn under letters of credit	$ 0

Stockholders' Equity - Addition

Stockholders' Equity - Additional Information (Detail) - USD ($)	Feb. 07, 2018	Apr. 20, 2017	Jan. 27, 2017	Dec. 31, 2017	Sep. 06, 2013
2013 program
Class Of Stock [Line Items]
Amount approved for repurchases under stock buyback program					$ 200,000,000
Remaining amount approved for repurchases under stock buyback program				$ 187,000,000
Subsequent Event | Dividend Declared
Class Of Stock [Line Items]
Dividend declaration date	Feb. 7, 2018
Dividend per share, declared	$ 0.02
Dividend payment date	Mar. 22, 2018
Dividend record date	Mar. 8, 2018
Seventy Seven Energy Inc.
Class Of Stock [Line Items]
Repayment of outstanding debt		$ 472,000,000	$ 472,000,000
Common Stock
Class Of Stock [Line Items]
Common stock offering				18,170,000
Common Stock | Seventy Seven Energy Inc.
Class Of Stock [Line Items]
Common stock offering			18,200,000
Net proceeds from common stock offering			$ 472,000,000

Cash Dividends (Detail)

Cash Dividends (Detail) - USD ($) $ / shares in Units, $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Dividends Payable [Line Items]
Cash dividends paid, per share	$ 0.08	$ 0.16	$ 0.40
Cash dividends paid	$ 16,315	$ 23,579	$ 58,775
Installment 1, FY 2017
Dividends Payable [Line Items]
Cash dividends paid, date	Mar. 22, 2017
Cash dividends paid, per share	$ 0.02
Cash dividends paid	$ 3,326
Installment 2, FY 2017
Dividends Payable [Line Items]
Cash dividends paid, date	Jun. 22, 2017
Cash dividends paid, per share	$ 0.02
Cash dividends paid	$ 4,269
Installment 3, FY 2017
Dividends Payable [Line Items]
Cash dividends paid, date	Sep. 21, 2017
Cash dividends paid, per share	$ 0.02
Cash dividends paid	$ 4,271
Installment 4, FY 2017
Dividends Payable [Line Items]
Cash dividends paid, date	Dec. 21, 2017
Cash dividends paid, per share	$ 0.02
Cash dividends paid	$ 4,449
Installment 1, FY 2016
Dividends Payable [Line Items]
Cash dividends paid, date		Mar. 24, 2016
Cash dividends paid, per share		$ 0.10
Cash dividends paid		$ 14,712
Installment 2, FY 2016
Dividends Payable [Line Items]
Cash dividends paid, date		Jun. 23, 2016
Cash dividends paid, per share		$ 0.02
Cash dividends paid		$ 2,953
Installment 3, FY 2016
Dividends Payable [Line Items]
Cash dividends paid, date		Sep. 22, 2016
Cash dividends paid, per share		$ 0.02
Cash dividends paid		$ 2,953
Installment 4, FY 2016
Dividends Payable [Line Items]
Cash dividends paid, date		Dec. 22, 2016
Cash dividends paid, per share		$ 0.02
Cash dividends paid		$ 2,961
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

Treasury Stock Acquisition (Det

Treasury Stock Acquisition (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Schedule of Treasury Stock [Line Items]
Treasury shares at beginning of period	43,392,617	43,207,240	42,818,585
Treasury shares at end of period	43,802,611	43,392,617	43,207,240
Treasury shares at beginning of period	$ 911,094	$ 907,045	$ 899,035
Treasury stock acquired, cost	7,617	4,049	8,010
Treasury shares at end of period	$ 918,711	$ 911,094	$ 907,045
2013 Stock Buyback Program
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, shares	5,503	8,488	8,618
Treasury stock acquired, cost	$ 109	$ 183	$ 180
Long Term Incentive Plan
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, shares	404,491	176,889	380,037
Treasury stock acquired, cost	$ 7,508	$ 3,866	$ 7,830

Stock-based Compensation - Addi

Stock-based Compensation - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Jun. 29, 2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of stock option granted	0
Employee Stock Option
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options outstanding, aggregate intrinsic value	$ 25.9
Options outstanding, weighted-average remaining contractual term	4 years 7 months 24 days
Options exercisable, aggregate intrinsic value	$ 23.7
Options exercisable, weighted-average remaining contractual term	4 years 3 months 21 days
Outstanding non-vested options	521,182
Restricted Stock Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding non-vested restricted stock	1,500,000
Performance Units Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Performance period	3 years
Basis of annual percentage exceeds	18.00%
Performance Units Awards | 2012
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Total shareholder return percentile for performance period	87.00%
Shares issued	384,000
Performance Units Awards | 2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Total shareholder return percentile for performance period	89.00%
Performance Units Awards | Condition One [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Award description	Generally, the recipients will receive a target number of shares if the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 50th percentile. If the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 75th percentile or higher, then the recipients will receive two times the target number of shares
Performance Units Awards | Condition Two [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Award description	if, during the two-year period ending March 31, 2018, the Company’s total shareholder return for any 30 consecutive day period equals or exceeds 18 percent on an annualized basis from April 1, 2013 through the last day of such 30 consecutive day period, and the recipient is actively employed by the Company through the last day of the extended performance period, then the Company will issue to the recipient the number of shares equal to the amount the recipient would have been entitled to receive had the Company’s total shareholder return been positive during the initial three-year performance period.
Amended and Restated Plan
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares available for future issuance	7,647,874	10,049,156
Shares authorized for grant	18,900,000	18,900,000
Amended and Restated Plan | Maximum
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Option term	10 years
Amended and Restated Plan | Non Employee Director
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	1 year
Amended and Restated Plan | Employees
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	3 years
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
Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan | 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 | 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 | 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 | Employees | Restricted Stock Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Awards vesting period	3 years

Company's Share-Based Compensat

Company's Share-Based Compensation Plans (Detail) - shares	Dec. 31, 2017	Jun. 29, 2017
Amended and Restated Plan
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares Authorized for Grant	18,900,000	18,900,000
Shares Underlying Awards Outstanding	5,286,459
Shares Available for Grant	7,647,874	10,049,156
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	3,804,500

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, 2016	Dec. 31, 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Volatility	35.11%	37.95%
Expected term (in years)	5 years	5 years
Dividend yield	2.05%	2.00%
Risk-free interest rate	1.40%	1.37%

Stock Option Activity (Detail)

Stock Option Activity (Detail)	12 Months Ended
	Dec. 31, 2017$ / sharesshares
Shares
Outstanding at beginning of year | shares	6,687,150
Exercised | shares	(50,000)
Expired | shares	(600,000)
Outstanding at end of year | shares	6,037,150
Exercisable at end of year | shares	5,515,968
Weighted-average exercise price
Outstanding at beginning of year | $ / shares	$ 20.68
Exercised | $ / shares	18.63
Expired | $ / shares	24.17
Outstanding at end of year | $ / shares	20.35
Exercisable at end of year | $ / shares	$ 20.49

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, 2017	Dec. 31, 2016	Dec. 31, 2015
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Weighted-average grant date fair value of stock options granted (per share)		$ 4.90	$ 5.79
Aggregate grant date fair value of stock options vested during the year	$ 4,565	$ 4,729	$ 5,077
Aggregate intrinsic value of stock options exercised	$ 209	$ 366

Additional Information with R74

Additional Information with Respect to Non-vested Options (Detail) - Employee Stock Option $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate intrinsic value	$ 2.1
Weighted-average remaining contractual term	8 years 2 months 12 days
Weighted-average remaining expected term	3 years 2 months 12 days
Weighted-average remaining vesting period	1 year 4 months 24 days
Unrecognized compensation cost	$ 2.6

Restricted Stock Activity (Deta

Restricted Stock Activity (Detail) - Restricted Stock Awards	12 Months Ended
	Dec. 31, 2017$ / sharesshares
Shares
Outstanding at beginning of year | shares	1,427,455
Granted | shares	890,904
Vested | shares	(764,213)
Forfeited | shares	(23,808)
Outstanding at end of year | shares	1,530,338
Weighted-average Grant Date Fair Value
Outstanding at beginning of year | $ / shares	$ 22.26
Granted | $ / shares	21.78
Vested | $ / shares	23.40
Forfeited | $ / shares	22.34
Outstanding at end of year | $ / shares	$ 21.41

Additional Information on Non-v

Additional Information on Non-vested Restricted Stock (Detail) - Restricted Stock Awards $ in Millions	12 Months Ended
	Dec. 31, 2017USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate intrinsic value	$ 34
Weighted-average remaining vesting period	1 year 3 months 18 days
Unrecognized compensation cost	$ 19.6

Restricted Stock Unit Activity

Restricted Stock Unit Activity (Detail) - Restricted Stock Units (RSUs)	12 Months Ended
	Dec. 31, 2017$ / sharesshares
Shares
Outstanding at beginning of year | shares	191,655
Granted | shares	1,238,692
Assumed | shares	505,551	[1]
Vested | shares	(549,451)
Forfeited | shares	(49,174)
Outstanding at end of year | shares	1,337,273
Weighted-average Grant Date Fair Value
Outstanding at beginning of year | $ / shares	$ 19.85
Granted | $ / shares	19.85
Assumed | $ / shares	22.45	[1]
Vested | $ / shares	22.24
Forfeited | $ / shares	21.26
Outstanding at end of year | $ / shares	$ 19.80
[1]	Restricted stock unit awards under the Seventy Seven Energy Inc. 2016 Omnibus Incentive Plan, which was adopted, assumed, amended and renamed by the Company in connection with the SSE merger. No additional awards will be made under this plan.

Performance Units (Detail)

Performance Units (Detail)	12 Months Ended
	Dec. 31, 2017shares
2,017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	186,198
2,016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	185,000
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

Fair Value of Performance Units

Fair Value of Performance Units (Detail) - Performance Units Awards $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)
2,017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	$ 5,780
2,016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	3,854
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

Compensation Expense Associated

Compensation Expense Associated with Performance Units (Detail) - Performance Units Awards - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
2,017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	$ 1,284
2,016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	1,285	$ 963
2,015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	1,351	1,351	$ 1,013
2,014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	$ 449	1,796	1,796
2,013
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units		$ 464	1,855
2,012
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units			$ 255

Leases - Additional Information

Leases - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Leases [Abstract]
Rent expense	$ 48.9	$ 25.3	$ 37.6

Summary of Future Minimum Renta

Summary of Future Minimum Rental Payments Under Operating Leases (Detail) $ in Thousands	Dec. 31, 2017USD ($)
Leases [Abstract]
2,018	$ 13,616
2,019	9,368
2,020	7,112
2,021	5,165
2,022	3,844
Thereafter	8,917
Total	$ 48,022

Components of Income Tax Provis

Components of Income Tax Provision (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Federal income tax benefit:
Current	$ (42)	$ (24,777)	$ (42,020)
Deferred	(335,106)	(134,592)	(83,812)
Federal income tax benefit, Total	(335,148)	(159,369)	(125,832)
State income tax expense (benefit):
Current	(215)	(257)	(3,480)
Deferred	4,511	(14,163)	(12,433)
State and Local Income Tax Expense (Benefit), Continuing Operations, Total	4,296	(14,420)	(15,913)
Foreign income tax expense (benefit):
Current	(3,108)	(368)	(2,590)
Deferred	249	(3,405)	(3,628)
Foreign Income Tax Expense (Benefit), Continuing Operations, Total	(2,859)	(3,773)	(6,218)
Total income tax benefit:
Current	(3,365)	(25,402)	(48,090)
Deferred	(330,346)	(152,160)	(99,873)
Total income tax benefit:	$ (333,711)	$ (177,562)	$ (147,963)

Difference Between Statutory Fe

Difference Between Statutory Federal Income Tax Rate and Effective Income Rate (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Tax Disclosure [Abstract]
Statutory tax rate	35.00%	35.00%	35.00%
State income taxes - net of the federal income tax benefit	1.90%	2.00%	2.10%
Permanent differences	(1.30%)	(0.10%)	(1.30%)
One-time tax effects of tax reform	66.70%
Share-based payments	3.60%
Acquisition related differences	(3.30%)
Other differences, net	(0.80%)	(1.10%)	(2.40%)
Effective tax rate	101.80%	35.80%	33.40%

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	Dec. 22, 2017	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Income Taxes [Line Items]
Increase in effective tax rate			66.00%
Effective tax rate			101.80%	35.80%	33.40%
Increase in effective tax rate due to tax reform			66.70%
Increase for excess tax benefits from employee stock compensation deductions			3.60%
Decrease in effective tax rate for acquisitions			3.30%
U.S. federal corporate tax rate			35.00%	35.00%	35.00%
Income tax expense benefit			$ (333,711,000)	$ (177,562,000)	$ (147,963,000)
Individual compensation deductable limit under Section 162 (m)			1,000,000
Maximum compensation paid to covered employees			1,000,000
Additional taxes recorded from remeasurement of deferred tax assets and liabilities			11,000,000
Other deferred tax assets			27,100,000
Other deferred tax liabilities			10,900,000
Gross federal net operating losses			1,100,000,000
Canadian net operating losses			19,200,000
Post-apportionment state net operating losses			678,000,000
Unrecognized tax benefits			0
Accounting Standards Update No. 2016-09
Income Taxes [Line Items]
Excess tax benefits from share-based compensations awards vested or exercised			$ 12,000,000
Tax Years Beginning After December 31, 2017
Income Taxes [Line Items]
GIL TI effective tax rate	10.50%
Tax Years Beginning After December 31, 2025
Income Taxes [Line Items]
GIL TI effective tax rate	13.125%
Tax reform
Income Taxes [Line Items]
U.S. federal corporate tax rate			35.00%
Income tax expense benefit			$ 219,000,000
Percentage of dividends received deduction due to tax reform			100.00%
Canada
Income Taxes [Line Items]
Tax periods open for examination			Tax years ended December 31, 2013 through December 31, 2016
Canada | Prior Years
Income Taxes [Line Items]
Net operating losses carried forward			$ 11,000,000
Canada | Earliest Tax Year
Income Taxes [Line Items]
Tax period open for examination			2,013
Canada | Latest Tax Year
Income Taxes [Line Items]
Tax period open for examination			2,016
Federal, State and Canadian | Expire in 2023
Income Taxes [Line Items]
Net operating losses carried forward			$ 137,000
Federal, State and Canadian | Expire in 2025
Income Taxes [Line Items]
Net operating losses carried forward			2,800,000
Federal, State and Canadian | Expire in 2024
Income Taxes [Line Items]
Net operating losses carried forward			2,400,000
Federal, State and Canadian | Expire in 2026
Income Taxes [Line Items]
Net operating losses carried forward			17,400,000
Federal, State and Canadian | Expire in 2027
Income Taxes [Line Items]
Net operating losses carried forward			102,000
Federal, State and Canadian | Expire in 2029
Income Taxes [Line Items]
Net operating losses carried forward			33,200,000
Federal, State and Canadian | Expire in 2030
Income Taxes [Line Items]
Net operating losses carried forward			28,600,000
Federal, State and Canadian | Expire in 2031
Income Taxes [Line Items]
Net operating losses carried forward			101,900,000
Federal, State and Canadian | Expire in 2032
Income Taxes [Line Items]
Net operating losses carried forward			9,700,000
Federal, State and Canadian | Expire in 2034
Income Taxes [Line Items]
Net operating losses carried forward			30,000
Federal, State and Canadian | Expire in 2035
Income Taxes [Line Items]
Net operating losses carried forward			302,700,000
Federal, State and Canadian | Expire in 2036
Income Taxes [Line Items]
Net operating losses carried forward			644,600,000
Federal, State and Canadian | Expire in 2037
Income Taxes [Line Items]
Net operating losses carried forward			647,100,000
State and Local Jurisdiction | Prior Years
Income Taxes [Line Items]
Net operating losses carried forward			$ 1,000,000
U.S.
Income Taxes [Line Items]
Tax periods open for examination			Tax years ended December 31, 2013 through December 31, 2016
U.S. | Earliest Tax Year
Income Taxes [Line Items]
Tax period open for examination			2,013
U.S. | Latest Tax Year
Income Taxes [Line Items]
Tax period open for examination			2,016
Scenario Forecast | Tax reform
Income Taxes [Line Items]
U.S. federal corporate tax rate		21.00%

Tax Effect of Significant Tempo

Tax Effect of Significant Temporary Differences Representing Deferred Tax Assets and Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax assets	$ 359,073	$ 274,973
Total deferred tax liabilities	(706,034)	(921,510)
Net deferred tax liability	(346,961)	(646,537)
Net Operating Loss Carryforwards
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax assets	285,542	203,485
Alternative Minimum Tax Credit
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax assets	7,907	7,907
Scientific Research and Experimental Development Tax Credit
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax assets	898
Workers Compensation Allowance
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax assets	19,662	26,157
Expense Associated with Stock Options and Restricted Stock
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax assets	12,338	17,116
Federal benefit of state deferred tax liabilities
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax assets	5,660	5,310
All Other
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax assets	27,066	14,998
Total deferred tax liabilities	(10,923)	(9,538)
Property and equipment basis difference
Schedule of Deferred Income Tax Assets and Liabilities [Line Items]
Total deferred tax liabilities	$ (695,111)	$ (911,972)

Employee Benefits - Additional

Employee Benefits - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Compensation And Retirement Disclosure [Abstract]
Cash contributions to 401(K) plan	$ 8.7	$ 4.4	$ 7.1

Business Segments - Additional

Business Segments - Additional Information (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2017USD ($)RigsSegmentCustomer	Dec. 31, 2016USD ($)Customer	Dec. 31, 2015USD ($)Customer
Segment Reporting Disclosure [Line Items]
Number of reportable business segments | Segment	3
Long-lived assets	$ 4,254,730	$ 3,408,963
Major Customer
Segment Reporting Disclosure [Line Items]
Revenues		$ 124,000	$ 244,000
Number of customers accounted for 10% or more of consolidated revenues | Customer	0	1	1
Major Customer | Revenues | Customer Concentration Risk
Segment Reporting Disclosure [Line Items]
Percentage of sales revenues		14.00%	13.00%
Contract Drilling
Segment Reporting Disclosure [Line Items]
Marketable land-based drilling rigs | Rigs	295
Oil and gas services	$ 1,040,033	$ 543,663	$ 1,153,892
Contract Drilling | Canada
Segment Reporting Disclosure [Line Items]
Oil and gas services	13,700	15,600	$ 37,500
Long-lived assets	$ 52,000	$ 44,000

Business Segments - Revenues (D

Business Segments - Revenues (Detail) - USD ($) $ in Thousands

3 Months Ended

12 Months Ended

Dec. 31, 2017

Sep. 30, 2017

Jun. 30, 2017

Mar. 31, 2017

Dec. 31, 2016

Sep. 30, 2016

Jun. 30, 2016

Mar. 31, 2016

Dec. 31, 2017

Dec. 31, 2016

Dec. 31, 2015

Segment Reporting Revenue Reconciling Item [Line Items]

Total revenues

$ 787,334

$ 684,989

$ 579,186

$ 305,175

$ 246,887

$ 206,133

$ 193,907

$ 268,939

$ 2,356,684

$ 915,866

$ 1,891,277

Other Operations

Segment Reporting Revenue Reconciling Item [Line Items]

Total revenues

[1]

76,781

18,299

24,931

Operating Segments | Contract Drilling

Segment Reporting Revenue Reconciling Item [Line Items]

Total revenues

1,041,492

544,196

1,155,565

Operating Segments | Pressure Pumping

Segment Reporting Revenue Reconciling Item [Line Items]

Total revenues

1,200,311

354,070

712,454

Operating Segments | Directional Drilling

Segment Reporting Revenue Reconciling Item [Line Items]

Total revenues

45,580

Intersegment Elimination

Segment Reporting Revenue Reconciling Item [Line Items]

Total revenues

[2]

$ (7,480)

$ (699)

$ (1,673)

[1]

Other operations includes the Company’s oilfield rental tools business, pipe handling components and related technology business, the oil and natural gas working interests and the Middle East/North Africa activities.

[2]

In 2017, intercompany revenues consists of contract drilling and revenues from other operations for services provided to contract drilling, pressure pumping and within other operations. In 2016, intercompany revenues consists of contract drilling and revenues within other operations. In 2015, intercompany revenues only consisted of contract drilling.

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, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		$ (21,647)	$ (38,016)	$ (140,236)	$ (92,639)	$ (113,226)	$ (123,409)	$ (124,332)	$ (95,259)	$ (292,538)	$ (456,226)	$ (406,972)
Other operating income (expense), net	[1]									31,957	14,323	(1,647)
Interest income										1,866	327	964
Interest expense										(37,472)	(40,366)	(36,475)
Other										343	69	34
Loss before income taxes										(327,801)	(496,196)	(442,449)
Other Operations
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(20,813)	(3,391)	(14,269)
Corporate
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(152,792)	(54,672)	(57,088)
Operating Segments | Contract Drilling
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(171,897)	(235,858)	(78,970)
Operating Segments | Pressure Pumping
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										21,028	$ (176,628)	$ (254,998)
Operating Segments | Directional Drilling
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										$ (21)
[1]	Other operating income (expense), net includes 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. This caption also includes expenses related to certain legal settlements net of insurance reimbursements.

Business Segments - Assets (Det

Business Segments - Assets (Detail) - USD ($) $ in Thousands		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		$ 5,758,856	$ 3,772,291	$ 4,465,048
Other Operations
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		172,094	48,885	38,726
Corporate
Segment Reporting Asset Reconciling Item [Line Items]
Total assets	[1]	144,069	36,957	155,574
Operating Segments | Contract Drilling
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		3,931,994	3,032,819	3,457,044
Operating Segments | Pressure Pumping
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		1,209,424	$ 653,630	$ 813,704
Operating Segments | Directional Drilling
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		$ 301,275
[1]	Corporate assets primarily include cash on hand, income tax receivables, certain property and equipment, and certain deferred tax assets.

Business Segments - Depreciatio

Business Segments - Depreciation, Amortization and Improvement (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	$ 783,341	$ 668,434	$ 864,759
Other Operations
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	29,402	10,114	26,301
Corporate
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	7,695	5,474	5,472
Operating Segments | Contract Drilling
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	538,891	467,974	618,434
Operating Segments | Pressure Pumping
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	198,006	$ 184,872	$ 214,552
Operating Segments | Directional Drilling
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	$ 9,347

Business Segments - Capital Exp

Business Segments - Capital Expenditures (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Segment Reporting Information [Line Items]
Capital expenditures	$ 567,087	$ 119,799	$ 743,776
Other Operations
Segment Reporting Information [Line Items]
Capital expenditures	31,547	6,116	16,625
Corporate
Segment Reporting Information [Line Items]
Capital expenditures	1,884	1,591	2,520
Operating Segments | Contract Drilling
Segment Reporting Information [Line Items]
Capital expenditures	354,425	72,508	527,054
Operating Segments | Pressure Pumping
Segment Reporting Information [Line Items]
Capital expenditures	171,436	$ 39,584	$ 197,577
Operating Segments | Directional Drilling
Segment Reporting Information [Line Items]
Capital expenditures	$ 7,795

Company's Demand Deposits and T

Company's Demand Deposits and Temporary Cash Investments (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015	Dec. 31, 2014
Risks And Uncertainties [Abstract]
Deposits in FDIC and SIPC-insured institutions under insurance limits	$ 13,860	$ 846
Deposits in FDIC and SIPC-insured institutions over insurance limits	106,849	12,866
Deposits in foreign banks	21,479	27,557
Total cash and cash equivalents	142,188	41,269
Less outstanding checks and other reconciling items	(99,360)	(6,117)
Cash and cash equivalents	$ 42,828	$ 35,152	$ 113,346	$ 43,012

Concentrations of Credit Risk -

Concentrations of Credit Risk - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Risks And Uncertainties [Abstract]
Expense for bad debts	$ 0	$ 0	$ 0

Estimated Fair Value of Outstan

Estimated Fair Value of Outstanding Debt Balances (Detail) - USD ($) $ in Thousands	Dec. 31, 2017	Dec. 31, 2016
Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	$ 868,000	$ 600,000
Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	867,582	546,728
Revolving Credit Facility | Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	268,000
Revolving Credit Facility | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	268,000
4.97% Series A Senior Notes, Due October 5th 2020 | Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	300,000	300,000
4.97% Series A Senior Notes, Due October 5th 2020 | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	303,966	283,534
4.27% Series B Senior Notes, Due June 14th 2022 | Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	300,000	300,000
4.27% Series B Senior Notes, Due June 14th 2022 | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	$ 295,616	$ 263,194

Fair Values of Financial Inst97

Fair Values of Financial Instruments - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2017	Dec. 31, 2016
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	4.46%	6.65%
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	4.64%	7.02%

Quarterly Financial Informati98

Quarterly Financial Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2017	Sep. 30, 2017	Jun. 30, 2017	Mar. 31, 2017	Dec. 31, 2016	Sep. 30, 2016	Jun. 30, 2016	Mar. 31, 2016	Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Quarterly Financial Information Disclosure [Abstract]
Operating revenues	$ 787,334	$ 684,989	$ 579,186	$ 305,175	$ 246,887	$ 206,133	$ 193,907	$ 268,939	$ 2,356,684	$ 915,866	$ 1,891,277
Operating income (loss)	(21,647)	(38,016)	(140,236)	(92,639)	(113,226)	(123,409)	(124,332)	(95,259)	(292,538)	(456,226)	(406,972)
Net income (loss)	$ 195,402	$ (33,769)	$ (92,184)	$ (63,539)	$ (78,122)	$ (84,143)	$ (85,866)	$ (70,503)	$ 5,910	$ (318,634)	$ (294,486)
Net income (loss) per common share:
Basic	$ 0.88	$ (0.16)	$ (0.46)	$ (0.40)	$ (0.53)	$ (0.58)	$ (0.58)	$ (0.48)	$ 0.03	$ (2.18)	$ (2)
Diluted	$ 0.88	$ (0.16)	$ (0.46)	$ (0.40)	$ (0.53)	$ (0.58)	$ (0.58)	$ (0.48)	$ 0.03	$ (2.18)	$ (2)

Valuation and Qualifying Acco99

Valuation and Qualifying Accounts (Detail) - Allowance for Doubtful Accounts - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2017	Dec. 31, 2016	Dec. 31, 2015
Valuation And Qualifying Accounts Disclosure [Line Items]
Beginning Balance		$ 3,191	$ 3,545	$ 3,546
Deductions	[1]	(868)	(354)	(1)
Ending Balance		$ 2,323	$ 3,191	$ 3,545
[1]	Consists of uncollectible accounts written off