Patterson-UTI Energy (PTEN) 10-K 13 Feb 20 2019 FY Annual report Financial data

Document and Entity Information

Document and Entity Information - USD ($) $ in Billions	12 Months Ended
	Dec. 31, 2019	Feb. 07, 2020	Jun. 28, 2019
Cover [Abstract]
Document Type	10-K
Amendment Flag	false
Document Period End Date	Dec. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	FY
Trading Symbol	PTEN
Security Exchange Name	NASDAQ
Title of 12(b) Security	Common Stock, $0.01 Par Value
Entity Registrant Name	Patterson-UTI Energy, Inc.
Entity Central Index Key	0000889900
Entity Interactive Data Current	Yes
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 Small Business	false
Entity Emerging Growth Company	false
Entity Shell Company	false
Entity Common Stock, Shares Outstanding		192,151,761
Entity Public Float			$ 2.3
Document Annual Report	true
Document Transition Report	false
Entity File Number	0-22664
Entity Tax Identification Number	75-2504748
Entity Address, Address Line One	10713 W. Sam Houston Pkwy N
Entity Address, Address Line Two	Suite 800
Entity Address, City or Town	Houston
Entity Address, State or Province	TX
Entity Incorporation, State or Country Code	DE
Entity Address, Postal Zip Code	77064
City Area Code	(281)
Local Phone Number	765-7100
Documents Incorporated by Reference	Documents incorporated by reference: Portions of the registrant’s definitive proxy statement for the 2020 Annual Meeting of Stockholders are incorporated by reference into Part III of this report.

CONSOLIDATED BALANCE SHEETS

CONSOLIDATED BALANCE SHEETS - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 174,185	$ 245,029
Accounts receivable, net of allowance for doubtful accounts of $6,516 and $2,312 at December 31, 2019 and 2018, respectively	339,699	558,817
Federal and state income taxes receivable	6,397	4,110
Inventory	36,357	65,579
Other	75,177	76,662
Total current assets	631,815	950,197
Property and equipment, net	3,306,677	4,002,549
Right of use asset	31,275
Goodwill and intangible assets	444,004	477,640
Deposits on equipment purchases	8,066	12,040
Other	17,778	27,440
Total assets	4,439,615	5,469,866
Current liabilities:
Accounts payable	170,475	288,962
Federal and state income taxes payable	342	1,408
Accrued liabilities	219,850	235,946
Lease liability	9,935
Total current liabilities	400,602	526,316
Long-term lease liability	26,644
Long-term debt, net of debt discount and issuance costs of $8,460 and $5,795 at December 31, 2019 and 2018, respectively	966,540	1,119,205
Deferred tax liabilities, net	202,959	306,161
Other	9,250	12,761
Total liabilities	1,605,995	1,964,443
Commitments and contingencies (see Note 9)
Stockholders’ equity:
Preferred stock, par value $.01; authorized 1,000,000 shares, no shares issued
Common stock, par value $.01; authorized 400,000,000 shares with 269,372,257 and 267,315,526 issued and 192,035,870 and 213,614,430 outstanding at December 31, 2019 and 2018, respectively	2,694	2,673
Additional paid-in capital	2,875,680	2,827,154
Retained earnings	1,294,902	1,753,557
Accumulated other comprehensive income	5,478	2,487
Treasury stock, at cost, 77,336,387 shares and 53,701,096 shares at December 31, 2019 and 2018, respectively	(1,345,134)	(1,080,448)
Total stockholders’ equity	2,833,620	3,505,423
Total liabilities and stockholders’ equity	$ 4,439,615	$ 5,469,866

CONSOLIDATED BALANCE SHEETS (Pa

CONSOLIDATED BALANCE SHEETS (Parenthetical) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 6,516	$ 2,312
Long-term debt, debt discount and issuance costs	$ 8,460	$ 5,795
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	400,000,000	400,000,000
Common stock, issued	269,372,257	267,315,526
Common stock, outstanding	192,035,870	213,614,430
Treasury stock, shares	77,336,387	53,701,096

CONSOLIDATED STATEMENTS OF OPER

CONSOLIDATED STATEMENTS OF OPERATIONS - USD ($) shares in Thousands		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Operating revenues:
Total operating revenues		$ 2,470,685,000	$ 3,326,997,000	$ 2,356,684,000
Operating costs and expenses:
Depreciation, depletion, amortization and impairment		1,003,873,000	916,318,000	783,341,000
Impairment of goodwill		17,800,000	211,129,000
Selling, general and administrative		133,513,000	134,071,000	105,847,000
Provision for bad debts		5,683,000	0	0
Merger and integration expenses			2,738,000	74,451,000
Other operating income, net	[1]	(2,305,000)	(17,569,000)	(31,957,000)
Total operating costs and expenses		2,932,261,000	3,649,174,000	2,649,222,000
Operating loss		(461,576,000)	(322,177,000)	(292,538,000)
Other income (expense):
Interest income		6,013,000	5,597,000	1,866,000
Interest expense, net of amount capitalized		(75,204,000)	(51,578,000)	(37,472,000)
Other		389,000	750,000	343,000
Total other expense		(68,802,000)	(45,231,000)	(35,263,000)
Loss before income taxes		(530,378,000)	(367,408,000)	(327,801,000)
Income tax benefit		(104,675,000)	(45,987,000)	(333,711,000)
Net income (loss)		$ (425,703,000)	$ (321,421,000)	$ 5,910,000
Net income (loss) per common share:
Basic		$ (2.10)	$ (1.47)	$ 0.03
Diluted		$ (2.10)	$ (1.47)	$ 0.03
Weighted average number of common shares outstanding:
Basic		203,039	218,643	198,447
Diluted		203,039	218,643	199,882
Contract Drilling
Operating revenues:
Total operating revenues		$ 1,308,350,000	$ 1,430,492,000	$ 1,040,033,000
Operating costs and expenses:
Operating costs and expenses		785,355,000	885,704,000	667,105,000
Impairment of goodwill		0	0
Pressure Pumping
Operating revenues:
Total operating revenues		868,694,000	1,573,396,000	1,200,311,000
Operating costs and expenses:
Operating costs and expenses		724,788,000	1,263,850,000	966,835,000
Impairment of goodwill			121,444,000
Directional Drilling
Operating revenues:
Total operating revenues		188,786,000	209,275,000	45,580,000
Operating costs and expenses:
Operating costs and expenses		178,645,000	175,829,000	32,172,000
Impairment of goodwill			89,685,000
Other
Operating revenues:
Total operating revenues		104,855,000	113,834,000	70,760,000
Operating costs and expenses:
Operating costs and expenses		$ 84,909,000	$ 77,104,000	$ 51,428,000
[1]	Other operating income, net includes net gains associated with the disposal of assets related to corporate strategy decisions of the executive management group. Accordingly, the related gains have been excluded from the operating results of specific segments. This caption also includes certain legal-related expenses and settlements, net of insurance reimbursements and certain research and development expenses

CONSOLIDATED STATEMENTS OF COMP

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Statement Of Income And Comprehensive Income [Abstract]
Net income (loss)	$ (425,703)	$ (321,421)	$ 5,910
Other comprehensive income (loss), net of taxes of $0 for 2019, $0 for 2018 and $0 for 2017:
Foreign currency translation adjustment	2,991	(4,335)	7,956
Total comprehensive income (loss)	$ (422,712)	$ (325,756)	$ 13,866

CONSOLIDATED STATEMENTS OF CO_2

CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS) (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
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, 2016	$ 2,248,724	$ 1,915	$ 1,042,696	$ 2,116,341	$ (1,134)	$ (911,094)
Beginning Balance (in shares) at Dec. 31, 2016		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
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		266,259,000
Net income (loss)	(321,421)			(321,421)
Foreign currency translation adjustment	(4,335)				(4,335)
Restricted stock issued for acquisition	2,932	$ 2	2,930
Restricted stock issued for acquisition (in shares)		192,000
Issuance of restricted stock		$ 4	(4)
Issuance of restricted stock (in shares)		381,000
Vesting of restricted stock units		$ 5	(5)
Vesting of restricted stock units (in shares)		452,000
Forfeitures of restricted stock (in shares)		(8,000)
Exercise of stock options	485		485
Exercise of stock options (in shares)		40,000
Stock-based compensation	37,925		37,925
Payment of cash dividends	(30,589)			(30,589)
Dividend equivalents	(330)			(330)
Purchase of treasury stock	(161,737)					(161,737)
Ending Balance at Dec. 31, 2018	$ 3,505,423	$ 2,673	2,827,154	1,753,557	2,487	(1,080,448)
Ending Balance (in shares) at Dec. 31, 2018	267,315,526	267,316,000
Net income (loss)	$ (425,703)			(425,703)
Foreign currency translation adjustment	2,991				2,991
Issuance of restricted stock		$ 2	(2)
Issuance of restricted stock (in shares)		185,000
Vesting of restricted stock units		$ 12	(12)
Vesting of restricted stock units (in shares)		1,173,000
Forfeitures of restricted stock (in shares)		(2,000)
Exercise of stock options	$ 9,219	$ 7	9,212
Exercise of stock options (in shares)	700,000	700,000
Stock-based compensation	$ 39,328		39,328
Payment of cash dividends	(32,428)			(32,428)
Dividend equivalents	(524)			(524)
Purchase of treasury stock	(264,686)					(264,686)
Ending Balance at Dec. 31, 2019	$ 2,833,620	$ 2,694	$ 2,875,680	$ 1,294,902	$ 5,478	$ (1,345,134)
Ending Balance (in shares) at Dec. 31, 2019	269,372,257	269,372,000

CONSOLIDATED STATEMENTS OF CASH

CONSOLIDATED STATEMENTS OF CASH FLOWS - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Cash flows from operating activities:
Net income (loss)	$ (425,703,000)	$ (321,421,000)	$ 5,910,000
Adjustments to reconcile net income (loss) to net cash provided by operating activities:
Depreciation, depletion, amortization and impairment	1,003,873,000	916,318,000	783,341,000
Impairment of goodwill	17,800,000	211,129,000
Dry holes and abandonments	109,000	915,000	1,929,000
Deferred income tax benefit	(103,202,000)	(41,185,000)	(330,346,000)
Stock-based compensation expense	39,328,000	37,925,000	44,483,000
Net gain on asset disposals	(13,904,000)	(28,958,000)	(33,510,000)
Write-down of capacity reservation contract	12,673,000
Provision for bad debts	5,683,000	0	0
Loss on early debt extinguishment	24,023,000
Amortization of debt discount and issuance costs	937,000	830,000	346,000
Changes in operating assets and liabilities:
Accounts receivable	213,588,000	23,515,000	(239,482,000)
Income taxes receivable/payable	(3,353,000)	(1,555,000)	990,000
Inventory and other assets	29,394,000	(1,470,000)	(23,449,000)
Accounts payable	(77,686,000)	(69,453,000)	104,072,000
Accrued expenses	(18,218,000)	4,136,000	(14,190,000)
Other liabilities	(9,139,000)	(56,000)	617,000
Net cash provided by operating activities	696,203,000	730,670,000	300,711,000
Cash flows from investing activities:
Acquisitions, net of cash acquired	(13,000)	(14,211,000)	(501,954,000)
Purchases of property and equipment	(347,512,000)	(641,458,000)	(567,087,000)
Proceeds from disposal of assets and insurance claims	45,761,000	47,357,000	60,945,000
Collection of note receivable		23,760,000
Other investments			(2,520,000)
Net cash used in investing activities	(301,764,000)	(584,552,000)	(1,010,616,000)
Cash flows from financing activities:
Proceeds from equity offering			471,570,000
Purchases of treasury stock	(255,467,000)	(161,737,000)	(6,809,000)
Dividends paid	(32,428,000)	(30,589,000)	(16,315,000)
Proceeds from long-term debt	496,969,000	521,194,000
Repayment of long-term debt	(673,443,000)
Proceeds from borrowings under revolving credit facility		79,000,000	599,000,000
Repayment of borrowings under revolving credit facility		(347,000,000)	(331,000,000)
Debt issuance costs	(852,000)	(4,489,000)
Proceeds from exercise of stock options		485,000	123,000
Net cash provided by (used in) financing activities	(465,221,000)	56,864,000	716,569,000
Effect of foreign exchange rate changes on cash	(62,000)	(781,000)	1,012,000
Net increase (decrease) in cash and cash equivalents	(70,844,000)	202,201,000	7,676,000
Cash and cash equivalents at beginning of year	245,029,000	42,828,000	35,152,000
Cash and cash equivalents at end of year	174,185,000	245,029,000	42,828,000
Net cash (paid) received during the year for:
Interest, net of capitalized interest of $732 in 2019, $1,435 in 2018 and $1,175 in 2017	(76,870,000)	(41,184,000)	(34,953,000)
Income taxes	(1,452,000)	3,172,000	3,947,000
Non-cash investing and financing activities:
Receivable from property and equipment insurance		15,000,000
Net increase (decrease) in payables for purchases of property and equipment	(40,857,000)	36,241,000	17,228,000
Issuance of common stock for business acquisitions		2,932,000	1,226,890,000
Net decrease (increase) in deposits on equipment purchases	3,974,000	$ 4,311,000	$ (301,000)
Cashless exercise of stock options	$ 9,219,000

CONSOLIDATED STATEMENTS OF CA_2

CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Statement Of Cash Flows [Abstract]
Interest expense, capitalized interest	$ 732	$ 1,435	$ 1,175

Description of Business and Sum

Description of Business and Summary of Significant Accounting Policies	12 Months Ended
	Dec. 31, 2019
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”), is a Houston, Texas-based oilfield services company that primarily owns and operates in the United States one of the largest fleets of land-based drilling rigs and a large fleet of pressure pumping equipment. The Company’s contract drilling business operates in the continental United States and western Canada, and the Company is pursuing contract drilling opportunities outside of North America. The Company’s pressure pumping business operates primarily in Texas and the Mid-Continent and Appalachian regions. The Company also provides a comprehensive suite of directional drilling services in most major producing onshore oil and gas basins in the United States, and the Company provides services that improve the statistical accuracy of horizontal wellbore placement. The Company has other operations through which the Company provides oilfield rental tools in select markets in the United States. The Company also services equipment for drilling contractors, and provides electrical controls and automation to the energy, marine and mining industries, 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. As used in these notes, “the Company” refers collectively to Patterson-UTI Energy, Inc. and its consolidated subsidiaries. Patterson-UTI Energy, Inc. conducts its business operations through its wholly-owned subsidiaries and has no employees or independent operations. The U.S. dollar is the functional currency for all of the Company’s operations except for its Canadian operations, which use the Canadian dollar as their functional currency. The effects of exchange rate changes are reflected in accumulated other comprehensive income, which is a separate component of stockholders’ equity. A summary of the significant accounting policies follows: Management estimates — The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“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 the Company’s contract drilling, pressure pumping, directional drilling, oilfield rentals, equipment servicing and electrical control and automation activities are recognized as services are performed. All of the wells the Company drilled in 2019, 2018 and 2017 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. On January 1, 2018, the Company adopted the new revenue guidance under Topic 606, Revenue from Contracts with Customers Leases — T he Company enters operating leases for operating locations, corporate offices and certain operating equipment. As of December 31, 2019, the Company does not have any finance leases. On January 1, 2019, the Company adopted the new lease guidance under Topic 842, Leases 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 uncollectible, 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 equipment servicing 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 $39.0 million and $35.6 million at December 31, 2019 and 2018, 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. Impairment expense related to oil and natural gas properties of approximately $2.2 million, $1.0 million and $4.3 million was recorded for the years ended December 31, 2019, 2018 and 2017, respectively. 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. Income taxes — The asset and liability method is used in accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for operating loss and tax credit carryforwards and for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the results of operations in the period that includes the enactment date. If applicable, a valuation allowance is recorded to reduce the carrying amounts of deferred tax assets unless it is more likely than not that such assets will be realized. The Company’s policy is to account for interest and penalties with respect to income taxes as operating expenses. Stock-based compensation — The Company recognizes the cost of share-based payments under the fair-value-based method. Under this method, compensation cost related to share-based payments is measured based on the estimated fair value of the awards at the date of grant, net of estimated forfeitures. This expense is recognized over the expected life of the awards (See Note 11). 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 Adopted Accounting Standards — In May 2014, the Financial Accounting Standards Board (“FASB”) issued an accounting standards update to provide guidance on the recognition of revenue from customers. Under this guidance, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects what it expects in exchange for the goods or services. This guidance also requires more detailed disclosures to enable users of the financial statements to understand the nature, amount, timing and uncertainty, if any, of revenue and cash flows arising from contracts with customers. The Company adopted this new revenue guidance effective January 1, 2018, utilizing the modified retrospective method, and expanded its consolidated financial statement disclosures in order to comply with the update (See Note 3). 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 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 Company adopted this new leasing guidance effective January 1, 2019 and expanded its consolidated financial statement disclosures in order to comply with the update (See Note 12). The adoption of this standard resulted in the recording of operating lease right of use assets of approximately $31.0 million and operating lease liabilities of approximately $35.8 million as of January 1, 2019. 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. The Company adopted this guidance effective January 1, 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 issued in the case of stock option exercises. In August 2016, the FASB issued an accounting standards update 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 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. 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. In March 2018, the FASB issued an accounting standards update to update the income tax accounting in U.S. GAAP to reflect the SEC interpretive guidance released on December 22, 2017, when significant U.S. tax law changes were enacted with the enactment of “H.R.1,” also known as the “Tax Cuts and Jobs Act” (“U.S. Tax Reform”). The adoption of this update in March 2018 did not have a material impact on the Company’s consolidated financial statements, as the Company was already following the SEC guidance (See Note 13). Recently Issued Accounting Standards — In June 2016, the FASB issued an accounting standards update on measurement of credit losses on financial instruments. This update improves financial reporting by requiring earlier recognition of credit losses on financing receivables and other financial assets in scope by using the Current Expected Credit Losses model (CECL). The CECL model utilizes a lifetime expected credit loss measurement objective for the recognition of credit losses on financial instruments at the time the asset is originated or acquired. This update will apply to receivables arising from revenue transactions such as contract assets and accounts receivables. This update is effective for interim and annual periods beginning after December 15, 2019, with early adoption permitted. The Company will adopt this new guidance on January 1, 2020 and does not expect this new guidance will have a material impact on its consolidated financial statements. In August 2018, the FASB issued an accounting standards update to align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The capitalized implementation costs of a hosting arrangement that is a service contract will be expensed over the term of the hosting arrangement. The Company will adopt this new guidance on January 1, 2020 In August 2018, the FASB issued an accounting standards update to eliminate certain disclosure requirements for fair value measurements for all entities, require public entities to disclose certain new information and modify certain disclosure requirements. The FASB developed the amendments to Topic 820 as part of its broader disclosure framework project, which aims to improve the effectiveness of disclosures in the notes to financial statements by focusing on requirements that clearly communicate the most important information to users of the financial statements. This update is effective for interim and annual periods beginning after December 15, 2019, with early adoption permitted. The Company will adopt this new guidance on January 1, 2020 and does not expect this new guidance will have a material impact on its In December 2019, the FASB issued an accounting standards update to simplify the accounting for income taxes. The amendments in the update are effective for public business entities for fiscal years beginning after December 15, 2020, with early adoption permitted. The Company plans to adopt this guidance on January 1, 2021 and is currently evaluating the impact of adoption on its consolidated financial statements. During the third quarter of 2019, the Company identified and recorded out-of-period adjustments primarily related to the accounting for inventory in its directional drilling segment. The Company concluded that these adjustments were not material to the consolidated financial statements for any of the current or prior periods presented. The net adjustment is reflected as a $6.6 million increase to “Loss before income taxes” in the consolidated statements of operations for the year ended December 31, 2019.

Acquisitions

Acquisitions	12 Months Ended
	Dec. 31, 2019
Business Combinations [Abstract]
Acquisitions	2. Acquisitions SSE On April 20, 2017, pursuant to a merger agreement, a subsidiary of the Company was merged with and into Seventy Seven Energy, Inc (“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 fracturing equipment. The oilfield rentals business acquired through the SSE merger has a 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. 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 following table represents the final 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 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, access to new geographies, access to new product lines, increased scale of operations, supply chain and corporate efficiencies as well as infrastructure optimization. The acquired goodwill was attributable to three operating segments, with $309 million to contract drilling, $121 million to pressure pumping and $6.3 million to oilfield rentals. A portion of the fair value consideration transferred has been 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, LLC (f/k/a Multi-Shot, LLC) (“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 was 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, 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. 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 following table represents the final 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 44,099 Other long-term liabilities 327 Total liabilities assumed 44,426 Net identifiable assets acquired 167,590 Goodwill 89,685 Total net assets acquired $ 257,275 The goodwill reflected above increased $1.0 million from the original preliminary purchase price allocation as a result of a measurement period adjustment that related to a valuation adjustment to accounts payable and accrued liabilities. The acquired goodwill was 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, access to new product lines, favorable market trends underlying these new business lines, earnings and growth opportunities and future technology development possibilities. All of the goodwill acquired was attributable to the directional drilling operating segment. See Note 6 for additional information regarding goodwill. A portion of the fair value consideration transferred has been 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 the Company’s 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 accounts for substantially all of the Company’s directional drilling segment, as disclosed in Note 16. 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 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 ) Current Power Solutions, Inc. (“Current Power”) During October 2018, the Company acquired Current Power. Current Power is a provider of electrical controls and automation to the energy, marine and mining industries. This acquisition was not material to the Company’s consolidated financial statements. Superior QC, LLC (“Superior QC”) During February 2018, the Company acquired the business of Superior QC, including its assets and intellectual property. Superior QC is a provider of software and services used to improve the statistical accuracy

Revenues

Revenues	12 Months Ended
	Dec. 31, 2019
Revenue From Contract With Customer [Abstract]
Revenues	3. Revenues ASC Topic 606 Revenue from Contracts with Customers On January 1, 2018, the Company adopted the new revenue guidance under Topic 606, Revenue from Contracts with Customers The Company’s contracts with customers include both long-term and short-term contracts. Services that primarily generate revenue earned for the Company include the operating business segments of contract drilling, pressure pumping and directional drilling which comprise the Company’s reportable segments. The Company also derives revenues from its other operations, which include the Company’s operating business segments of oilfield rentals, equipment servicing, electrical controls and automation, and oil and natural gas working interests. For more information on the Company’s business segments, see Note 16. Charges for services are considered a series of distinct services. Since each distinct service in a series would be satisfied over time if it were accounted for separately, and the entity would measure its progress towards satisfaction using the same measure of progress for each distinct service in the series, the Company is able to account for these integrated services as a single performance obligation that is satisfied over time. The transaction price is the amount of consideration to which the Company expects to be entitled in exchange for transferring promised goods or services to a customer, based on terms of the Company’s contracts with its customers. The consideration promised in a contract with a customer may include fixed amounts and/or variable amounts. Payments received for services are considered variable consideration as the time in service will fluctuate as the services are provided. Topic 606 provides an allocation exception, which allows the Company to allocate variable consideration to one or more distinct services promised in a series of distinct services that form part of a single performance obligation as long as certain criteria are met. These criteria state that the variable payment must relate specifically to the entity’s efforts to satisfy the performance obligation or transfer the distinct good or service, and allocation of the variable consideration is consistent with the standards’ allocation objective. Since payments received for services meet both of these criteria requirements, the Company recognizes revenue when the service is performed. An estimate of variable consideration should be constrained to the extent that it is not probable that a significant revenue reversal in the amount of cumulative revenue recognized will not occur when the uncertainty associated with the variable consideration is subsequently resolved. Payments received for other types of consideration are fully constrained as they are highly susceptible to factors outside the entity’s influence and therefore could be subject to a significant revenue reversal once resolved. As such, revenue received for these types of consideration is recognized when the service is performed. Estimates of variable consideration are subject to change as facts and circumstances evolve. As such, the Company will evaluate its estimates of variable consideration that are subject to constraints throughout the contract period and revise estimates, if necessary, at the end of each reporting period. The Company is a working interest owner of oil and natural gas properties located in Texas and New Mexico. The ownership terms are outlined in joint operating agreements for each well between the operator of the wells and the various interest owners, including the Company, who are considered non-operators of the well. The Company receives revenue each period for its working interest in the well during the period. The revenue received for the working interests from these oil and gas properties does not fall under the scope of the new revenue standard, and therefore, will continue to be reported under current guidance ASC 932-323 Extractive Activities – Oil and Gas, Investments – Equity Method and Joint Ventures. Reimbursement Revenue – 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. The Company’s disaggregated revenue recognized from contracts with customers is included in Note 16. Accounts Receivable and Contract Liabilities Accounts receivable is the Company’s right to consideration once it becomes unconditional. Payment terms typically range from 30 to 60 days. Accounts receivable balances were $336 million and $554 million as of December 31, 2019 and 2018, respectively. These balances do not include amounts related to the Company’s oil and gas working interests as those contracts are excluded from Topic 606. Accounts receivable balances are included in “Accounts Receivable” in the consolidated balance sheets. The Company does not have any significant contract asset balances, and as such, contract balances are not presented at the net amount at a contract level. Contract liabilities include prepayments received from customers prior to the requested services being completed. Once the services are complete and have been invoiced, the prepayment is applied against the customer’s account to offset the accounts receivable balance. Also included in contract liabilities are payments received from customers for the initial mobilization of newly constructed or upgraded rigs that were moved on location to the initial well site. These mobilization payments are allocated to the overall performance obligation and amortized over the initial term of the contract. During the year ended December 31, 2019 and 2018, approximately $1.0 million and $1.6 million , respectively, was amortized and recorded in drilling revenue. Total contract liability balances were $2.7 million and $7.6 million as of December 31, 2019 and December 31, 2018, respectively. Contract liability balances are included in “Accounts payable” and “Accrued liabilities” in the consolidated balance sheets. Contract Costs Costs incurred for newly constructed or rig upgrades based on a contract with a customer are considered capital improvements and are capitalized to drilling equipment and depreciated over the estimated useful life of the asset. Practical Expedients Adopted with Topic 606 The Company has elected to adopt the following practical expedients upon the transition date to Topic 606 on January 1, 2018: • Use of portfolio approach: An entity can apply this guidance to a portfolio of contracts (or performance obligations) with similar characteristics if the entity reasonably expects that the effects on the financial statements of applying this guidance to the portfolio would not differ materially from applying this guidance to the individual contracts (or performance obligations) within that portfolio. • Excluding disclosure about transaction price: As a practical expedient, an entity need not disclose the information for a performance obligation if either of the following conditions is met: a) The performance obligation is part of a contract that has an original expected duration of one year or less. b) The entity recognizes revenue from the satisfaction of the performance obligation. • Excluding sales taxes from the transaction price: The scope of this policy election is the same as the scope of the policy election under previous guidance. This election provides exclusion from the measurement of the transaction price all taxes assessed by a governmental authority that are both imposed on and concurrent with a specific revenue producing transaction and collected by the entity from a customer. • Costs of obtaining a contract: An entity can immediately expense costs of obtaining a contract if they would be amortized within a year.

Inventory

Inventory	12 Months Ended
	Dec. 31, 2019
Inventory Disclosure [Abstract]
Inventory	4. Inventory Inventory consisted of the following at December 31, 2019 and 2018 (in thousands): 2019 2018 Finished goods $ 105 $ 347 Work-in-process 1,229 6,375 Raw materials and supplies 35,023 58,857 Inventory $ 36,357 $ 65,579

Property and Equipment

Property and Equipment	12 Months Ended
	Dec. 31, 2019
Property Plant And Equipment [Abstract]
Property and Equipment	5. Property and Equipment Property and equipment consisted of the following at December 31, 2019 and 2018 (in thousands): 2019 2018 Equipment $ 8,114,326 $ 8,370,933 Oil and natural gas properties 226,646 219,855 Buildings 184,700 186,736 Land 25,747 26,144 Total property and equipment 8,551,419 8,803,668 Less accumulated depreciation, depletion and impairment (5,244,742 ) (4,801,119 ) Property and equipment, net $ 3,306,677 $ 4,002,549 Depreciation, depletion, amortization and impairment — The following table summarizes depreciation, depletion, amortization and impairment expense related to property and equipment, intangible assets and liabilities for 2019, 2018 and 2017 (in thousands): 2019 2018 2017 Depreciation and impairment expense $ 974,206 $ 887,155 $ 753,510 Amortization expense 17,722 18,197 21,764 Depletion expense 11,945 10,966 8,067 Total $ 1,003,873 $ 916,318 $ 783,341 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 inactive rigs to working condition and the expected demand for drilling services by rig type. 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 2019, the Company identified 36 legacy non-APEX® rigs and related equipment that would be retired. Based on the strong customer preference across the industry for super-spec drilling rigs, the Company believes the 36 rigs that were retired have limited commercial opportunity. The Company recorded a $173 million charge related to this retirement. In 2018, the Company identified 42 legacy non-APEX® rigs and related equipment that would be retired. Based on the strong customer preference across the industry for super-spec drilling rigs, the Company believes the 42 rigs that were retired had limited commercial opportunity. The Company recorded a $48.4 million charge related to this retirement. ecorded a 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 for marketability based on the condition of inactive equipment, expenditures that would be necessary to bring the equipment to working condition and the expected demand. The components of equipment that will no longer be marketed are evaluated, and those components with continuing utility will be used as parts to support active equipment. The remaining components of this equipment are retired. In 2019, the Company recorded a charge of $20.5 million for the write-down of pressure pumping equipment compared to a $17.4 million write-down of pressure pumping equipment in 2018. The Company also periodically evaluates its directional drilling assets. During 2019, the Company recorded a charge of $8.4 million for the write-down of directional drilling equipment. There were no similar charges in 2018 or 2017. The Company reviews its long-lived assets, including property and equipment, for impairment whenever events or changes in circumstances indicate that the 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. 2019 Triggering Event Assessment Due to the decline in the market price of the Company’s common stock and recent commodity prices, the Company’s results of operations for the quarter ended September 30, 2019 and management’s expectations of operating results in future periods, the Company lowered its expectations with respect to future activity levels in certain of its operating segments. The Company deemed it necessary to assess the recoverability of its contract drilling, pressure pumping, directional drilling and oilfield rentals asset groups as of September 30, 2019. The Company performed an analysis as required by ASC 360-10-35 to assess the recoverability of the asset groups within its contract drilling, pressure pumping, directional drilling and oilfield rentals operating segments as of September 30, 2019. With respect to these asset groups, 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 asset groups, and no impairment was indicated. Expected cash flows, on an undiscounted basis, exceeded the carrying values of the asset groups within the contract drilling, pressure pumping, directional drilling and oilfield rentals operating segments by approximately 35 For the assessment performed in 2019, the expected cash flows for the Company’s asset groups included revenue growth rates, operating expense growth rates, and terminal growth rates. Also, the expected cash flows for the contract drilling, pressure pumping, directional drilling and oilfield rentals asset groups were based on the assumption that activity levels in all four segments would generally be lower than levels experienced in 2019 and would begin to recover in late 2020 or 2021 in response to improved oil prices. While the Company believes these assumptions with respect to future oil pricing are reasonable, actual future prices and activity levels may vary significantly from the ones that were assumed. The timeframe over which oil prices and activity levels may recover is highly uncertain. All of these factors are beyond the Company’s control. If the lower oil price environment experienced in 2019 were to last into late 2021 and beyond, the Company’s actual cash flows would likely be less than the expected cash flows used in these assessments and could result in impairment charges in the future, and such impairment could be material. The Company concluded that no triggering events occurred during the quarter ended December 31, 2019 with respect to its asset groups based on the Company’s results of operations for the current year, management’s expectations of operating results in future periods and the prevailing commodity prices at the time. Prior Year Triggering Event Assessment Due to the decline in the market price of the Company’s common stock and the deterioration of crude oil prices in the fourth quarter of 2018, the Company lowered its expectations with respect to future activity levels in certain of its operating segments. The Company deemed it necessary to assess the recoverability of its contract drilling, pressure pumping, directional drilling and oilfield rentals asset groups. The Company performed an analysis as required by ASC 360-10-35 to assess the recoverability of the asset groups within its contract drilling, pressure pumping, directional drilling and oilfield rentals operating segments as of December 31, 2018. With respect to these asset groups, 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 asset groups, and no impairment was indicated. Expected cash flows, on an undiscounted basis, exceeded the carrying values of the asset groups within the contract drilling, pressure pumping, directional drilling and oilfield rentals operating segments by approximately 38%, 58%, 9% and 23%, respectively. For the assessment performed in 2018, the expected cash flows for the Company’s asset groups included revenue growth rates, operating expense growth rates, and terminal growth rates. Also, the expected cash flows for the contract drilling, pressure pumping, directional drilling and oilfield rentals asset groups were based on the assumption that activity levels in all four segments would generally be lower than levels experienced in the fourth quarter of 2018, and would begin to recover in late 2019 and continue into 2020 in response to improved oil prices and activity levels. The Company concluded that no triggering events occurred during the year ended December 31, 2017 with respect to its asset groups based on the Company’s results of operations for the year ended December 31, 2017 management’s expectations of operating results in future periods and the prevailing commodity prices at the time.

Goodwill and Intangible Assets

Goodwill and Intangible Assets	12 Months Ended
	Dec. 31, 2019
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill and Intangible Assets	6. Goodwill and Intangible Assets Goodwill — Goodwill by operating segment as of December 31, 2019 and 2018 and changes for the years then ended are as follows (in thousands): Contract Pressure Directional Other Drilling Pumping Drilling Operations Total Balance, December 31, 2017 $ 395,060 $ 121,444 $ 88,685 $ 6,284 $ 611,473 Goodwill acquired — — — 9,412 9,412 Measurement period adjustment — — 1,000 — 1,000 Impairment — (121,444 ) (89,685 ) — (211,129 ) Balance, December 31, 2018 $ 395,060 $ — $ — $ 15,696 $ 410,756 Measurement period adjustment — — — $ 2,104 2,104 Impairment — — — (17,800 ) (17,800 ) Balance, December 31, 2019 $ 395,060 $ — $ — $ — $ 395,060 There were no accumulated impairment losses related to goodwill in the contract drilling segment as of December 31, 2019 or 2018. The change to goodwill in Other Operations in 2019 was primarily a result of a measurement period adjustment related to accrued liabilities, which resulted in a $2.1 million increase from the original purchase price allocation assessed with the Current Power acquisition. 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 impairment testing purposes, goodwill is evaluated at the reporting unit level. The Company’s reporting units for impairment testing are 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 the resulting fair value of goodwill is less than the carrying value of goodwill, an impairment loss would be recognized for the amount of the shortfall. Due to the decline in the market price of the Company’s common stock and recent commodity prices, the Company’s results of operations for the quarter ended September 3 0 , 2019 and management’s expectations of operating results in future periods, the Company lowered its expectations with respect to future activity levels in certain of its operating segments. The Company performed a quantitative impairment assessment of its goodwill as of Sept ember 3 0 , 2019. In completing the assessment, the fair value of each reporting unit was estimated using the income approach . 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 assumptions included discount rates , revenue growth rates, operating expense growth rates, and terminal growth rates. Based on the results of the goodwill impairment test as of September 30, 2019, the fair value of the contract drilling reporting unit exceeded its carrying value by approximately 13% and management concluded that no impairment was indicated in its contract drilling reporting unit; however, impairment was indicated in its oilfield rentals and electrical controls and automation reporting units included in the other operations segment. The Company recognized an impairment charge of $17.8 million in 2019 associated with the impairment of all of the goodwill in its oilfield rentals and electrical controls and automation reporting units. The timeframe over which oil prices and activity levels may recover is highly uncertain. If the lower oil price environment experienced in 2019 were to last into late 2021 and beyond, the Company’s actual cash flows would likely be less than the expected cash flows used in these assessments and could result in additional goodwill impairment charges in the future and such impairment could be material. Due to the decline in the market price of the Company’s common stock and the deterioration of crude oil prices in the fourth quarter of 2018, the Company lowered its expectations with respect to future activity levels in certain of its operating segments. The Company performed a quantitative impairment assessment of its goodwill as of December 31, 2018. In completing the assessment, the fair value of each reporting unit was estimated using the income approach. 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 assumptions included discount rates, revenue growth rates, operating expense growth rates, and terminal growth rates. Based on the results of the goodwill impairment test as of December 31, 2018, the fair value of the contract drilling and oilfield rentals reporting units exceeded their carrying values by approximately 16% and 14%, respectively, and the Company concluded that no impairment was indicated in its contract drilling and oilfield rentals reporting units; however, impairment was indicated in its pressure pumping and directional drilling reporting units. The Company recognized an impairment charge of $211 million associated with the impairment of all of the goodwill in its pressure pumping and directional drilling reporting units. In connection with the Company’s annual goodwill impairment assessment as of December 31, 2019 and 2017, 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 its 2019 and 2017 operating results and forecasted operating results for the respective succeeding year. The Company also considered its overall market capitalization at December 31, 2019 and 2017. Intangible Assets — In 2018, intangible assets were recorded in the Company’s directional drilling operating segment with the acquisition of Superior QC and in other operations with the acquisition of Current Power. 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 for additional information. The Company’s intangible assets were recorded at fair value on the date of acquisition and are amortized on a straight line basis. The Company did not incur any costs to renew or extend the term of acquired intangible assets in 2019 or 2018. 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 Directional drilling 3.00 Customer relationships Other operations 7.00 Developed technology Directional drilling 5.22 Favorable drilling contracts Contract drilling 0.83 Internal use software Directional drilling 5.00 Due to the decline in the market price of the Company’s common stock and recent commodity prices, the Company’s results of operations for the quarter ended September 30, 2019 and management’s expectations of operating results in future periods, the Company lowered its expectations with respect to future activity levels in certain of its operating segments. The Company deemed it necessary to assess the recoverability of its contract drilling, pressure pumping, directional drilling and oilfield rentals asset groups as of September 30, 2019. The assessments of recoverability of the asset groups included the respective intangible assets, and no impairment was indicated. See Note 5 for additional information. Due to the decline in the market price of the Company’s common stock and the deterioration of crude oil prices in the fourth quarter of 2018, the Company lowered its expectations with respect to activity levels in certain of its operating segments. The Company deemed it necessary to assess the recoverability of its contract drilling, pressure pumping, directional drilling and oilfield rentals asset groups as of December 31, 2018. The assessments of recoverability of the asset groups included the respective intangible assets, and no impairment was indicated. See Note 5 for additional information. The Company concluded that no triggering events necessitating an impairment assessment of the intangible assets had occurred during the quarter ended December 31, 2019 or in 2017. The gross carrying amount and accumulated amortization of intangible assets as of December 31, 2019 and 2018 are as follows (in thousands): 2019 2018 Gross Carrying Accumulated Net Carrying Gross Carrying Accumulated Net Carrying Amount Amortization Amount Amount Amortization Amount Customer relationships $ 28,000 $ (19,710 ) $ 8,290 $ 28,000 $ (10,719 ) $ 17,281 Developed technology 55,772 (15,386 ) 40,386 55,772 (6,533 ) 49,239 Favorable drilling contracts — — — 22,500 (22,500 ) — Internal use software 482 (214 ) 268 482 (118 ) 364 $ 84,254 $ (35,310 ) $ 48,944 $ 106,754 $ (39,870 ) $ 66,884 Amortization expense on intangible assets of approximately $17.9 million, $18.3 million and $24.3 million was recorded for the years ended December 31, 2019, 2018 and 2017, respectively. The remaining amortization expense associated with finite-lived intangible assets is expected to be as follows (in thousands): Year ending December 31, 2020 $ 19,273 2021 12,483 2022 12,461 2023 1,034 2024 1,034 Thereafter 2,659 Total $ 48,944

Accrued Liabilities

Accrued Liabilities	12 Months Ended
	Dec. 31, 2019
Payables And Accruals [Abstract]
Accrued Liabilities	7. Accrued Liabilities Accrued expenses consisted of the following at December 31, 2019 and 2018 (in thousands): 2019 2018 Salaries, wages, payroll taxes and benefits $ 57,615 $ 66,285 Workers’ compensation liability 81,112 83,772 Property, sales, use and other taxes 22,404 25,318 Insurance, other than workers’ compensation 9,218 9,531 Accrued interest payable 12,021 15,774 Other 37,480 35,266 Accrued liabilities $ 219,850 $ 235,946

Long Term Debt

Long Term Debt	12 Months Ended
	Dec. 31, 2019
Debt Disclosure [Abstract]
Long Term Debt	8. Long-Term Debt 2019 Term Loan Agreement — On August 22, 2019, the Company entered into a term loan agreement (“Term Loan Agreement”) among the Company, as borrower, Wells Fargo Bank, National Association, as administrative agent and lender and the other lender party thereto. The Term Loan Agreement is a committed senior unsecured term loan facility that permits a single borrowing of up to $150 million, which was drawn in full by the Company on September 23, 2019. Subject to customary conditions, the Company may request that the lenders’ aggregate commitments be increased by up to $75 million, not to exceed total commitments of $225 million. The maturity date under the Term Loan Agreement is June 10, 2022. The Company repaid $50 million of the borrowings under the Term Loan Agreement on December 16, 2019. Loans under the Term Loan Agreement bear interest by reference, at the Company’s election, to the LIBOR rate or base rate. The applicable margin on LIBOR rate loans varies from 1.00% to 1.375%, and the applicable margin on base rate loans varies from 0.00% to 0.375%, in each case determined based upon the Company’s credit rating. As of December 31, 2019, the applicable margin on LIBOR rate loans and base rate loans was 1.125% and 0.125%, respectively. The Term Loan Agreement contains representations, warranties, affirmative and negative covenants and events of default and associated remedies that the Company believes are customary for agreements of this nature, including certain restrictions on the ability of the Company and each subsidiary of the Company to incur debt and grant liens. If the Company’s credit rating is below investment grade, the Company will become subject to a restricted payment covenant, which would require the Company to have a Pro Forma Debt Service Coverage Ratio (as defined in the Term Loan Agreement) greater than or equal to 1.50 to 1.00 immediately before and immediately after making any restricted payment. The Term Loan Agreement requires mandatory prepayment in an amount equal to 100% of the net cash proceeds from the issuance of new senior indebtedness (other than certain permitted indebtedness) if the Company’s credit rating is below investment grade. The Term Loan Agreement also requires that the Company’s total debt to capitalization ratio, expressed as a percentage, not exceed 50%. The Term Loan Agreement generally defines the total 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 end of the most recently ended fiscal quarter. As of December 31, 2019, the Company had $100 million in borrowings outstanding under the Term Loan Agreement at a LIBOR interest rate of 2.917%. 2018 Credit Agreement — On March 27, 2018, the Company entered into an amended and restated credit agreement (the “Credit Agreement”) among the Company, as borrower, Wells Fargo Bank, National Association, as administrative agent, letter of credit issuer, swing line lender and lender, each of the other lenders and letter of credit issuers party thereto, The Bank of Nova Scotia and U.S. Bank National Association, as Co-Syndication Agents, Royal Bank of Canada, as Documentation Agent and Wells Fargo Securities, LLC, The Bank of Nova Scotia and U.S. Bank National Association, as Co-Lead Arrangers and Joint Book Runners. The Credit Agreement is a committed senior unsecured revolving credit facility that permits aggregate borrowings of up to $600 million, including a letter of credit facility that, at any time outstanding, is limited to $150 million and a swing line facility that, at any time outstanding, is limited to $20 million. Subject to customary conditions, the Company may request that the lenders’ aggregate commitments be increased by up to $300 million, not to exceed total commitments of $900 million. The original maturity date under the Credit Agreement was March 27, 2023. On March 26, 2019, the Company entered into Amendment No. 1 to Amended and Restated Credit Agreement, which amended the Credit Agreement to, among other things, extend the maturity date under the Credit Agreement from March 27, 2023 to March 27, 2024. one-year Loans under the Credit Agreement bear interest by reference, at the Company’s election, to the LIBOR rate or base rate. The applicable margin on LIBOR rate loans varies from 1.00% to 2.00% and the applicable margin on base rate loans varies from 0.00% to 1.00%, in each case determined based upon the Company’s credit rating. A letter of credit fee is payable by the Company equal to the applicable margin for LIBOR rate loans times the daily amount available to be drawn under outstanding letters of credit. The commitment fee rate payable to the lenders varies from 0.10% to 0.30% based on the Company’s credit rating. No subsidiaries of the Company are currently required to be a guarantor under the Credit Agreement. However, if any subsidiary guarantees or incurs debt in excess of the Priority Debt Basket (as defined in the Credit Agreement), such subsidiary is required to become a guarantor under the Credit Agreement. The Credit Agreement contains representations, warranties, affirmative and negative covenants and events of default and associated remedies that the Company believes are customary for agreements of this nature, including certain restrictions on the ability of the Company and each subsidiary of the Company to incur debt and grant liens. If the Company’s credit rating is below investment grade, the Company will become subject to a restricted payment covenant, which would require the Company to have a Pro Forma Debt Service Coverage Ratio (as defined in the Credit Agreement) greater than or equal to 1.50 to 1.00 immediately before and immediately after making any restricted payment. The Credit Agreement also requires that the Company’s total debt to capitalization ratio, expressed as a percentage, not exceed 50%. 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 end of the most recently ended fiscal quarter. As of December 31, 2019, the Company had no The Company had $81,000 in letters of credit outstanding under the revolving credit facility at December 31, 2019 and, as a result, had available borrowing capacity of approximately $600 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, 2019, the Company had $63.3 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. No subsidiaries of the Company currently guarantee payment under the Credit Agreement. Series A Senior Notes and Series 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 bore interest at a rate of 4.97% per annum. On September 25, 2019, the Company fully prepaid the Series A Notes. The total amount of the prepayment, including the applicable “make-whole” premium, was approximately $308 million, which represents 100% of the principal and the “make-whole” premium to the prepayment date. On June 14, 2012, the Company completed the issuance and sale of $300 million in aggregate principal amount of its 4.27% Series B Senior Notes due June 14, 2022 (the “Series B Notes”) in a private placement. The Series B Notes bore interest at a rate of 4.27% per annum. On December 16, 2019, the Company fully prepaid the Series B Notes. The total amount of the prepayment, including the applicable “make-whole” premium, was approximately $315 million, which represents 100% of the principal and the “make-whole” premium to the prepayment date Primarily as a result of the “make-whole” premiums, the Company incurred a $8.2 million loss on early extinguishment of the Series A Notes in the three months ended September 30, 2019, and a $15.8 million loss on early extinguishment of the Series B Notes in the three months ended December 31, 2019, which were included in “Interest expense , net of amount capitalized” in the consolidated statements of operations 2028 Senior Notes and 2029 Senior Notes — On January 19, 2018, the Company completed its offering of $525 million in aggregate principal amount of the Company’s 3.95% Senior Notes due 2028 (the “2028 Notes”). 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. On November 15, 2019, the Company completed an offering of $350 million in aggregate principal amount of the Company’s 5.15% Senior Notes due 2029 (the “2029 Notes”). The net proceeds before offering expenses were approximately $347 million. The Company used a portion of the net proceeds from the offering to prepay its Series B Notes. The remaining net proceeds and available cash on hand was used to repay $50 million of the borrowings under the Term Loan Agreement. 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 Company pays interest on the 2029 Notes on May 15 and November 15 of each year. The 2029 Notes will mature on November 15, 2029. The 2029 Notes bear interest at a rate of 5.15% per annum. The 2028 Notes and 2029 Notes (together, the “Senior Notes”) are senior unsecured obligations of the Company, which rank equally with all of the Company’s other existing and future senior unsecured debt and will rank senior in right of payment to all of the Company’s other future subordinated debt. The Senior Notes will be effectively subordinated to any of the Company’s future secured debt to the extent of the value of the assets securing such debt. In addition, the Senior Notes will be structurally subordinated to the liabilities (including trade payables) of the Company’s subsidiaries that d o not guarantee the Senior Notes. No subsidiaries of the Company are currently required to be a guarantor under the Senior Notes . If subsidiaries of the Company guarantee the Senior Notes in the future, such guarantees (the “Guarantees”) will rank equally in right of payment with all of the guarantors’ future unsecured senior debt and senior in right of payment to all of the guarantors’ future subordinated debt. The Guarantees will be effectively subordinated to any of the guarantors’ future secured debt to the extent of the value of the assets securing such debt. The Company, at its option, may redeem the Senior Notes in whole or in part, at any time or from time to time at a redemption price equal to 100% of the principal amount The indentures pursuant to which the Senior Notes were issued include 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 indentures, each holder of the Senior Notes may require the Company to purchase all or a portion The indentures Debt issuance costs — The Company incurred approximately $151,000 debt issuance costs in connection with the Term Loan Agreement. The Company incurred approximately $4.6 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 . The Company incurred approximately $1.6 million in debt issuance costs in connection with the 2028 Notes and approximately $1.0 million in debt issuance costs in connection with the 2029 Notes. These costs were deferred and are being recognized as interest expense over the term of the underlying debt. Debt issuance costs, except those related to line-of-credit arrangements, are presented in the balance sheet as a direct deduction from the carrying amount of the related debt. Debt issuance costs related to line-of-credit arrangements are classified as a deferred charge. Amortization of debt issuance costs is reported as interest expense. Interest expense related to the amortization of debt issuance costs was approximately $2.0 million, $2.0 million and $2.6 million for the years ended December 31, 2019, 2018 and 2017, respectively. Amortization of debt issuance costs for the year ended December 31, 2019 includes $185,000 of debt issuance costs that were expensed as a result of the Series A Notes prepayment, $394,000 of debt issuance costs that were expensed as a result of the Series B Notes prepayment and approximately $50,000 of debt issuance costs that were expensed as a result of the Term Loan Agreement partial repayment. Amortization of debt issuance costs for the year ended December 31, 2018 includes $317,000 of debt issuance costs related to commitments by lenders under the Company’s previous credit agreement who did not participate in the Credit Agreement. Presented below is a schedule of the principal repayment requirements of long-term debt by fiscal year as of December 31, 2019 (in thousands): Year ending December 31, 2020 $ — 2021 — 2022 100,000 2023 — 2024 — Thereafter 875,000 Total $ 975,000

Commitments, Contingencies and

Commitments, Contingencies and Other Matters	12 Months Ended
	Dec. 31, 2019
Commitments And Contingencies Disclosure [Abstract]
Commitments, Contingencies and Other Matters	9. Commitments, Contingencies and Other Matters Commitments – As of December 31, 2019, the Company maintained letters of credit in the aggregate amount of $63.4 million primarily 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, 2019, no amounts had been drawn under the letters of credit. As of December 31, 2019, the Company had commitments to purchase major equipment and make investments totaling approximately $51 million for its drilling, pressure pumping, directional drilling and oilfield rentals businesses. The Company’s pressure pumping business has entered into agreements to purchase minimum quantities of proppants and chemicals from certain vendors. The agreements expire in years 2020 through 2023. As of December 31, 2019, the remaining obligation under these agreements was approximately $37.8 million, of which approximately $15.8 million relates to purchases required during 2020. In the event the required minimum quantities are not purchased during any contract year, the Company could be required to make a liquidated damages payment to the respective vendor for any shortfall. In 2017, the Company entered into a capacity reservation agreement that required a cash deposit to increase the Company’s access to finer grades of sand for its pressure pumping business. As market prices for sand substantially decreased since 2017, the Company purchased lower cost sand outside of this capacity reservation contract and recorded a charge of $12.7 million in the second quarter of 2019 to revalue the deposit to its expected realizable value. Contingencies – The Company’s operations are subject to many hazards inherent in the businesses in which it operates, including inclement weather, blowouts, explosions, fires, loss of well control, equipment failure, 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. An accident or other event resulting in significant environmental or property damage, or injuries or fatalities involving the Company’s employees or other persons could also trigger investigations by federal, state or local authorities. Such an accident or other event could cause the Company to incur substantial expenses in connection with the investigation, remediation and resolution, as well as cause lasting damage to the Company’s reputation, loss of customers and an inability to obtain insurance. The Company has indemnification agreements with many of its customers, and also maintains liability and other forms of insurance. In general, the Company’s contracts typically contain provisions requiring its customers to indemnify the Company for, among other things, reservoir and certain pollution damage. The Company’s right to indemnification may, however, be unenforceable or limited due to negligent or willful acts or omissions 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 services 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 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 maintains insurance coverage of types and amounts that the Company believes to be customary in the industry, but is not fully insured against all risks, either because insurance is not available or because of the high premium costs. The insurance coverage that the Company maintains includes insurance for fire, windstorm and other risks of physical loss to its equipment and certain other assets, employer’s liability, automobile liability, commercial general liability, workers’ compensation and insurance for other specific risks. The Company cannot assure, however, that any insurance obtained will be adequate to cover any losses or liabilities, or that this insurance will continue to be available, or available on terms that are acceptable to the Company. While the Company carries insurance to cover physical damage to, or loss of, a substantial portion of its equipment and certain other assets, such insurance does not cover the full replacement cost of such equipment or other assets. 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 $10.0 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 most cybersecurity risks, and does not carry a significant amount of insurance to cover risks of underground reservoir damage. On July 18, 2018, the U.S. Occupational Safety and Health Administration (“OSHA”) issued a citation containing alleged violations, proposed abatement dates and an aggregate proposed penalty of approximately $74,000 in connection with an accident at a drilling site in Pittsburg County, Oklahoma that resulted in the losses of life of five people, including three of the Company’s employees. The Company filed a notice of contest with OSHA that contested all citation items, abatement dates and proposed penalties. The Department of Labor (the “DOL”) filed a complaint on OSHA’s behalf seeking enforcement of the citation as issued, and the Company filed an answer to the complaint. In October 2019, the Company and the DOL agreed to a settlement of all but one of the citation items, and a hearing on the remaining citation item was held before an administrative law judge. The Company and the DOL will file post-hearing briefs and await the judge’s determination. The Company is party to various other 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, cash flows or results of operations 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 • 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 • 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, 2019
Equity [Abstract]
Stockholders' Equity	10. 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, 2019, 2018 and 2017 as follows: Per Share Total (in thousands) 2019 Paid on March 21, 2019 $ 0.04 $ 8,499 Paid on June 20, 2019 0.04 8,344 Paid on September 19, 2019 0.04 7,847 Paid on December 19, 2019 0.04 7,738 Total cash dividends $ 0.16 $ 32,428 2018 Paid on March 22, 2018 $ 0.02 $ 4,443 Paid on June 21, 2018 0.04 8,832 Paid on September 20, 2018 0.04 8,685 Paid on December 20, 2018 0.04 8,629 Total cash dividends $ 0.14 $ 30,589 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 On February 5, 2020, the Company’s Board of Directors approved a cash dividend on its common stock in the amount of $0.04 per share to be paid on March 19, 2020 to holders of record as of March 5, 2020. 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 authorized purchases of up to $200 million of the Company’s common stock in open market or privately negotiated transactions. On July 25, 2018, the Company’s Board of Directors approved an increase of the authorization under the stock buyback program to allow for $250 million of future share repurchases. On July 24, 2019, the Company’s Board of Directors approved another increase of the authorization under the stock buyback program to allow for $250 million of future share repurchases. The Company acquired shares of stock from directors in 2017 and employees during 2019, 2018, and 2017 that are ac counted for as treasury stock. Certain of these shares were acquired to satisfy the exercise price and employees’ tax withholding obligation s upon 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 and restricted stock units. These shares were acquired at fair market value. These acquisitions were made pursuant to the terms of the Plan (as defined below ) and not pursuant to the stock buyback program. Treasury stock acquisitions during the years ended December 31, 2019, 2018 and 2017 were as follows (dollars in thousands): 2019 2018 2017 Shares Cost Shares Cost Shares Cost Treasury shares at beginning of period 53,701,096 $ 1,080,448 43,802,611 $ 918,711 43,392,617 $ 911,094 Purchases pursuant to stock buyback program 22,566,331 250,109 9,331,131 150,497 5,503 109 Acquisitions pursuant to long-term incentive plan 1,037,947 14,205 567,354 11,240 404,491 7,508 Other 31,013 372 — — — — Treasury shares at end of period 77,336,387 $ 1,345,134 53,701,096 $ 1,080,448 43,802,611 $ 918,711

Stock-based Compensation

Stock-based Compensation	12 Months Ended
	Dec. 31, 2019
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Stock-based Compensation	11. 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 include equity instruments in the form of stock options, restricted stock or restricted stock units that have included service conditions and, in certain cases, performance conditions. The Company’s share-based awards also include share-settled performance unit awards. Share-settled performance unit awards are accounted for as equity awards. 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 Patterson-UTI Energy, Inc. 2014 Long-Term Incentive Plan (the “2014 Plan”) was originally approved by the Company’s stockholders effective as of April 17, 2014 and authorized 9.1 million shares for issuance. 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 by 9.8 million shares. On June 6, 2019, the Company’s stockholders approved an amendment to the Amended and Restated Plan to increase the number of shares available for issuance under the plan by 9.5 million shares and to extend the latest date on which awards may be granted under the Amended and Restated Plan to June 6, 2029 (the “Amendment” and the Amended and Restated Plan, as amended by the Amendment, the “Plan”). Shares Shares Underlying Shares Authorized Awards Available Plan Name for Grant Outstanding for Grant Amended and Restated Plan 28,400,000 6,320,440 8,331,502 Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended — 2,533,500 — A summary of the 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, 2019, 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 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. 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 such 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 years ended December 31, 2019, 2018 and 2017. Stock option activity for the year ended December 31, 2019 follows: Weighted Average Shares Exercise Price Per Share Outstanding at beginning of year 5,501,150 $ 19.63 Exercised (700,000 ) $ 13.17 Expired (35,000 ) $ 14.95 Outstanding at end of year 4,766,150 $ 20.62 Exercisable at end of year 4,736,150 $ 20.63 Options outstanding at December 31, 2019 have no intrinsic value and a weighted-average remaining contractual term of 3.62 years. Options exercisable at December 31, 2019 have no intrinsic value and a weighted-average remaining contractual term of 3.60 years. Additional information with respect to options granted, vested and exercised during the years ended December 31, 2019, 2018 and 2017 follows (in thousands, except per share data): 2019 2018 2017 Weighted-average grant date fair value of stock options granted (per share) NA NA NA Aggregate grant date fair value of stock options vested during the year $ 543 $ 1,954 $ 4,565 Aggregate intrinsic value of stock options exercised $ — $ — $ 209 As of December 31, 2019, options to purchase 30,000 shares were outstanding and not vested. All of these non-vested options are expected to ultimately vest. Additional information as of December 31, 2019 with respect to these non-vested options follows (dollars in thousands): Aggregate intrinsic value $ — Weighted-average remaining contractual term 6.71 years Weighted-average remaining expected term 1.71 years Weighted-average remaining vesting period 1.71 years Unrecognized compensation cost $ 151 Restricted Stock— For all restricted stock awards made 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, 2019 follows: Weighted Average Grant Date Fair Shares Value Per Share Non-vested restricted stock outstanding at beginning of year 436,224 $ 21.41 Vested (362,673 ) $ 21.38 Forfeited (1,500 ) $ 21.71 Non-vested restricted stock outstanding at end of year 72,051 $ 21.59 As of December 31, 2019, approximately 72,000 shares of non-vested restricted stock outstanding are expected to vest. Additional information as of December 31, 2019 with respect to these non-vested shares follows (dollars in thousands): Aggregate intrinsic value $ 757 Weighted-average remaining vesting period .3 year Unrecognized compensation cost $ 1,247 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. Forfeitable dividend equivalents are accrued on certain 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, 2019 follows: Weighted Average Time Performance Grant Date Fair Based Based Value Per Share Non-vested restricted stock units outstanding at beginning of year 2,602,608 435,315 $ 18.95 Granted 1,505,048 — $ 12.40 Vested (1) (1,135,231 ) (38,000 ) $ 19.19 Forfeited (340,699 ) — $ 17.08 Non-vested restricted stock units outstanding at end of year 2,631,726 397,315 $ 15.81 (1) As of December 31, 2019, approximately 2.9 million non-vested restricted stock units outstanding are expected to vest. Additional information as of December 31, 2019 with respect to these non-vested restricted stock units follows (dollars in thousands): Aggregate intrinsic value $ 30,938 Weighted-average remaining vesting period 1.9 years Unrecognized compensation cost $ 36,933 Performance Unit Awards. The Company has granted share-settled performance unit awards to certain employees (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 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. For the Performance Units granted in May 2017 and April 2018, 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. For the Performance Units granted in April 2019, the recipients will receive the target number of shares if the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 55th 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. If the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 25th percentile, then the recipients will only receive one-half of the target number of shares. If the Company’s total shareholder return during the performance period, when compared to the peer group, is between the 25th and target percentile, or the target and 75th percentile, then the shares to be received by the recipients will be determined using linear interpolation for levels of achievement between these points. For the Performance Units awarded prior to 2016, there was no payout unless the Company’s total shareholder return was positive and, when compared to the peer group was at or above the 25 th th The total target number of shares with respect to the Performance Units for the years 2014-2019 is set forth below: 2019 2018 2017 2016 2015 2014 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Target number of shares 489,800 310,700 186,198 185,000 190,600 154,000 The 2014 Performance Units settled with In April 2018, 381,200 shares were issued to settle the 2015 Performance Units. In April 2019, 185,000 shares were issued to settle the 2016 Performance Units. The Performance Units granted in 2017, 2018, and 2019 have not reached the end of their respective performance periods. Because the Performance Units are share-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): 2019 2018 2017 2016 2015 2014 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 $ 9,958 $ 8,004 $ 5,780 $ 3,854 $ 4,052 $ 5,388 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): 2019 2018 2017 2016 2015 2014 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Year ended December 31, 2019 $ 2,489 $ 2,668 $ 1,927 $ 321 NA NA Year ended December 31, 2018 NA $ 2,001 $ 1,927 $ 1,285 $ 338 NA Year ended December 31, 2017 NA NA $ 1,284 $ 1,285 $ 1,351 $ 449 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, 2019
Leases [Abstract]
Leases	12. Leases ASC Topic 842 Leases On January 1, 2019, the Company adopted the new lease guidance under Topic 842, Leases The Company has entered into operating leases for operating locations, corporate offices and certain operating equipment. These leases have remaining lease terms of one month to nine years as of December 31, 2019. Currently, the Company does not have any finance leases. Renewal options are included in the right of use asset and lease liability if it is reasonably certain that the Company will exercise the option. The Company has elected the short-term lease recognition practical expedient whereby right of use assets and lease liabilities are not recognized for leasing arrangements with an initial term of one year or less. Topic 842 requires that lessees and lessors discount lease payments at the lease commencement date using the rate implicit in the lease, if available, or the lessee’s incremental borrowing rate. The Company uses the implicit rate when readily determinable. If the implicit rate is not readily determinable, the Company uses its incremental borrowing rate based on the information available at the commencement date in the determination of the present value of future lease payments. In the fourth quarter of 2019 the Company entered into a sale-leaseback transaction that qualified as a sale. The Company sold a facility for proceeds of $10.2 million and concurrently entered into an operating lease agreement with the unrelated third-party for certain floors of the building for a 58-month term. The associated gain on sale of approximately $800,000 is included in “Other operating expenses (income), net” in the consolidated statements of operations. For the year ended December 31, 2019 the Company has entered into 3 new facility leases and recorded an increase to the operating lease right-of-use assets and corresponding operating lease liabilities of approximately $3.8 million. The Company also extended 9 facilities leases and recorded an increase to the operating lease right-of-use assets and corresponding operating lease liabilities of approximately $7.1 million. Practical Expedients Adopted with Topic 842 The Company has elected to adopt the following practical expedients upon the transition date to Topic 842 on January 1, 2019: • Transitional practical expedients package: An entity may elect to apply the listed practical expedients as a package to all the leases that commenced before the effective date. The practical expedients are: a) The entity need not reassess whether any expired or existing contracts are or contain leases; b) The entity need not reassess the lease classification for expired or existing contracts; c) The entity need not reassess initial direct costs for any existing leases. • Use of portfolio approach: An entity can apply this guidance to a portfolio of leases with similar characteristics if the entity reasonably expects that the application of the leases model to the portfolio would not differ materially from the application of the leases model to the individual leases in that portfolio. This approach can also be applied to other aspects of the leases guidance for which lessees/lessors need to make judgments and estimates, such as determining the discount rate and determining and reassessing the lease term. • Lease and non-lease components: As a practical expedient, lease and non-lease components may be combined where the revenue recognition pattern is the same and where the lease component, when accounted for separately, would be considered an operating lease. The Company’s contract drilling, pressure pumping and directional drilling contracts contain a lease component related to the underlying equipment utilized, in addition to the service component provided by the Company’s crews and expertise to operate the related equipment. The Company has concluded that the non-lease service of operating its equipment and providing expertise in the services provided to customers is predominant in the Company’s drilling, pressure pumping and directional drilling contracts. With the election of this practical expedient, the Company will continue to present a single performance obligation for these contracts under the revenue guidance in ASC 606. Lease expense consisted of the following for the year ended December 31, 2019 (in thousands): Year Ended December 31, 2019 Operating lease cost $ 10,944 Short-term lease expense (1) 440 Total lease expense $ 11,384 (1) Short-term lease expense represents expense related to leases with a contract term of one year or less. Supplemental cash flow information related to leases for the year ended December 31, 2019 is as follows (in thousands): Year Ended December 31, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 10,033 Right of use assets obtained in exchange for lease obligations: Operating leases $ 10,870 Supplemental balance sheet information related to leases as of December 31, 2019 is as follows: December 31, 2019 Weighted Average Remaining Lease Term: Operating leases 5.3 years Weighted Average Discount Rate: Operating leases 4.2 % Maturities of operating lease liabilities as of December 31, 2019 are as follows (in thousands): Year ending December 31, 2020 $ 11,212 2021 8,484 2022 6,220 2023 3,955 2024 3,055 Thereafter 7,883 Total lease payments 40,809 Less imputed interest (4,230 ) Total $ 36,579

Income Taxes

Income Taxes	12 Months Ended
	Dec. 31, 2019
Income Tax Disclosure [Abstract]
Income Taxes	13. Income Taxes Components of the income tax provision applicable to federal, state and foreign income taxes for the years ended December 31, 2019, 2018 and 2017 are as follows (in thousands): 2019 2018 2017 Federal income tax benefit: Current $ (1,976 ) $ (3,954 ) $ (42 ) Deferred (90,441 ) (35,081 ) (335,106 ) (92,417 ) (39,035 ) (335,148 ) State income tax expense (benefit): Current 851 1,704 (215 ) Deferred (11,593 ) (11,147 ) 4,511 (10,742 ) (9,443 ) 4,296 Foreign income tax expense (benefit): Current (348 ) (2,552 ) (3,108 ) Deferred (1,168 ) 5,043 249 (1,516 ) 2,491 (2,859 ) Total income tax benefit: Current (1,473 ) (4,802 ) (3,365 ) Deferred (103,202 ) (41,185 ) (330,346 ) Total income tax benefit: $ (104,675 ) $ (45,987 ) $ (333,711 ) Loss before income taxes for the U.S. for years ended December 31, 2019, 2018, and 2017 are $499.9 million, $343.1 million, and $312.9 million, respectively. Loss before income taxes for non-U.S. jurisdictions for years ended December 31, 2019, 2018, and 2017 are $30.5 million, $24.3 million, and $14.9 million, respectively. The difference between the statutory federal income tax rate and the effective income tax rate for the years ended December 31, 2019, 2018 and 2017 is summarized as follows: 2019 2018 2017 Statutory tax rate 21.0 % 21.0 % 35.0 % State income taxes - net of the federal income tax benefit 1.7 1.2 1.9 Goodwill impairment (0.7 ) (6.9 ) — Permanent differences (0.5 ) (0.6 ) (1.3 ) Tax effects of tax reform — (1.3 ) 66.7 Share-based payments (0.7 ) (0.1 ) 3.6 Acquisition related differences — — (3.3 ) Valuation allowance (0.8 ) (3.7 ) — State deferred tax remeasurement (1.1 ) 2.3 — Other differences, net 0.8 0.6 (0.8 ) Effective tax rate 19.7 % 12.5 % 101.8 % The effective tax rate increased by approximately 7.2% to 19.7% for 2019 compared to 12.5% for 2018. This difference was primarily due to higher goodwill impairment charges in 2018 relative to 2019, which are not deductible for tax purposes. These charges resulted in a 6.9% decrease to the effective tax rate in 2018, as compared to a 0.7% decrease to the effective tax rate in 2019. Another factor was valuation allowances being established against deferred tax assets in certain state and non-U.S. jurisdictions, which were higher in 2018 as compared to 2019. These resulted in a 3.7 % decrease to the effective tax rate in 2018, as compared to a % decrease to the rate in 2019. The Company continues to monitor income tax developments in the United States and other countries affecting the Company. In December 2017, the United States enacted U.S. Tax Reform, which materially impacted the consolidated financial statements by decreasing the U.S. corporate statutory tax rate and significantly affecting future periods. The Company expects several proposed U.S. Treasury regulations under U.S. Tax Reform that were issued during 2018 and 2019 to be finalized during 2020. The Company will incorporate into its future financial statements the impacts, if any, of these regulations and additional authoritative guidance when finalized. The Company continues to elect permanent reinvestment of unremitted earnings in Canada effective January 1, 2010, and it intends to do so for the foreseeable future. If the Company were to repatriate earnings, in the form of dividends or otherwise, it might be subject to certain income taxes (subject to an adjustment for foreign tax credits) and withholding taxes payable. The tax effect of significant temporary differences representing deferred tax assets and liabilities at December 31, 2019 and 2018 are as follows (in thousands): 2019 2018 Deferred tax assets: Net operating loss carryforwards $ 375,308 $ 324,389 Tax credits 4,138 6,404 Expense associated with stock options and restricted stock 10,561 13,375 Workers' compensation allowance 19,536 19,900 Other deferred tax asset 21,698 22,423 431,241 386,491 Less: Valuation allowance (17,231 ) (13,232 ) Total deferred tax assets 414,010 373,259 Deferred tax liabilities: Property and equipment basis difference (607,785 ) (669,196 ) Other (9,184 ) (10,224 ) Total deferred tax liabilities (616,969 ) (679,420 ) Net deferred tax liability $ (202,959 ) $ (306,161 ) 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. The Company considers carryback availability, the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment. In 2019, the Company recorded an additional $4 million of valuation allowances against its net deferred tax assets, primarily relating to certain Canadian subsidiaries. These valuation allowances were recorded due to a change in judgment as to the realizability of these assets in future tax years. For income tax purposes, the Company has approximately $1.4 billion of gross federal net operating losses, approximately $47.4 million of gross Canadian net operating losses and approximately $847 million of post-apportionment state net operating losses as of December 31, 2019, before valuation allowances. The majority of federal net operating losses will expire in varying amounts, if unused, between 2034 and 2037. Federal net operating losses generated in 2018 and 2019 can be carried forward indefinitely. Canadian net operating losses will expire in varying amounts, if unused, between 2036 and 2039. State net operating losses will expire in varying amounts, if unused, between 2023 and 2039. As of December 31, 2019, 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, 2019, the tax years ended December 31, 2014 through December 31, 2018 are open for examination by U.S. taxing authorities. As of December 31, 2019, the tax years ended December 31, 2012 through December 31, 2018 are open for examination by Canadian taxing authorities.

Earnings Per Share

Earnings Per Share	12 Months Ended
	Dec. 31, 2019
Earnings Per Share [Abstract]
Earnings Per Share	14. Earnings Per 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, performance units and restricted stock units. The dilutive effect of stock options, performance units 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, 2019, 2018 and 2017, 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): 2019 2018 2017 BASIC EPS: Net income (loss) $ (425,703 ) $ (321,421 ) $ 5,910 Adjust for (income) loss attributed to holders of non-vested restricted stock — — (170 ) Income (loss) attributed to common stockholders $ (425,703 ) $ (321,421 ) $ 5,740 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 203,039 218,643 198,447 Basic net income (loss) per common share $ (2.10 ) $ (1.47 ) $ 0.03 DILUTED EPS: Income (loss) attributed to common stockholders $ (425,703 ) $ (321,421 ) $ 5,740 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 203,039 218,643 198,447 Add dilutive effect of potential common shares — — 1,435 Weighted average number of diluted common shares outstanding 203,039 218,643 199,882 Diluted net income (loss) per common share $ (2.10 ) $ (1.47 ) $ 0.03 Potentially dilutive securities excluded as anti-dilutive 9,195 9,762 3,289

Employee Benefits

Employee Benefits	12 Months Ended
	Dec. 31, 2019
Compensation And Retirement Disclosure [Abstract]
Employee Benefits	15. Employee Benefits The Company maintains a 401(k) plan for all eligible employees. The Company’s operating results include expenses of approximately $13.2 million in 2019, $14.3 million in 2018 and $8.7 million in 2017 for the Company’s contributions to the plan.

Business Segments

Business Segments	12 Months Ended
	Dec. 31, 2019
Segment Reporting [Abstract]
Business Segments	16. Business Segments At December 31, 2019, the Company had three reportable 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 and has a separate management team that reports 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, 2019, the Company had 216 marketed land-based drilling rigs in the continental United States and western Canada. For the years ended December 31, 2019, 2018 and, 2017, contract drilling revenue earned in Canada was $4.7 million, $9.3 million and $13.7 million, respectively. Additionally, long-lived assets within the contract drilling segment located in Canada totaled $20.1 million and $26.2 million as of December 31, 2019 and 2018, 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. Substantially all of the revenue in the pressure pumping segment is from well stimulation services (such as hydraulic fracturing) 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. The Company also provides wireline and cementing services through its pressure pumping segment. 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. Substantially all of the revenue in the directional drilling segment is from directional drilling, downhole performance motors and measurement-while-drilling services, which are sold as a bundle. Major Customer — During 2019, 2018 and 2017, no single customer accounted for more than 10% of the Company’s consolidated operating revenues. The following tables summarize selected financial information relating to the Company’s business segments (in thousands): Year Ended December 31, 2019 2018 2017 Revenues: Contract drilling $ 1,309,988 $ 1,432,012 $ 1,041,492 Pressure pumping 868,694 1,573,396 1,200,311 Directional drilling 188,786 209,275 45,580 Other operations (1) 122,885 131,028 76,781 Elimination of intercompany revenues (2) (19,668 ) (18,714 ) (7,480 ) Total revenues $ 2,470,685 $ 3,326,997 $ 2,356,684 Income (loss) before income taxes: Contract drilling $ (151,329 ) $ (33,115 ) $ (171,897 ) Pressure pumping (102,701 ) (77,328 ) 21,028 Directional drilling (52,724 ) (117,497 ) (21 ) Other operations (54,725 ) (18,221 ) (20,813 ) Corporate (96,719 ) (93,585 ) (152,792 ) Other operating income, net (3) 2,305 17,569 31,957 Provision for bad debts (5,683 ) — — Interest income 6,013 5,597 1,866 Interest expense (75,204 ) (51,578 ) (37,472 ) Other 389 750 343 Loss before income taxes $ (530,378 ) $ (367,408 ) $ (327,801 ) Depreciation, depletion, amortization and impairment: Contract drilling $ 668,007 $ 571,607 $ 538,891 Pressure pumping 233,952 250,010 198,006 Directional drilling 52,223 45,317 9,347 Other operations 42,803 41,512 29,402 Corporate 6,888 7,872 7,695 Total depreciation, depletion, amortization and impairment $ 1,003,873 $ 916,318 $ 783,341 Capital expenditures: Contract drilling $ 194,416 $ 394,595 $ 354,425 Pressure pumping 105,803 173,848 171,436 Directional drilling 15,549 35,929 7,795 Other operations 27,132 34,660 31,547 Corporate 4,612 2,426 1,884 Total capital expenditures $ 347,512 $ 641,458 $ 567,087 Identifiable assets: Contract drilling $ 3,190,463 $ 3,817,638 $ 3,931,994 Pressure pumping 695,570 921,237 1,209,424 Directional drilling 164,273 239,341 301,275 Other operations 128,290 177,374 172,094 Corporate (4) 261,019 314,276 144,069 Total assets $ 4,439,615 $ 5,469,866 $ 5,758,856 ( 1 ) Other operations includes the Company’s oilfield rentals business, drilling equipment service business, the electrical controls and automation business, the oil and natural gas working interests and Middle East organizational activities. ( 2 ) Intercompany revenues consists of contract drilling and revenues from other operations for services provided to contract drilling, pressure pumping and within other operations ( 3 ) Other operating income, net includes net gains associated with the disposal of assets related to corporate strategy decisions of the executive management group. Accordingly, the related gains have been excluded from the operating results of specific segments. This caption also includes certain legal-related expenses and settlements, net of insurance reimbursements and certain research and development expenses ( 4 ) Corporate assets primarily include cash on hand and certain property and equipment.

Concentrations of Credit Risk

Concentrations of Credit Risk	12 Months Ended
	Dec. 31, 2019
Risks And Uncertainties [Abstract]
Concentrations of Credit Risk	17. 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, 2019 and 2018, the Company’s demand deposits and temporary cash investments consisted of the following (in thousands): 2019 2018 Deposits in FDIC and SIPC-insured institutions under insurance limits $ 1,250 $ 750 Deposits in FDIC and SIPC-insured institutions over insurance limits 179,375 229,132 Deposits in foreign banks 2,309 22,698 182,934 252,580 Less outstanding checks and other reconciling items (8,749 ) (7,551 ) Cash and cash equivalents $ 174,185 $ 245,029 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. A $5.7 million provision for bad debts was recognized in 2019 with respect to accounts receivable balances that were estimated to be uncollectible

Fair Values of Financial Instru

Fair Values of Financial Instruments	12 Months Ended
	Dec. 31, 2019
Fair Value Disclosures [Abstract]
Fair Values of Financial Instruments	18. 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, 2019 and 2018 is set forth below (in thousands): December 31, 2019 December 31, 2018 Carrying Fair Carrying Fair Value Value Value Value 3.95% Senior Notes $ 525,000 $ 511,485 $ 525,000 $ 482,488 5.15% Senior Notes 350,000 358,864 — — 4.97% Series A Senior Notes — — 300,000 300,043 4.27% Series B Senior Notes — — 300,000 293,900 2019 Term Loan 100,000 100,000 — — Total debt $ 975,000 $ 970,349 $ 1,125,000 $ 1,076,431 The fair value of the 3.95% Senior Notes at December 31, 2019 and December 31, 2018 are based on discounted cash flows associated with the notes using the market rate of interest at December 31, 2019 and the 5.07% market rate of interest at December 31, 2018. is based on discounted cash flows associated with the notes using the market rate of interest at December 31, 2019. The fair value estimates of the 3.95% Senior Notes and the 5.15% Senior Notes are considered Level 1 fair value estimates in the fair value hierarchy of fair value accounting. The fair values of the Series A Notes and Series B Notes at December 31, 2018 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 rate used in measuring this fair value was 4.97

Quarterly Financial Information

Quarterly Financial Information	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Quarterly Financial Information	19. Quarterly Financial Information (in thousands, except per share amounts) (unaudited) 1 st 2 nd 3 rd 4 th Quarter Quarter Quarter Quarter 2019 Operating revenues $ 704,171 $ 675,765 $ 598,452 $ 492,297 Operating loss (23,383 ) (48,125 ) (307,305 ) (82,763 ) Net loss (28,614 ) (49,447 ) (261,719 ) (85,923 ) Net loss per common share: Basic $ (0.14 ) $ (0.24 ) $ (1.31 ) $ (0.44 ) Diluted $ (0.14 ) $ (0.24 ) $ (1.31 ) $ (0.44 ) 2018 Operating revenues $ 809,164 $ 854,418 $ 867,478 $ 795,937 Operating loss (22,102 ) (9,004 ) (80,281 ) (210,790 ) Net loss (34,417 ) (10,713 ) (75,042 ) (201,249 ) Net loss per common share: Basic $ (0.16 ) $ (0.05 ) $ (0.34 ) $ (0.93 ) Diluted $ (0.16 ) $ (0.05 ) $ (0.34 ) $ (0.93 )

Valuation And Qualifying Accoun

Valuation And Qualifying Accounts	12 Months Ended
	Dec. 31, 2019
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, 2019 Deducted from asset accounts: Allowance for doubtful accounts $ 2,312 $ 5,683 $ (1,479 ) $ 6,516 Year Ended December 31, 2018 Deducted from asset accounts: Allowance for doubtful accounts $ 2,323 $ — $ (11 ) $ 2,312 Year Ended December 31, 2017 Deducted from asset accounts: Allowance for doubtful accounts $ 3,191 $ — $ (868 ) $ 2,323 (1)

Description of Business and S_2

Description of Business and Summary of Significant Accounting Policies (Policies)	12 Months Ended
	Dec. 31, 2019
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 the Company’s contract drilling, pressure pumping, directional drilling, oilfield rentals, equipment servicing and electrical control and automation activities are recognized as services are performed. All of the wells the Company drilled in 2019, 2018 and 2017 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. On January 1, 2018, the Company adopted the new revenue guidance under Topic 606, Revenue from Contracts with Customers
Leases	Leases — T he Company enters operating leases for operating locations, corporate offices and certain operating equipment. As of December 31, 2019, the Company does not have any finance leases. On January 1, 2019, the Company adopted the new lease guidance under Topic 842, Leases
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 uncollectible, 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 equipment servicing 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 $39.0 million and $35.6 million at December 31, 2019 and 2018, 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. Impairment expense related to oil and natural gas properties of approximately $2.2 million, $1.0 million and $4.3 million was recorded for the years ended December 31, 2019, 2018 and 2017, respectively.
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.
Income Taxes	Income taxes — The asset and liability method is used in accounting for income taxes. Under this method, deferred tax assets and liabilities are recognized for operating loss and tax credit carryforwards and for the future tax consequences attributable to differences between the financial statement carrying amounts of existing assets and liabilities and their respective tax bases. Deferred tax assets and liabilities are measured using enacted tax rates expected to apply to taxable income in the year in which those temporary differences are expected to be recovered or settled. The effect on deferred tax assets and liabilities of a change in tax rates is recognized in the results of operations in the period that includes the enactment date. If applicable, a valuation allowance is recorded to reduce the carrying amounts of deferred tax assets unless it is more likely than not that such assets will be realized. The Company’s policy is to account for interest and penalties with respect to income taxes as operating expenses.
Stock-based Compensation	Stock-based compensation — The Company recognizes the cost of share-based payments under the fair-value-based method. Under this method, compensation cost related to share-based payments is measured based on the estimated fair value of the awards at the date of grant, net of estimated forfeitures. This expense is recognized over the expected life of the awards (See Note 11). 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 Adopted Accounting Standards — In May 2014, the Financial Accounting Standards Board (“FASB”) issued an accounting standards update to provide guidance on the recognition of revenue from customers. Under this guidance, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects what it expects in exchange for the goods or services. This guidance also requires more detailed disclosures to enable users of the financial statements to understand the nature, amount, timing and uncertainty, if any, of revenue and cash flows arising from contracts with customers. The Company adopted this new revenue guidance effective January 1, 2018, utilizing the modified retrospective method, and expanded its consolidated financial statement disclosures in order to comply with the update (See Note 3). 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 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 Company adopted this new leasing guidance effective January 1, 2019 and expanded its consolidated financial statement disclosures in order to comply with the update (See Note 12). The adoption of this standard resulted in the recording of operating lease right of use assets of approximately $31.0 million and operating lease liabilities of approximately $35.8 million as of January 1, 2019. 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. The Company adopted this guidance effective January 1, 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 issued in the case of stock option exercises. In August 2016, the FASB issued an accounting standards update 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 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. 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. In March 2018, the FASB issued an accounting standards update to update the income tax accounting in U.S. GAAP to reflect the SEC interpretive guidance released on December 22, 2017, when significant U.S. tax law changes were enacted with the enactment of “H.R.1,” also known as the “Tax Cuts and Jobs Act” (“U.S. Tax Reform”). The adoption of this update in March 2018 did not have a material impact on the Company’s consolidated financial statements, as the Company was already following the SEC guidance (See Note 13). Recently Issued Accounting Standards — In June 2016, the FASB issued an accounting standards update on measurement of credit losses on financial instruments. This update improves financial reporting by requiring earlier recognition of credit losses on financing receivables and other financial assets in scope by using the Current Expected Credit Losses model (CECL). The CECL model utilizes a lifetime expected credit loss measurement objective for the recognition of credit losses on financial instruments at the time the asset is originated or acquired. This update will apply to receivables arising from revenue transactions such as contract assets and accounts receivables. This update is effective for interim and annual periods beginning after December 15, 2019, with early adoption permitted. The Company will adopt this new guidance on January 1, 2020 and does not expect this new guidance will have a material impact on its consolidated financial statements. In August 2018, the FASB issued an accounting standards update to align the requirements for capitalizing implementation costs incurred in a hosting arrangement that is a service contract with the requirements for capitalizing implementation costs incurred to develop or obtain internal-use software. The capitalized implementation costs of a hosting arrangement that is a service contract will be expensed over the term of the hosting arrangement. The Company will adopt this new guidance on January 1, 2020 In August 2018, the FASB issued an accounting standards update to eliminate certain disclosure requirements for fair value measurements for all entities, require public entities to disclose certain new information and modify certain disclosure requirements. The FASB developed the amendments to Topic 820 as part of its broader disclosure framework project, which aims to improve the effectiveness of disclosures in the notes to financial statements by focusing on requirements that clearly communicate the most important information to users of the financial statements. This update is effective for interim and annual periods beginning after December 15, 2019, with early adoption permitted. The Company will adopt this new guidance on January 1, 2020 and does not expect this new guidance will have a material impact on its In December 2019, the FASB issued an accounting standards update to simplify the accounting for income taxes. The amendments in the update are effective for public business entities for fiscal years beginning after December 15, 2020, with early adoption permitted. The Company plans to adopt this guidance on January 1, 2021 and is currently evaluating the impact of adoption on its consolidated financial statements. During the third quarter of 2019, the Company identified and recorded out-of-period adjustments primarily related to the accounting for inventory in its directional drilling segment. The Company concluded that these adjustments were not material to the consolidated financial statements for any of the current or prior periods presented. The net adjustment is reflected as a $6.6 million increase to “Loss before income taxes” in the consolidated statements of operations for the year ended December 31, 2019.

Description of Business and S_3

Description of Business and Summary of Significant Accounting Policies (Tables)	12 Months Ended
	Dec. 31, 2019
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

Acquisitions (Tables)

Acquisitions (Tables)	12 Months Ended
	Dec. 31, 2019
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 following table represents the final 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 Assigned to Identifiable Intangible Assets	A portion of the fair value consideration transferred has been 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
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 following table represents the final 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 44,099 Other long-term liabilities 327 Total liabilities assumed 44,426 Net identifiable assets acquired 167,590 Goodwill 89,685 Total net assets acquired $ 257,275
Portion of Fair Value Consideration Transferred Assigned to Identifiable Intangible Assets	A portion of the fair value consideration transferred has been 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, 2019
Inventory Disclosure [Abstract]
Inventory	Inventory consisted of the following at December 31, 2019 and 2018 (in thousands): 2019 2018 Finished goods $ 105 $ 347 Work-in-process 1,229 6,375 Raw materials and supplies 35,023 58,857 Inventory $ 36,357 $ 65,579

Property and Equipment (Tables)

Property and Equipment (Tables)	12 Months Ended
	Dec. 31, 2019
Property Plant And Equipment [Abstract]
Property and Equipment	Property and equipment consisted of the following at December 31, 2019 and 2018 (in thousands): 2019 2018 Equipment $ 8,114,326 $ 8,370,933 Oil and natural gas properties 226,646 219,855 Buildings 184,700 186,736 Land 25,747 26,144 Total property and equipment 8,551,419 8,803,668 Less accumulated depreciation, depletion and impairment (5,244,742 ) (4,801,119 ) Property and equipment, net $ 3,306,677 $ 4,002,549
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, intangible assets and liabilities for 2019, 2018 and 2017 (in thousands): 2019 2018 2017 Depreciation and impairment expense $ 974,206 $ 887,155 $ 753,510 Amortization expense 17,722 18,197 21,764 Depletion expense 11,945 10,966 8,067 Total $ 1,003,873 $ 916,318 $ 783,341

Goodwill and Intangible Assets

Goodwill and Intangible Assets (Tables)	12 Months Ended
	Dec. 31, 2019
Goodwill And Intangible Assets Disclosure [Abstract]
Goodwill by Operating Segment	Goodwill — Goodwill by operating segment as of December 31, 2019 and 2018 and changes for the years then ended are as follows (in thousands): Contract Pressure Directional Other Drilling Pumping Drilling Operations Total Balance, December 31, 2017 $ 395,060 $ 121,444 $ 88,685 $ 6,284 $ 611,473 Goodwill acquired — — — 9,412 9,412 Measurement period adjustment — — 1,000 — 1,000 Impairment — (121,444 ) (89,685 ) — (211,129 ) Balance, December 31, 2018 $ 395,060 $ — $ — $ 15,696 $ 410,756 Measurement period adjustment — — — $ 2,104 2,104 Impairment — — — (17,800 ) (17,800 ) Balance, December 31, 2019 $ 395,060 $ — $ — $ — $ 395,060
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 Directional drilling 3.00 Customer relationships Other operations 7.00 Developed technology Directional drilling 5.22 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, 2019 and 2018 are as follows (in thousands): 2019 2018 Gross Carrying Accumulated Net Carrying Gross Carrying Accumulated Net Carrying Amount Amortization Amount Amount Amortization Amount Customer relationships $ 28,000 $ (19,710 ) $ 8,290 $ 28,000 $ (10,719 ) $ 17,281 Developed technology 55,772 (15,386 ) 40,386 55,772 (6,533 ) 49,239 Favorable drilling contracts — — — 22,500 (22,500 ) — Internal use software 482 (214 ) 268 482 (118 ) 364 $ 84,254 $ (35,310 ) $ 48,944 $ 106,754 $ (39,870 ) $ 66,884
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, 2020 $ 19,273 2021 12,483 2022 12,461 2023 1,034 2024 1,034 Thereafter 2,659 Total $ 48,944

Accrued Liabilities (Tables)

Accrued Liabilities (Tables)	12 Months Ended
	Dec. 31, 2019
Payables And Accruals [Abstract]
Summary of Accrued Expenses	Accrued expenses consisted of the following at December 31, 2019 and 2018 (in thousands): 2019 2018 Salaries, wages, payroll taxes and benefits $ 57,615 $ 66,285 Workers’ compensation liability 81,112 83,772 Property, sales, use and other taxes 22,404 25,318 Insurance, other than workers’ compensation 9,218 9,531 Accrued interest payable 12,021 15,774 Other 37,480 35,266 Accrued liabilities $ 219,850 $ 235,946

Long Term Debt (Tables)

Long Term Debt (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 (in thousands): Year ending December 31, 2020 $ — 2021 — 2022 100,000 2023 — 2024 — Thereafter 875,000 Total $ 975,000

Stockholders' Equity (Tables)

Stockholders' Equity (Tables)	12 Months Ended
	Dec. 31, 2019
Equity [Abstract]
Cash Dividends	Cash Dividends – The Company paid cash dividends during the years ended December 31, 2019, 2018 and 2017 as follows: Per Share Total (in thousands) 2019 Paid on March 21, 2019 $ 0.04 $ 8,499 Paid on June 20, 2019 0.04 8,344 Paid on September 19, 2019 0.04 7,847 Paid on December 19, 2019 0.04 7,738 Total cash dividends $ 0.16 $ 32,428 2018 Paid on March 22, 2018 $ 0.02 $ 4,443 Paid on June 21, 2018 0.04 8,832 Paid on September 20, 2018 0.04 8,685 Paid on December 20, 2018 0.04 8,629 Total cash dividends $ 0.14 $ 30,589 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
Treasury Stock Acquisition	Treasury stock acquisitions during the years ended December 31, 2019, 2018 and 2017 were as follows (dollars in thousands): 2019 2018 2017 Shares Cost Shares Cost Shares Cost Treasury shares at beginning of period 53,701,096 $ 1,080,448 43,802,611 $ 918,711 43,392,617 $ 911,094 Purchases pursuant to stock buyback program 22,566,331 250,109 9,331,131 150,497 5,503 109 Acquisitions pursuant to long-term incentive plan 1,037,947 14,205 567,354 11,240 404,491 7,508 Other 31,013 372 — — — — Treasury shares at end of period 77,336,387 $ 1,345,134 53,701,096 $ 1,080,448 43,802,611 $ 918,711

Stock-based Compensation (Table

Stock-based Compensation (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 are as follows: Shares Shares Underlying Shares Authorized Awards Available Plan Name for Grant Outstanding for Grant Amended and Restated Plan 28,400,000 6,320,440 8,331,502 Patterson-UTI Energy, Inc. 2005 Long-Term Incentive Plan, as amended — 2,533,500 —
Stock Option Activity	Stock option activity for the year ended December 31, 2019 follows: Weighted Average Shares Exercise Price Per Share Outstanding at beginning of year 5,501,150 $ 19.63 Exercised (700,000 ) $ 13.17 Expired (35,000 ) $ 14.95 Outstanding at end of year 4,766,150 $ 20.62 Exercisable at end of year 4,736,150 $ 20.63
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, 2019, 2018 and 2017 follows (in thousands, except per share data): 2019 2018 2017 Weighted-average grant date fair value of stock options granted (per share) NA NA NA Aggregate grant date fair value of stock options vested during the year $ 543 $ 1,954 $ 4,565 Aggregate intrinsic value of stock options exercised $ — $ — $ 209
Restricted Stock Activity	Restricted stock activity for the year ended December 31, 2019 follows: Weighted Average Grant Date Fair Shares Value Per Share Non-vested restricted stock outstanding at beginning of year 436,224 $ 21.41 Vested (362,673 ) $ 21.38 Forfeited (1,500 ) $ 21.71 Non-vested restricted stock outstanding at end of year 72,051 $ 21.59
Restricted Stock Unit Activity	Restricted stock unit activity for the year ended December 31, 2019 follows: Weighted Average Time Performance Grant Date Fair Based Based Value Per Share Non-vested restricted stock units outstanding at beginning of year 2,602,608 435,315 $ 18.95 Granted 1,505,048 — $ 12.40 Vested (1) (1,135,231 ) (38,000 ) $ 19.19 Forfeited (340,699 ) — $ 17.08 Non-vested restricted stock units outstanding at end of year 2,631,726 397,315 $ 15.81 (1)
Performance Units	The total target number of shares with respect to the Performance Units for the years 2014-2019 is set forth below: 2019 2018 2017 2016 2015 2014 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Target number of shares 489,800 310,700 186,198 185,000 190,600 154,000
Fair Value of Performance Units	The fair value of the Performance Units is set forth below (in thousands): 2019 2018 2017 2016 2015 2014 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 $ 9,958 $ 8,004 $ 5,780 $ 3,854 $ 4,052 $ 5,388
Compensation Expense Associated with Performance Units	Compensation expense associated with the Performance Units is set forth below (in thousands): 2019 2018 2017 2016 2015 2014 Performance Performance Performance Performance Performance Performance Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Unit Awards Year ended December 31, 2019 $ 2,489 $ 2,668 $ 1,927 $ 321 NA NA Year ended December 31, 2018 NA $ 2,001 $ 1,927 $ 1,285 $ 338 NA Year ended December 31, 2017 NA NA $ 1,284 $ 1,285 $ 1,351 $ 449
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, 2019 with respect to these non-vested options follows (dollars in thousands): Aggregate intrinsic value $ — Weighted-average remaining contractual term 6.71 years Weighted-average remaining expected term 1.71 years Weighted-average remaining vesting period 1.71 years Unrecognized compensation cost $ 151
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, 2019 with respect to these non-vested shares follows (dollars in thousands): Aggregate intrinsic value $ 757 Weighted-average remaining vesting period .3 year Unrecognized compensation cost $ 1,247
Restricted Stock Units (RSUs)
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, 2019 with respect to these non-vested restricted stock units follows (dollars in thousands): Aggregate intrinsic value $ 30,938 Weighted-average remaining vesting period 1.9 years Unrecognized compensation cost $ 36,933

Leases (Tables)

Leases (Tables)	12 Months Ended
	Dec. 31, 2019
Leases [Abstract]
Summary of Lease Expense	Lease expense consisted of the following for the year ended December 31, 2019 (in thousands): Year Ended December 31, 2019 Operating lease cost $ 10,944 Short-term lease expense (1) 440 Total lease expense $ 11,384 (1) Short-term lease expense represents expense related to leases with a contract term of one year or less.
Summary of Supplemental Cash Flow Information Related to Leases	Supplemental cash flow information related to leases for the year ended December 31, 2019 is as follows (in thousands): Year Ended December 31, 2019 Cash paid for amounts included in the measurement of lease liabilities: Operating cash flows from operating leases $ 10,033 Right of use assets obtained in exchange for lease obligations: Operating leases $ 10,870
Summary of Supplemental Balance Sheet Information Related to Leases	Supplemental balance sheet information related to leases as of December 31, 2019 is as follows: December 31, 2019 Weighted Average Remaining Lease Term: Operating leases 5.3 years Weighted Average Discount Rate: Operating leases 4.2 %
Summary of Maturities of Operating Lease Liabilities	Maturities of operating lease liabilities as of December 31, 2019 are as follows (in thousands): Year ending December 31, 2020 $ 11,212 2021 8,484 2022 6,220 2023 3,955 2024 3,055 Thereafter 7,883 Total lease payments 40,809 Less imputed interest (4,230 ) Total $ 36,579

Income Taxes (Tables)

Income Taxes (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019, 2018 and 2017 are as follows (in thousands): 2019 2018 2017 Federal income tax benefit: Current $ (1,976 ) $ (3,954 ) $ (42 ) Deferred (90,441 ) (35,081 ) (335,106 ) (92,417 ) (39,035 ) (335,148 ) State income tax expense (benefit): Current 851 1,704 (215 ) Deferred (11,593 ) (11,147 ) 4,511 (10,742 ) (9,443 ) 4,296 Foreign income tax expense (benefit): Current (348 ) (2,552 ) (3,108 ) Deferred (1,168 ) 5,043 249 (1,516 ) 2,491 (2,859 ) Total income tax benefit: Current (1,473 ) (4,802 ) (3,365 ) Deferred (103,202 ) (41,185 ) (330,346 ) Total income tax benefit: $ (104,675 ) $ (45,987 ) $ (333,711 )
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, 2019, 2018 and 2017 is summarized as follows: 2019 2018 2017 Statutory tax rate 21.0 % 21.0 % 35.0 % State income taxes - net of the federal income tax benefit 1.7 1.2 1.9 Goodwill impairment (0.7 ) (6.9 ) — Permanent differences (0.5 ) (0.6 ) (1.3 ) Tax effects of tax reform — (1.3 ) 66.7 Share-based payments (0.7 ) (0.1 ) 3.6 Acquisition related differences — — (3.3 ) Valuation allowance (0.8 ) (3.7 ) — State deferred tax remeasurement (1.1 ) 2.3 — Other differences, net 0.8 0.6 (0.8 ) Effective tax rate 19.7 % 12.5 % 101.8 %
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, 2019 and 2018 are as follows (in thousands): 2019 2018 Deferred tax assets: Net operating loss carryforwards $ 375,308 $ 324,389 Tax credits 4,138 6,404 Expense associated with stock options and restricted stock 10,561 13,375 Workers' compensation allowance 19,536 19,900 Other deferred tax asset 21,698 22,423 431,241 386,491 Less: Valuation allowance (17,231 ) (13,232 ) Total deferred tax assets 414,010 373,259 Deferred tax liabilities: Property and equipment basis difference (607,785 ) (669,196 ) Other (9,184 ) (10,224 ) Total deferred tax liabilities (616,969 ) (679,420 ) Net deferred tax liability $ (202,959 ) $ (306,161 )

Earnings Per Share (Tables)

Earnings Per Share (Tables)	12 Months Ended
	Dec. 31, 2019
Earnings Per Share [Abstract]
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, 2019, 2018 and 2017, 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): 2019 2018 2017 BASIC EPS: Net income (loss) $ (425,703 ) $ (321,421 ) $ 5,910 Adjust for (income) loss attributed to holders of non-vested restricted stock — — (170 ) Income (loss) attributed to common stockholders $ (425,703 ) $ (321,421 ) $ 5,740 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 203,039 218,643 198,447 Basic net income (loss) per common share $ (2.10 ) $ (1.47 ) $ 0.03 DILUTED EPS: Income (loss) attributed to common stockholders $ (425,703 ) $ (321,421 ) $ 5,740 Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock 203,039 218,643 198,447 Add dilutive effect of potential common shares — — 1,435 Weighted average number of diluted common shares outstanding 203,039 218,643 199,882 Diluted net income (loss) per common share $ (2.10 ) $ (1.47 ) $ 0.03 Potentially dilutive securities excluded as anti-dilutive 9,195 9,762 3,289

Business Segments (Tables)

Business Segments (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 2018 2017 Revenues: Contract drilling $ 1,309,988 $ 1,432,012 $ 1,041,492 Pressure pumping 868,694 1,573,396 1,200,311 Directional drilling 188,786 209,275 45,580 Other operations (1) 122,885 131,028 76,781 Elimination of intercompany revenues (2) (19,668 ) (18,714 ) (7,480 ) Total revenues $ 2,470,685 $ 3,326,997 $ 2,356,684 Income (loss) before income taxes: Contract drilling $ (151,329 ) $ (33,115 ) $ (171,897 ) Pressure pumping (102,701 ) (77,328 ) 21,028 Directional drilling (52,724 ) (117,497 ) (21 ) Other operations (54,725 ) (18,221 ) (20,813 ) Corporate (96,719 ) (93,585 ) (152,792 ) Other operating income, net (3) 2,305 17,569 31,957 Provision for bad debts (5,683 ) — — Interest income 6,013 5,597 1,866 Interest expense (75,204 ) (51,578 ) (37,472 ) Other 389 750 343 Loss before income taxes $ (530,378 ) $ (367,408 ) $ (327,801 ) Depreciation, depletion, amortization and impairment: Contract drilling $ 668,007 $ 571,607 $ 538,891 Pressure pumping 233,952 250,010 198,006 Directional drilling 52,223 45,317 9,347 Other operations 42,803 41,512 29,402 Corporate 6,888 7,872 7,695 Total depreciation, depletion, amortization and impairment $ 1,003,873 $ 916,318 $ 783,341 Capital expenditures: Contract drilling $ 194,416 $ 394,595 $ 354,425 Pressure pumping 105,803 173,848 171,436 Directional drilling 15,549 35,929 7,795 Other operations 27,132 34,660 31,547 Corporate 4,612 2,426 1,884 Total capital expenditures $ 347,512 $ 641,458 $ 567,087 Identifiable assets: Contract drilling $ 3,190,463 $ 3,817,638 $ 3,931,994 Pressure pumping 695,570 921,237 1,209,424 Directional drilling 164,273 239,341 301,275 Other operations 128,290 177,374 172,094 Corporate (4) 261,019 314,276 144,069 Total assets $ 4,439,615 $ 5,469,866 $ 5,758,856 ( 1 ) Other operations includes the Company’s oilfield rentals business, drilling equipment service business, the electrical controls and automation business, the oil and natural gas working interests and Middle East organizational activities. ( 2 ) Intercompany revenues consists of contract drilling and revenues from other operations for services provided to contract drilling, pressure pumping and within other operations ( 3 ) Other operating income, net includes net gains associated with the disposal of assets related to corporate strategy decisions of the executive management group. Accordingly, the related gains have been excluded from the operating results of specific segments. This caption also includes certain legal-related expenses and settlements, net of insurance reimbursements and certain research and development expenses ( 4 ) Corporate assets primarily include cash on hand and certain property and equipment.

Concentrations of Credit Risk (

Concentrations of Credit Risk (Tables)	12 Months Ended
	Dec. 31, 2019
Risks And Uncertainties [Abstract]
Company's Demand Deposits and Temporary Cash Investments	At December 31, 2019 and 2018, the Company’s demand deposits and temporary cash investments consisted of the following (in thousands): 2019 2018 Deposits in FDIC and SIPC-insured institutions under insurance limits $ 1,250 $ 750 Deposits in FDIC and SIPC-insured institutions over insurance limits 179,375 229,132 Deposits in foreign banks 2,309 22,698 182,934 252,580 Less outstanding checks and other reconciling items (8,749 ) (7,551 ) Cash and cash equivalents $ 174,185 $ 245,029

Fair Values of Financial Inst_2

Fair Values of Financial Instruments (Tables)	12 Months Ended
	Dec. 31, 2019
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, 2019 and 2018 is set forth below (in thousands): December 31, 2019 December 31, 2018 Carrying Fair Carrying Fair Value Value Value Value 3.95% Senior Notes $ 525,000 $ 511,485 $ 525,000 $ 482,488 5.15% Senior Notes 350,000 358,864 — — 4.97% Series A Senior Notes — — 300,000 300,043 4.27% Series B Senior Notes — — 300,000 293,900 2019 Term Loan 100,000 100,000 — — Total debt $ 975,000 $ 970,349 $ 1,125,000 $ 1,076,431

Quarterly Financial Informati_2

Quarterly Financial Information (Tables)	12 Months Ended
	Dec. 31, 2019
Quarterly Financial Information Disclosure [Abstract]
Summary of Unaudited Quarterly Financial Information	1 st 2 nd 3 rd 4 th Quarter Quarter Quarter Quarter 2019 Operating revenues $ 704,171 $ 675,765 $ 598,452 $ 492,297 Operating loss (23,383 ) (48,125 ) (307,305 ) (82,763 ) Net loss (28,614 ) (49,447 ) (261,719 ) (85,923 ) Net loss per common share: Basic $ (0.14 ) $ (0.24 ) $ (1.31 ) $ (0.44 ) Diluted $ (0.14 ) $ (0.24 ) $ (1.31 ) $ (0.44 ) 2018 Operating revenues $ 809,164 $ 854,418 $ 867,478 $ 795,937 Operating loss (22,102 ) (9,004 ) (80,281 ) (210,790 ) Net loss (34,417 ) (10,713 ) (75,042 ) (201,249 ) Net loss per common share: Basic $ (0.16 ) $ (0.05 ) $ (0.34 ) $ (0.93 ) Diluted $ (0.16 ) $ (0.05 ) $ (0.34 ) $ (0.93 )

Description of Business and S_4

Description of Business and Summary of Significant Accounting Policies - Additional Information (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jan. 01, 2019
Basis Of Consolidation And Presentation [Line Items]
Reimbursement of workers compensation insurance claims included in other current assets	$ 39,000	$ 35,600
Impairment expense related to oil and natural gas properties	2,200	1,000	$ 4,300
Right of use asset	31,275
Operating lease liabilities	36,579
Adjustment of loss before income tax	(530,378)	$ (367,408)	$ (327,801)
Contract Drilling
Basis Of Consolidation And Presentation [Line Items]
Adjustment of loss before income tax	$ (6,600)
Accounting Standards Update 2016-02
Basis Of Consolidation And Presentation [Line Items]
Right of use asset				$ 31,000
Operating lease liabilities				$ 35,800

Estimated Useful Lives of Prope

Estimated Useful Lives of Property and Equipment (Detail)	12 Months Ended
	Dec. 31, 2019
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

Acquisitions - Additional Infor

Acquisitions - Additional Information (Detail) shares in Thousands, $ in Thousands	Oct. 11, 2017USD ($)shares	Apr. 20, 2017USD ($)Rigshpshares	Jan. 27, 2017USD ($)	Dec. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Business Acquisition [Line Items]
Goodwill				$ 395,060	$ 410,756	$ 611,473
Increase in goodwill due to measurement period adjustments				2,104	1,000
Merger and integration related costs					2,738	74,451
Contract Drilling
Business Acquisition [Line Items]
Goodwill				$ 395,060	$ 395,060	395,060
Pressure Pumping
Business Acquisition [Line Items]
Goodwill						121,444
Seventy Seven Energy Inc.
Business Acquisition [Line Items]
Shares of common stock exchange in business acquisition | shares		46,298
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 fracturing equipment | hp		500,000
Goodwill		$ 436,554
Merger and integration related costs						$ 36,700
Seventy Seven Energy Inc. | Contract Drilling
Business Acquisition [Line Items]
Goodwill		309,000
Seventy Seven Energy Inc. | Pressure Pumping
Business Acquisition [Line Items]
Goodwill		121,000
Seventy Seven Energy Inc. | Oilfield Rentals
Business Acquisition [Line Items]
Goodwill		$ 6,300
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
Repayment of outstanding debt	$ 63,000
Merger date				Oct. 11, 2017
Total fair value of the consideration transferred	257,275
Goodwill	89,685
Aggregate consideration paid by the company	69,800
Business acquisition, description of acquired entity				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, measurement-while-drilling, and wireline steering tools.
Increase in goodwill due to measurement period adjustments	$ 1,000

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, 2019	Dec. 31, 2018	Dec. 31, 2017	Oct. 11, 2017	Apr. 20, 2017
Liabilities assumed
Goodwill	$ 395,060	$ 410,756	$ 611,473
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				44,099
Other long-term liabilities				327
Total liabilities assumed				44,426
Net identifiable assets acquired				167,590
Goodwill				89,685
Total net assets acquired				$ 257,275

Portion of Fair Value Considera

Portion of Fair Value Consideration Transferred Provisionally Assigned to Identifiable Intangible Assets (Detail) - Seventy Seven Energy Inc. $ in Thousands	Apr. 20, 2017USD ($)
Business Acquisition [Line Items]
Fair Value, Assets, Portion of the fair value consideration transferred	$ 22,500
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

Portion of Fair Value Conside_2

Portion of Fair Value Consideration Transferred Assigned to Identifiable Intangible Assets (Detail) - MS Directional $ in Thousands	Oct. 11, 2017USD ($)
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
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
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
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)

Revenues - Additional Informati

Revenues - Additional Information (Detail) - USD ($) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Disaggregation Of Revenue [Line Items]
Accounts receivable balances	$ 339,699				$ 558,817				$ 339,699	$ 558,817
Amount amortized and recorded in drilling revenue	492,297	$ 598,452	$ 675,765	$ 704,171	795,937	$ 867,478	$ 854,418	$ 809,164	2,470,685	3,326,997	$ 2,356,684
Contract Drilling
Disaggregation Of Revenue [Line Items]
Amount amortized and recorded in drilling revenue									1,308,350	1,430,492	$ 1,040,033
ASC Topic 606 Revenue from Contracts with Customers
Disaggregation Of Revenue [Line Items]
Accounts receivable balances	336,000				554,000				336,000	554,000
ASC Topic 606 Revenue from Contracts with Customers | Accounts Payable
Disaggregation Of Revenue [Line Items]
Total contract liability	$ 2,700				$ 7,600				2,700	7,600
ASC Topic 606 Revenue from Contracts with Customers | Contract Drilling
Disaggregation Of Revenue [Line Items]
Amount amortized and recorded in drilling revenue									$ 1,000	$ 1,600
Maximum
Disaggregation Of Revenue [Line Items]
Accounts receivable payment terms									60 days
Minimum
Disaggregation Of Revenue [Line Items]
Accounts receivable payment terms									30 days

Revenues - Additional Informa_2

Revenues - Additional Information1 (Detail)	Dec. 31, 2019
Maximum | Revenue, Remaining Performance Obligation, Expected Timing of Satisfaction, Start Date: 2020-01-01
Disaggregation Of Revenue [Line Items]
Performance obligation original expected duration	1 year

Inventory (Detail)

Inventory (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Inventory Net [Abstract]
Finished goods	$ 105	$ 347
Work-in-process	1,229	6,375
Raw materials and supplies	35,023	58,857
Inventory	$ 36,357	$ 65,579

Property and Equipment (Detail)

Property and Equipment (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Property Plant And Equipment [Line Items]
Total property and equipment	$ 8,551,419	$ 8,803,668
Less accumulated depreciation, depletion and impairment	(5,244,742)	(4,801,119)
Property and equipment, net	3,306,677	4,002,549
Equipment
Property Plant And Equipment [Line Items]
Total property and equipment	8,114,326	8,370,933
Oil and natural gas properties
Property Plant And Equipment [Line Items]
Total property and equipment	226,646	219,855
Buildings
Property Plant And Equipment [Line Items]
Total property and equipment	184,700	186,736
Land
Property Plant And Equipment [Line Items]
Total property and equipment	$ 25,747	$ 26,144

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, 2019	Dec. 31, 2018	Dec. 31, 2017
Property Plant And Equipment [Abstract]
Depreciation and impairment expense	$ 974,206	$ 887,155	$ 753,510
Amortization expense	17,722	18,197	21,764
Depletion expense	11,945	10,966	8,067
Total	$ 1,003,873	$ 916,318	$ 783,341

Property and Equipment - Additi

Property and Equipment - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2019USD ($)Rigs	Dec. 31, 2018USD ($)Rigs	Dec. 31, 2017USD ($)	Dec. 31, 2016USD ($)	Sep. 30, 2019
Pressure Pumping
Property Plant And Equipment [Line Items]
Impairment charge for the write-down of drilling equipment	$ 20,500,000	$ 17,400,000	$ 0	$ 0
Percentage of excepted cash flows on undiscounted basis exceeding the carrying values of asset groups		58.00%			54.00%
Directional Drilling
Property Plant And Equipment [Line Items]
Impairment charge for the write-down of drilling equipment	$ 8,400,000	$ 0	0
Percentage of excepted cash flows on undiscounted basis exceeding the carrying values of asset groups		9.00%			23.00%
Contract Drilling
Property Plant And Equipment [Line Items]
Percentage of excepted cash flows on undiscounted basis exceeding the carrying values of asset groups		38.00%			35.00%
Oilfield Rentals
Property Plant And Equipment [Line Items]
Percentage of excepted cash flows on undiscounted basis exceeding the carrying values of asset groups		23.00%			7.00%
Rigs and Spare Rig Components That Would No Longer Be Marketed
Property Plant And Equipment [Line Items]
Number of rigs | Rigs	36	42
Impairment charge for the write-down of drilling equipment	$ 173,000,000	$ 48,400,000	$ 29,000,000

Goodwill by Operating Segment (

Goodwill by Operating Segment (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018
Goodwill [Line Items]
Balance at beginning of period	$ 410,756,000	$ 611,473,000
Goodwill acquired		9,412,000
Measurement period adjustment	2,104,000	1,000,000
Impairment	(17,800,000)	(211,129,000)
Balance at end of period	395,060,000	410,756,000
Contract Drilling
Goodwill [Line Items]
Balance at beginning of period	395,060,000	395,060,000
Impairment	0	0
Balance at end of period	395,060,000	395,060,000
Pressure Pumping
Goodwill [Line Items]
Balance at beginning of period		121,444,000
Impairment		(121,444,000)
Directional Drilling
Goodwill [Line Items]
Balance at beginning of period		88,685,000
Measurement period adjustment		1,000,000
Impairment		(89,685,000)
Other Operations
Goodwill [Line Items]
Balance at beginning of period	15,696,000	6,284,000
Goodwill acquired		9,412,000
Measurement period adjustment	2,104,000
Impairment	$ (17,800,000)
Balance at end of period		$ 15,696,000

Goodwill and Intangible Asset_2

Goodwill and Intangible Assets - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Goodwill And Intangible Assets Disclosure [Line Items]
Increase in goodwill	$ 2,100,000
Goodwill impairment charge	17,800,000	$ 211,129,000
Cost incurred to renew or extend term of intangible asset	0	0
Impairment	0	0
Amortization expense on intangible assets	17,900,000	18,300,000	$ 24,300,000
Contract Drilling
Goodwill And Intangible Assets Disclosure [Line Items]
Accumulated impairment losses	$ 0	$ 0
Percentage fair value exceeds carrying values	13.00%	16.00%
Goodwill impairment charge	$ 0	$ 0
Other Operations
Goodwill And Intangible Assets Disclosure [Line Items]
Accumulated impairment losses	0	$ 0
Goodwill impairment charge	17,800,000
Oilfield Rentals and Electrical Controls and Automation Reporting Unit
Goodwill And Intangible Assets Disclosure [Line Items]
Goodwill impairment charge	$ 17,800,000
Oilfield Rental
Goodwill And Intangible Assets Disclosure [Line Items]
Percentage fair value exceeds carrying values		14.00%
Goodwill impairment charge		$ 0
Pressure Pumping and Directional Drilling
Goodwill And Intangible Assets Disclosure [Line Items]
Goodwill impairment charge		$ 211,000,000

Summary of Segment and Weighted

Summary of Segment and Weighted Average Useful Life of Intangible Assets (Detail)	12 Months Ended
	Dec. 31, 2019
Customer Relationships | Directional Drilling
Acquired Finite Lived Intangible Assets [Line Items]
Weighted Average Useful Life, Identifiable intangible assets	3 years
Customer Relationships | Other Operations
Acquired Finite Lived Intangible Assets [Line Items]
Weighted Average Useful Life, Identifiable intangible assets	7 years
Developed Technology | Directional Drilling
Acquired Finite Lived Intangible Assets [Line Items]
Weighted Average Useful Life, Identifiable intangible assets	5 years 2 months 19 days
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, 2019	Dec. 31, 2018
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 84,254	$ 106,754
Accumulated Amortization	(35,310)	(39,870)
Net Carrying Amount	48,944	66,884
Customer Relationships
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	28,000	28,000
Accumulated Amortization	(19,710)	(10,719)
Net Carrying Amount	8,290	17,281
Developed Technology
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	55,772	55,772
Accumulated Amortization	(15,386)	(6,533)
Net Carrying Amount	40,386	49,239
Favorable Drilling Contracts
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount		22,500
Accumulated Amortization		(22,500)
Internal Use Software
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	482	482
Accumulated Amortization	(214)	(118)
Net Carrying Amount	$ 268	$ 364

Remaining Amortization Expense

Remaining Amortization Expense Associated with Finite-Lived Intangible Assets (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Goodwill And Intangible Assets Disclosure [Abstract]
2020	$ 19,273
2021	12,483
2022	12,461
2023	1,034
2024	1,034
Thereafter	2,659
Net Carrying Amount	$ 48,944	$ 66,884

Summary of Accrued Expenses (De

Summary of Accrued Expenses (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Payables And Accruals [Abstract]
Salaries, wages, payroll taxes and benefits	$ 57,615	$ 66,285
Workers’ compensation liability	81,112	83,772
Property, sales, use and other taxes	22,404	25,318
Insurance, other than workers’ compensation	9,218	9,531
Accrued interest payable	12,021	15,774
Other	37,480	35,266
Accrued liabilities	$ 219,850	$ 235,946

Long Term Debt - Term Loan Agre

Long Term Debt - Term Loan Agreement - Additional Information (Detail) - Term Loan Agreement - USD ($)	Dec. 16, 2019	Aug. 22, 2019	Dec. 31, 2019
Debt Instrument [Line Items]
Credit agreement date			Aug. 22, 2019
Credit facility, maximum borrowing capacity		$ 150,000,000
Debt maturity date		Jun. 10, 2022
Percentage of net cash proceeds from issuance of new senior indebtedness			100.00%
Term Loan, amount outstanding			$ 100,000,000
London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.125%
LIBOR interest rate			2.917%
Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			0.125%
Subject To Customary Conditions
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity		$ 225,000,000
Credit facility, additional borrowing capacity		$ 75,000,000
Repayments of borrowings	$ 50,000,000
Minimum
Debt Instrument [Line Items]
Debt service coverage ratio			150.00%
Minimum | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.00%
Minimum | Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			0.00%
Maximum
Debt Instrument [Line Items]
Debt to capitalization ratio, percentage the Company must not exceed at any time			50.00%
Maximum | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.375%
Maximum | Base Rate
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			0.375%

Long Term Debt - Credit Facilit

Long Term Debt - Credit Facilities - Additional Information (Detail)	Mar. 27, 2018USD ($)Option	Dec. 31, 2019USD ($)	Dec. 31, 2019USD ($)
Debt Instrument [Line Items]
Letters of credit outstanding		$ 63,400,000	$ 63,400,000
Letter of Credit
Debt Instrument [Line Items]
Line of credit, borrowings outstanding		0	0
Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit, borrowings outstanding		0	0
Line of credit, available borrowing capacity		$ 600,000,000	$ 600,000,000
Credit Agreement
Debt Instrument [Line Items]
Credit agreement date			Mar. 27, 2018
Credit agreement, financial covenant description			the Company’s total debt to capitalization ratio, expressed as a percentage, not exceed 50%. 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 end of the most recently ended fiscal quarter.
Credit Agreement | Minimum
Debt Instrument [Line Items]
Commitment fee rate payable to lenders based on credit rating			0.10%
Debt service coverage ratio		150.00%
Credit Agreement | Maximum
Debt Instrument [Line Items]
Commitment fee rate payable to lenders based on credit rating			0.30%
Debt to capitalization ratio, percentage the Company must not exceed at any time			50.00%
Credit Agreement | London Interbank Offered Rate (LIBOR) | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.00%
Credit Agreement | London Interbank Offered Rate (LIBOR) | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.00%
Credit Agreement | Base Rate | Minimum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			0.00%
Credit Agreement | Base Rate | Maximum
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			1.00%
Credit Agreement | Revolving Credit Facility
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity	$ 600,000,000
Debt maturity date	Mar. 27, 2023
Debt instrument, number of optional extensions to initial maturity date | Option	2
Optional extension period of initial maturity date	1 year
Letters of credit outstanding		$ 81,000	$ 81,000
Credit Agreement | Revolving Credit Facility | Subject To Customary Conditions
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity	$ 900,000,000
Credit facility, additional borrowing capacity	300,000,000
Credit Agreement | Revolving Credit Facility | Letter of Credit
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity	150,000,000
Credit Agreement | Revolving Credit Facility | Swing Line Facility
Debt Instrument [Line Items]
Credit facility, maximum borrowing capacity	$ 20,000,000
Reimbursement Agreement
Debt Instrument [Line Items]
Letters of credit outstanding		$ 63,300,000	$ 63,300,000
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) - USD ($)

Dec. 16, 2019

Nov. 15, 2019

Sep. 25, 2019

Mar. 27, 2018

Jan. 19, 2018

Jun. 14, 2012

Oct. 05, 2010

Dec. 31, 2019

Sep. 30, 2019

Dec. 31, 2019

Dec. 31, 2018

Dec. 31, 2017

Sep. 27, 2012

Debt Instrument [Line Items]

Loss on early extinguishment

$ (24,023,000)

Repayment of borrowings

$ 347,000,000

$ 331,000,000

Proceeds from borrowings, before offering expenses

79,000,000

599,000,000

Interest expense related to amortization of debt issuance costs

2,000,000

$ 2,000,000

$ 2,600,000

Revolving Credit Facility

Debt Instrument [Line Items]

Repayment of borrowings

$ 239,000,000

4.97% Series A Senior Notes, Due October 5th 2020

Debt Instrument [Line Items]

Long-term debt, aggregate principal amount

$ 300,000,000

Debt interest rate

4.97%

Notes issuance date

Oct. 5, 2010

Debt Instrument principle including make-whole premium

$ 308,000,000

Debt instrument, redemption percentage

100.00%

Loss on early extinguishment

$ 8,200,000

Debt issuance costs

$ 1,900,000

Interest expense related to amortization of debt issuance costs

185,000

4.27% Series B Senior Notes, Due June 14th 2022

Debt Instrument [Line Items]

Long-term debt, aggregate principal amount

$ 300,000,000

Debt interest rate

4.27%

Debt Instrument principle including make-whole premium

$ 315,000,000

Debt instrument, redemption percentage

100.00%

Debt maturity date

Jun. 14, 2012

Loss on early extinguishment

$ 15,800,000

Debt issuance costs

$ 1,600,000

Interest expense related to amortization of debt issuance costs

$ 394,000

3.95% Senior Notes Due 2028

Debt Instrument [Line Items]

Long-term debt, aggregate principal amount

$ 525,000,000

Debt interest rate

3.95%

3.95%

3.95%

3.95%

Debt instrument, redemption percentage

100.00%

Debt maturity date

Feb. 1, 2028

Proceeds from borrowings, before offering expenses

$ 521,000,000

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 Senior Notes in whole or in part, at any time or from time to time at a redemption price equal to 100% of the principal amount of such Senior Notes to be redeemed, plus accrued and unpaid interest, if any, on those Senior Notes to the redemption date, plus a “make-whole” premium. Additionally, commencing on November 1, 2027, in the case of the 2028 Notes, and on August 15, 2029, in the case of the 2029 Notes, the Company, at its option, may redeem the respective Senior Notes in whole or in part, at a redemption price equal to 100% of the principal amount of the Senior Notes to be redeemed, plus accrued and unpaid interest, if any, on those Senior 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 indentures, each holder of the Senior Notes may require the Company to purchase all or a portion of such holder’s Senior Notes at a price equal to 101% of their principal amount, plus accrued and unpaid interest, if any, to, but excluding, the repurchase date.

Redemption price percentage of principal amount of debt instrument on change of control

101.00%

Debt issuance costs

$ 1,600,000

5.15% Senior Notes Due 2029

Debt Instrument [Line Items]

Long-term debt, aggregate principal amount

$ 350,000,000

Debt interest rate

5.15%

5.15%

5.15%

Debt maturity date

Nov. 15, 2029

Proceeds from borrowings, before offering expenses

$ 347,000,000

Debt payment term

The Company pays interest on the 2029 Notes on May 15 and November 15 of each year.

Debt issuance costs

1,000,000

Term Loan Agreement

Debt Instrument [Line Items]

Repayment of borrowings

$ 50,000,000

Interest expense related to amortization of debt issuance costs

$ 50,000

Credit Agreement

Debt Instrument [Line Items]

Debt issuance costs

$ 4,600,000

Credit Agreement | Revolving Credit Facility

Debt Instrument [Line Items]

Debt maturity date

Mar. 27, 2023

Previous Credit Agreement

Debt Instrument [Line Items]

Interest expense related to amortization of debt issuance costs

$ 317,000

Schedule of Principal Repayment

Schedule of Principal Repayment Requirements of Long-Term Debt (Detail) $ in Thousands	Dec. 31, 2019USD ($)
Debt Disclosure [Abstract]
2022	$ 100,000
Thereafter	875,000
Total	$ 975,000

Commitments Contingencies and O

Commitments Contingencies and Other Matters - Additional Information (Detail) - USD ($)	Jul. 18, 2018	Jun. 30, 2019	Dec. 31, 2019
Commitments and Contingencies Disclosure [Line Items]
Letters of credit, collateral for retrospective premiums and retained losses			$ 63,400,000
Commitments to purchase major equipment and investments			$ 51,000,000
Agreement expire description			The agreements expire in years 2020 through 2023.
Current obligation			$ 37,800,000
Purchase obligations for 2020			15,800,000
Deposit revaluation charge		$ 12,700,000
General liability insurance policy, deductible per occurrence			10,000,000
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
Aggregate proposed penalty in connection with accident in site	$ 74,000
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			250.00%
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			200.00%
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			300.00%
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			250.00%
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. 05, 2020	Apr. 20, 2017	Jan. 27, 2017	Dec. 31, 2017	Dec. 31, 2019	Jul. 24, 2019	Feb. 06, 2019	Jul. 25, 2018	Sep. 06, 2013
Class Of Stock [Line Items]
Net proceeds from common stock offering				$ 471,570,000
Amount approved for repurchases under stock buyback program					$ 150,000,000		$ 250,000,000
2013 program
Class Of Stock [Line Items]
Increase of the authorization under the stock buyback program						$ 250,000,000	$ 250,000,000	$ 250,000,000
2013 program | Maximum
Class Of Stock [Line Items]
Amount approved for repurchases under stock buyback program									$ 200,000,000
Subsequent Event | Dividend Declared
Class Of Stock [Line Items]
Dividend declaration date	Feb. 5, 2020
Dividend per share, declared	$ 0.04
Dividend payment date	Mar. 19, 2020
Dividend record date	Mar. 5, 2020
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, 2019	Dec. 31, 2018	Dec. 31, 2017
Dividends Payable [Line Items]
Cash dividends paid, per share	$ 0.16	$ 0.14	$ 0.08
Cash dividends paid	$ 32,428	$ 30,589	$ 16,315
Installment 1, FY 2019
Dividends Payable [Line Items]
Cash dividends paid, date	Mar. 21, 2019
Cash dividends paid, per share	$ 0.04
Cash dividends paid	$ 8,499
Installment 2, FY 2019
Dividends Payable [Line Items]
Cash dividends paid, date	Jun. 20, 2019
Cash dividends paid, per share	$ 0.04
Cash dividends paid	$ 8,344
Installment 3, FY 2019
Dividends Payable [Line Items]
Cash dividends paid, date	Sep. 19, 2019
Cash dividends paid, per share	$ 0.04
Cash dividends paid	$ 7,847
Installment 4, FY 2019
Dividends Payable [Line Items]
Cash dividends paid, date	Dec. 19, 2019
Cash dividends paid, per share	$ 0.04
Cash dividends paid	$ 7,738
Installment 1, FY 2018
Dividends Payable [Line Items]
Cash dividends paid, date		Mar. 22, 2018
Cash dividends paid, per share		$ 0.02
Cash dividends paid		$ 4,443
Installment 2, FY 2018
Dividends Payable [Line Items]
Cash dividends paid, date		Jun. 21, 2018
Cash dividends paid, per share		$ 0.04
Cash dividends paid		$ 8,832
Installment 3, FY 2018
Dividends Payable [Line Items]
Cash dividends paid, date		Sep. 20, 2018
Cash dividends paid, per share		$ 0.04
Cash dividends paid		$ 8,685
Installment 4, FY 2018
Dividends Payable [Line Items]
Cash dividends paid, date		Dec. 20, 2018
Cash dividends paid, per share		$ 0.04
Cash dividends paid		$ 8,629
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

Treasury Stock Acquisition (Det

Treasury Stock Acquisition (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Schedule of Treasury Stock [Line Items]
Treasury shares at beginning of period	53,701,096	43,802,611	43,392,617
Other	31,013
Treasury shares at end of period	77,336,387	53,701,096	43,802,611
Treasury shares at beginning of period	$ 1,080,448	$ 918,711	$ 911,094
Treasury stock acquired, cost	264,686	161,737	7,617
Other	372
Treasury shares at end of period	$ 1,345,134	$ 1,080,448	$ 918,711
Stock Buyback Program
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, shares	22,566,331	9,331,131	5,503
Treasury stock acquired, cost	$ 250,109	$ 150,497	$ 109
Long Term Incentive Plan
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, shares	1,037,947	567,354	404,491
Treasury stock acquired, cost	$ 14,205	$ 11,240	$ 7,508

Stock-based Compensation - Addi

Stock-based Compensation - Additional Information (Detail) - USD ($)	Jun. 06, 2019	Apr. 30, 2019	Apr. 30, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Jun. 29, 2017	Apr. 17, 2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of stock option granted				0	0	0
Employee Stock Option
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Options outstanding, aggregate intrinsic value				$ 0
Options outstanding, weighted-average remaining contractual term				3 years 7 months 13 days
Options exercisable, aggregate intrinsic value				$ 0
Options exercisable, weighted-average remaining contractual term				3 years 7 months 6 days
Outstanding non-vested options				30,000
Restricted Stock Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding non-vested restricted stock				72,000
Restricted Stock Units (RSUs)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Outstanding non-vested restricted stock				2,900,000
Performance Units Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Performance period				3 years
Performance Units Awards | 2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares issued		185,000
Performance Units Awards | 2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares issued			381,200
Performance Units Awards | Condition One [Member]
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Award description				For the Performance Units granted in May 2017 and April 2018, 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. For the Performance Units granted in April 2019, the recipients will receive the target number of shares if the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 55th 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.
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
Amended and Restated Plan
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares authorized for grant	28,400,000			28,400,000
Shares available for future issuance	9,500,000			8,331,502			9,800,000
Extended date for awards granted	Jun. 6, 2029
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. 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 | Employees | Employee Stock Option
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, 2019	Jun. 06, 2019	Jun. 29, 2017
Amended and Restated Plan
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Shares Authorized for Grant	28,400,000	28,400,000
Shares Underlying Awards Outstanding	6,320,440
Shares Available for Grant	8,331,502	9,500,000	9,800,000
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	2,533,500

Stock Option Activity (Detail)

Stock Option Activity (Detail)	12 Months Ended
	Dec. 31, 2019$ / sharesshares
Shares
Outstanding at beginning of year | shares	5,501,150
Exercised | shares	(700,000)
Expired | shares	(35,000)
Outstanding at end of year | shares	4,766,150
Exercisable at end of year | shares	4,736,150
Weighted Average Exercise Price Per Share
Outstanding at beginning of year | $ / shares	$ 19.63
Exercised | $ / shares	13.17
Expired | $ / shares	14.95
Outstanding at end of year | $ / shares	20.62
Exercisable at end of year | $ / shares	$ 20.63

Additional Information with Res

Additional Information with Respect to Options Granted, Vested and Exercised (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]
Aggregate grant date fair value of stock options vested during the year	$ 543	$ 1,954	$ 4,565
Aggregate intrinsic value of stock options exercised			$ 209

Additional Information with R_2

Additional Information with Respect to Non-vested Options (Detail) - Employee Stock Option $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Weighted-average remaining contractual term	6 years 8 months 15 days
Weighted-average remaining expected term	1 year 8 months 15 days
Weighted-average remaining vesting period	1 year 8 months 15 days
Unrecognized compensation cost	$ 151

Restricted Stock Activity (Deta

Restricted Stock Activity (Detail) - Restricted Stock Awards	12 Months Ended
	Dec. 31, 2019$ / sharesshares
Shares
Outstanding at beginning of year | shares	436,224
Vested | shares	(362,673)
Forfeited | shares	(1,500)
Outstanding at end of year | shares	72,051
Weighted Average Grant Date Fair Value Per Share
Outstanding at beginning of year | $ / shares	$ 21.41
Vested | $ / shares	21.38
Forfeited | $ / shares	21.71
Outstanding at end of year | $ / shares	$ 21.59

Additional Information on Non-v

Additional Information on Non-vested Restricted Stock (Detail) - Restricted Stock Awards $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate intrinsic value	$ 757
Weighted-average remaining vesting period	3 years
Unrecognized compensation cost	$ 1,247

Restricted Stock Unit Activity

Restricted Stock Unit Activity (Detail)	12 Months Ended
	Dec. 31, 2019$ / sharesshares
Time Based Restricted Stock Units
Shares
Outstanding at beginning of year	2,602,608
Granted	1,505,048
Vested	(1,135,231)	[1]
Forfeited	(340,699)
Outstanding at end of year	2,631,726
Performance Based Restricted Stock Units
Shares
Outstanding at beginning of year	435,315
Vested	(38,000)	[1]
Outstanding at end of year	397,315
Restricted Stock Units (RSUs)
Weighted Average Grant Date Fair Value Per Share
Outstanding at beginning of year | $ / shares	$ 18.95
Granted | $ / shares	12.40
Vested | $ / shares	19.19	[1]
Forfeited | $ / shares	17.08
Outstanding at end of year | $ / shares	$ 15.81
[1]

Additional Information on Non_2

Additional Information on Non-vested Restricted Stock Unit (Detail) - Restricted Stock Units (RSUs) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate intrinsic value	$ 30,938
Weighted-average remaining vesting period	1 year 10 months 24 days
Unrecognized compensation cost	$ 36,933

Performance Units (Detail)

Performance Units (Detail)	12 Months Ended
	Dec. 31, 2019shares
2019
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	489,800
2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	310,700
2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	186,198
2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	185,000
2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	190,600
2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Target number of shares	154,000

Fair Value of Performance Units

Fair Value of Performance Units (Detail) - Performance Units Awards $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
2019
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	$ 9,958
2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	8,004
2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	5,780
2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	3,854
2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	4,052
2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Aggregate fair value at date of grant	$ 5,388

Compensation Expense Associated

Compensation Expense Associated with Performance Units (Detail) - Performance Units Awards - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
2019
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	$ 2,489
2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	2,668	$ 2,001
2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	1,927	1,927	$ 1,284
2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	$ 321	1,285	1,285
2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units		$ 338	1,351
2014
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units			$ 449

Leases - Additional Information

Leases - Additional Information (Detail)	3 Months Ended	12 Months Ended
	Dec. 31, 2019USD ($)	Dec. 31, 2019USD ($)Facility	Dec. 31, 2018USD ($)	Dec. 31, 2017USD ($)
Lessee Lease Description [Line Items]
Operating leasing arrangements initial term	58 months	58 months
Proceeds from sale of facility	$ 10,200,000
Gain on sale of facility		$ 13,904,000	$ 28,958,000	$ 33,510,000
Right of use asset	31,275,000	31,275,000
Operating lease liabilities	36,579,000	$ 36,579,000
New Facility Lease
Lessee Lease Description [Line Items]
Number of facility leases | Facility		3
Right of use asset	3,800,000	$ 3,800,000
Operating lease liabilities	3,800,000	$ 3,800,000
Extended Facility Lease
Lessee Lease Description [Line Items]
Number of facility leases | Facility		9
Right of use asset	7,100,000	$ 7,100,000
Operating lease liabilities	7,100,000	$ 7,100,000
Other Operating Expenses (Income), Net
Lessee Lease Description [Line Items]
Gain on sale of facility	$ 800,000
Minimum
Lessee Lease Description [Line Items]
Operating leasing arrangements initial term	1 year	1 year
Leases remaining lease terms		1 month
Maximum
Lessee Lease Description [Line Items]
Leases remaining lease terms		9 years

Leases - Summary of Lease Expen

Leases - Summary of Lease Expense (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Leases [Abstract]
Operating lease cost	$ 10,944
Short-term lease expense	440	[1]
Total lease expense	$ 11,384
[1]	(1) Short-term lease expense represents expense related to leases with a contract term of one year or less.

Leases - Summary of Supplementa

Leases - Summary of Supplemental Cashflow Information Related to Leases (Detail) $ in Thousands	12 Months Ended
	Dec. 31, 2019USD ($)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$ 10,033
Right of use assets obtained in exchange for lease obligations:
Operating leases	$ 10,870

Leases - Summary of Supplemen_2

Leases - Summary of Supplemental Balance Sheet Information Related to Leases (Detail)	Dec. 31, 2019
Weighted Average Remaining Lease Term:
Operating leases	5 years 3 months 18 days
Weighted Average Discount Rate:
Operating leases	4.20%

Leases - Summary of Maturities

Leases - Summary of Maturities of Operating Lease Liabilities (Detail) $ in Thousands	Dec. 31, 2019USD ($)
Leases [Abstract]
2020	$ 11,212
2021	8,484
2022	6,220
2023	3,955
2024	3,055
Thereafter	7,883
Total lease payments	40,809
Less imputed interest	(4,230)
Total	$ 36,579

Components of Income Tax Provis

Components of Income Tax Provision (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Federal income tax benefit:
Current	$ (1,976)	$ (3,954)	$ (42)
Deferred	(90,441)	(35,081)	(335,106)
Federal income tax benefit, Total	(92,417)	(39,035)	(335,148)
State income tax expense (benefit):
Current	851	1,704	(215)
Deferred	(11,593)	(11,147)	4,511
State and Local Income Tax Expense (Benefit), Continuing Operations, Total	(10,742)	(9,443)	4,296
Foreign income tax expense (benefit):
Current	(348)	(2,552)	(3,108)
Deferred	(1,168)	5,043	249
Foreign Income Tax Expense (Benefit), Continuing Operations, Total	(1,516)	2,491	(2,859)
Total income tax benefit:
Current	(1,473)	(4,802)	(3,365)
Deferred	(103,202)	(41,185)	(330,346)
Total income tax benefit:	$ (104,675)	$ (45,987)	$ (333,711)

Income Taxes - Additional Infor

Income Taxes - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Taxes [Line Items]
Loss before income taxes for the U.S. jurisdictions	$ 499,900,000	$ 343,100,000	$ 312,900,000
Loss before income taxes for non-U.S. jurisdictions	$ 30,500,000	$ 24,300,000	$ 14,900,000
Increase in effective tax rate due to goodwill impairment charges	7.20%
Effective income tax rate	19.70%	12.50%	101.80%
Decrease in effective tax rate of goodwill impairment	0.70%	6.90%
Decrease in effective tax rate of valuation allowances	0.80%	3.70%
Valuation allowances against net deferred tax assets	$ 17,231,000	$ 13,232,000
Gross federal net operating losses	1,400,000,000
Gross Canadian net operating losses	47,400,000
Post-apportionment state net operating losses	847,000,000
Unrecognized tax benefits	0
Canada
Income Taxes [Line Items]
Valuation allowances against net deferred tax assets	$ 4,000,000
Net operating loss carryforwards expiration, beginning year	2036
Net operating loss carryforwards expiration, ending year	2039
Tax periods open for examination	Tax years ended December 31, 2012 through December 31, 2018
Canada | Earliest Tax Year
Income Taxes [Line Items]
Tax period open for examination	2012
Canada | Latest Tax Year
Income Taxes [Line Items]
Tax period open for examination	2018
U.S.
Income Taxes [Line Items]
Net operating loss carryforwards expiration, beginning year	2034
Net operating loss carryforwards expiration, ending year	2037
Tax periods open for examination	Tax years ended December 31, 2014 through December 31, 2018
U.S. | Earliest Tax Year
Income Taxes [Line Items]
Tax period open for examination	2014
U.S. | Latest Tax Year
Income Taxes [Line Items]
Tax period open for examination	2018
State Jurisdictions
Income Taxes [Line Items]
Net operating loss carryforwards expiration, beginning year	2023
Net operating loss carryforwards expiration, ending year	2039

Difference Between Statutory Fe

Difference Between Statutory Federal Income Tax Rate and Effective Income Rate (Detail)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Income Tax Disclosure [Abstract]
Statutory tax rate	21.00%	21.00%	35.00%
State income taxes - net of the federal income tax benefit	1.70%	1.20%	1.90%
Goodwill impairment	(0.70%)	(6.90%)
Permanent differences	(0.50%)	(0.60%)	(1.30%)
Tax effects of tax reform		(1.30%)	66.70%
Share-based payments	(0.70%)	(0.10%)	3.60%
Acquisition related differences			(3.30%)
Valuation allowance	(0.80%)	(3.70%)
State deferred tax remeasurement	(1.10%)	2.30%
Other differences, net	0.80%	0.60%	(0.80%)
Effective tax rate	19.70%	12.50%	101.80%

Tax Effect of Significant Tempo

Tax Effect of Significant Temporary Differences Representing Deferred Tax Assets and Liabilities (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Deferred tax assets:
Net operating loss carryforwards	$ 375,308	$ 324,389
Tax credits	4,138	6,404
Expense associated with stock options and restricted stock	10,561	13,375
Workers' compensation allowance	19,536	19,900
Other deferred tax asset	21,698	22,423
Total deferred tax assets, gross	431,241	386,491
Total deferred tax assets, net	414,010	373,259
Valuation allowance	(17,231)	(13,232)
Deferred tax liabilities:
Property and equipment basis difference	(607,785)	(669,196)
Other	(9,184)	(10,224)
Total deferred tax liabilities	(616,969)	(679,420)
Net deferred tax liability	$ (202,959)	$ (306,161)

Earnings Per Share - Calculatio

Earnings Per Share - 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, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
BASIC EPS:
Net income (loss)	$ (85,923)	$ (261,719)	$ (49,447)	$ (28,614)	$ (201,249)	$ (75,042)	$ (10,713)	$ (34,417)	$ (425,703)	$ (321,421)	$ 5,910
Adjust for (income) loss attributed to holders of non-vested restricted stock											(170)
Income (loss) attributed to common stockholders									$ (425,703)	$ (321,421)	$ 5,740
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock									203,039	218,643	198,447
Basic net income (loss) per common share	$ (0.44)	$ (1.31)	$ (0.24)	$ (0.14)	$ (0.93)	$ (0.34)	$ (0.05)	$ (0.16)	$ (2.10)	$ (1.47)	$ 0.03
DILUTED EPS:
Income (loss) attributed to common stockholders									$ (425,703)	$ (321,421)	$ 5,740
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock									203,039	218,643	198,447
Add dilutive effect of potential common shares											1,435
Weighted average number of diluted common shares outstanding									203,039	218,643	199,882
Diluted net income (loss) per common share	$ (0.44)	$ (1.31)	$ (0.24)	$ (0.14)	$ (0.93)	$ (0.34)	$ (0.05)	$ (0.16)	$ (2.10)	$ (1.47)	$ 0.03
Potentially dilutive securities excluded as anti-dilutive									9,195	9,762	3,289

Employee Benefits - Additional

Employee Benefits - Additional Information (Detail) - USD ($) $ in Millions	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Compensation And Retirement Disclosure [Abstract]
Cash contributions to 401(K) plan	$ 13.2	$ 14.3	$ 8.7

Business Segments - Additional

Business Segments - Additional Information (Detail) $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019USD ($)Rigs	Sep. 30, 2019USD ($)	Jun. 30, 2019USD ($)	Mar. 31, 2019USD ($)	Dec. 31, 2018USD ($)	Sep. 30, 2018USD ($)	Jun. 30, 2018USD ($)	Mar. 31, 2018USD ($)	Dec. 31, 2019USD ($)RigsSegmentCustomer	Dec. 31, 2018USD ($)Customer	Dec. 31, 2017USD ($)Customer
Segment Reporting Disclosure [Line Items]
Number of reportable business segments | Segment									3
Total operating revenues	$ 492,297	$ 598,452	$ 675,765	$ 704,171	$ 795,937	$ 867,478	$ 854,418	$ 809,164	$ 2,470,685	$ 3,326,997	$ 2,356,684
Long-lived assets	$ 3,306,677				4,002,549				$ 3,306,677	$ 4,002,549
Major Customer
Segment Reporting Disclosure [Line Items]
Number of customers accounted for 10% or more of consolidated revenues | Customer									0	0	0
Contract Drilling
Segment Reporting Disclosure [Line Items]
Marketable land-based drilling rigs | Rigs	216								216
Total operating revenues									$ 1,308,350	$ 1,430,492	$ 1,040,033
Contract Drilling | Canada
Segment Reporting Disclosure [Line Items]
Total operating revenues									4,700	9,300	$ 13,700
Long-lived assets	$ 20,100				$ 26,200				$ 20,100	$ 26,200

Business Segments - Revenues (D

Business Segments - Revenues (Detail) - USD ($) $ in Thousands		3 Months Ended								12 Months Ended
		Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues		$ 492,297	$ 598,452	$ 675,765	$ 704,171	$ 795,937	$ 867,478	$ 854,418	$ 809,164	$ 2,470,685	$ 3,326,997	$ 2,356,684
Contract Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues										1,308,350	1,430,492	1,040,033
Pressure Pumping
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues										868,694	1,573,396	1,200,311
Directional Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues										188,786	209,275	45,580
Operating Segments | Contract Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues										1,309,988	1,432,012	1,041,492
Operating Segments | Pressure Pumping
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues										868,694	1,573,396	1,200,311
Operating Segments | Directional Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues										188,786	209,275	45,580
Other Operations
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues	[1]									122,885	131,028	76,781
Intersegment Elimination
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues	[2]									$ (19,668)	$ (18,714)	$ (7,480)
[1]	Other operations includes the Company’s oilfield rentals business, drilling equipment service business, the electrical controls and automation business, the oil and natural gas working interests and Middle East organizational activities.
[2]	Intercompany revenues consists of contract drilling and revenues from other operations for services provided to contract drilling, pressure pumping and within other operations

Business Segments - Income (Los

Business Segments - Income (Loss) Before Income Taxes (Detail) - USD ($)		3 Months Ended								12 Months Ended
		Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		$ (82,763,000)	$ (307,305,000)	$ (48,125,000)	$ (23,383,000)	$ (210,790,000)	$ (80,281,000)	$ (9,004,000)	$ (22,102,000)	$ (461,576,000)	$ (322,177,000)	$ (292,538,000)
Other operating income, net	[1]									2,305,000	17,569,000	31,957,000
Provision for bad debts										(5,683,000)	0	0
Interest income										6,013,000	5,597,000	1,866,000
Interest expense										(75,204,000)	(51,578,000)	(37,472,000)
Other										389,000	750,000	343,000
Loss before income taxes										(530,378,000)	(367,408,000)	(327,801,000)
Corporate
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(96,719,000)	(93,585,000)	(152,792,000)
Operating Segments | Contract Drilling
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(151,329,000)	(33,115,000)	(171,897,000)
Operating Segments | Pressure Pumping
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(102,701,000)	(77,328,000)	21,028,000
Operating Segments | Directional Drilling
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										(52,724,000)	(117,497,000)	(21,000)
Other Operations
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)										$ (54,725,000)	$ (18,221,000)	$ (20,813,000)
[1]	Other operating income, net includes net gains associated with the disposal of assets related to corporate strategy decisions of the executive management group. Accordingly, the related gains have been excluded from the operating results of specific segments. This caption also includes certain legal-related expenses and settlements, net of insurance reimbursements and certain research and development expenses

Business Segments - Depreciatio

Business Segments - Depreciation, Depletion, Amortization and Impairment (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	$ 1,003,873	$ 916,318	$ 783,341
Corporate
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	6,888	7,872	7,695
Operating Segments | Contract Drilling
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	668,007	571,607	538,891
Operating Segments | Pressure Pumping
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	233,952	250,010	198,006
Operating Segments | Directional Drilling
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	52,223	45,317	9,347
Other Operations
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	$ 42,803	$ 41,512	$ 29,402

Business Segments - Capital Exp

Business Segments - Capital Expenditures (Detail) - USD ($) $ in Thousands	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Information [Line Items]
Capital expenditures	$ 347,512	$ 641,458	$ 567,087
Corporate
Segment Reporting Information [Line Items]
Capital expenditures	4,612	2,426	1,884
Operating Segments | Contract Drilling
Segment Reporting Information [Line Items]
Capital expenditures	194,416	394,595	354,425
Operating Segments | Pressure Pumping
Segment Reporting Information [Line Items]
Capital expenditures	105,803	173,848	171,436
Operating Segments | Directional Drilling
Segment Reporting Information [Line Items]
Capital expenditures	15,549	35,929	7,795
Other Operations
Segment Reporting Information [Line Items]
Capital expenditures	$ 27,132	$ 34,660	$ 31,547

Business Segments - Identifiabl

Business Segments - Identifiable Assets (Detail) - USD ($) $ in Thousands		Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		$ 4,439,615	$ 5,469,866	$ 5,758,856
Corporate
Segment Reporting Asset Reconciling Item [Line Items]
Total assets	[1]	261,019	314,276	144,069
Operating Segments | Contract Drilling
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		3,190,463	3,817,638	3,931,994
Operating Segments | Pressure Pumping
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		695,570	921,237	1,209,424
Operating Segments | Directional Drilling
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		164,273	239,341	301,275
Other Operations
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		$ 128,290	$ 177,374	$ 172,094
[1]	Corporate assets primarily include cash on hand and certain property and equipment.

Company's Demand Deposits and T

Company's Demand Deposits and Temporary Cash Investments (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017	Dec. 31, 2016
Risks And Uncertainties [Abstract]
Deposits in FDIC and SIPC-insured institutions under insurance limits	$ 1,250	$ 750
Deposits in FDIC and SIPC-insured institutions over insurance limits	179,375	229,132
Deposits in foreign banks	2,309	22,698
Total cash and cash equivalents	182,934	252,580
Less outstanding checks and other reconciling items	(8,749)	(7,551)
Cash and cash equivalents	$ 174,185	$ 245,029	$ 42,828	$ 35,152

Concentrations of Credit Risk -

Concentrations of Credit Risk - Additional Information (Detail) - USD ($)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Risks And Uncertainties [Abstract]
Expense for bad debts	$ 5,683,000	$ 0	$ 0

Estimated Fair Value of Outstan

Estimated Fair Value of Outstanding Debt Balances (Detail) - USD ($) $ in Thousands	Dec. 31, 2019	Dec. 31, 2018
Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	$ 975,000	$ 1,125,000
Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	970,349	1,076,431
3.95% Senior Notes Due 2028 | Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	525,000	525,000
3.95% Senior Notes Due 2028 | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	511,485	482,488
5.15% Senior Notes Due 2029 | Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	350,000
5.15% Senior Notes Due 2029 | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	358,864
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
4.97% Series A Senior Notes, Due October 5th 2020 | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt		300,043
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
4.27% Series B Senior Notes, Due June 14th 2022 | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt		$ 293,900
2019 Term Loan | Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	100,000
2019 Term Loan | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	$ 100,000

Fair Values of Financial Inst_3

Fair Values of Financial Instruments - Additional Information (Detail)	12 Months Ended
	Dec. 31, 2019	Dec. 31, 2018	Nov. 15, 2019	Jan. 19, 2018	Jun. 14, 2012	Oct. 05, 2010
3.95% Senior Notes Due 2028
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Debt interest rate	3.95%	3.95%		3.95%
Current market rates used in measuring fair value	4.33%	5.07%
5.15% Senior Notes Due 2029
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Debt interest rate	5.15%		5.15%
Current market rates used in measuring fair value	4.81%
4.97% Series A Senior Notes, Due October 5th 2020
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Debt interest rate						4.97%
Current market rates used in measuring fair value		4.97%
4.27% Series B Senior Notes, Due June 14th 2022
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Debt interest rate					4.27%
Current market rates used in measuring fair value		4.92%

Quarterly Financial Informati_3

Quarterly Financial Information (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended								12 Months Ended
	Dec. 31, 2019	Sep. 30, 2019	Jun. 30, 2019	Mar. 31, 2019	Dec. 31, 2018	Sep. 30, 2018	Jun. 30, 2018	Mar. 31, 2018	Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Quarterly Financial Information Disclosure [Abstract]
Operating revenues	$ 492,297	$ 598,452	$ 675,765	$ 704,171	$ 795,937	$ 867,478	$ 854,418	$ 809,164	$ 2,470,685	$ 3,326,997	$ 2,356,684
Operating income (loss)	(82,763)	(307,305)	(48,125)	(23,383)	(210,790)	(80,281)	(9,004)	(22,102)	(461,576)	(322,177)	(292,538)
Net income (loss)	$ (85,923)	$ (261,719)	$ (49,447)	$ (28,614)	$ (201,249)	$ (75,042)	$ (10,713)	$ (34,417)	$ (425,703)	$ (321,421)	$ 5,910
Net loss per common share:
Basic	$ (0.44)	$ (1.31)	$ (0.24)	$ (0.14)	$ (0.93)	$ (0.34)	$ (0.05)	$ (0.16)	$ (2.10)	$ (1.47)	$ 0.03
Diluted	$ (0.44)	$ (1.31)	$ (0.24)	$ (0.14)	$ (0.93)	$ (0.34)	$ (0.05)	$ (0.16)	$ (2.10)	$ (1.47)	$ 0.03

Valuation and Qualifying Acco_2

Valuation and Qualifying Accounts (Detail) - Allowance for Doubtful Accounts - USD ($) $ in Thousands		12 Months Ended
		Dec. 31, 2019	Dec. 31, 2018	Dec. 31, 2017
Valuation And Qualifying Accounts Disclosure [Line Items]
Beginning Balance		$ 2,312	$ 2,323	$ 3,191
Charged to Costs and Expenses		5,683
Deductions	[1]	(1,479)	(11)	(868)
Ending Balance		$ 6,516	$ 2,312	$ 2,323
[1]