10-Q

38*523000" 

UNITED STATES

SECURITIES AND EXCHANGE COMMISSION

Washington, D.C. 20549

Form 10-Q

☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the quarterly period ended March 31, 2019

or

☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934

For the transition period from                     to                     

Commission file number 0-22664

Patterson-UTI Energy, Inc.

(Exact name of registrant as specified in its charter)

DELAWARE	75-2504748
(State or other jurisdiction of incorporation or organization)	(I.R.S. Employer Identification No.)
10713 W. SAM HOUSTON PKWY N, SUITE 800 HOUSTON, TEXAS	77064
(Address of principal executive offices)	(Zip Code)

(281) 765-7100

(Registrant’s telephone number, including area code)

N/A

(Former name, former address and former fiscal year, if changed since last report)

Indicate by check mark whether the registrant (1) has filed all reports required to be filed by Section 13 or 15(d) of the Securities Exchange Act of 1934 during the preceding 12 months (or for such shorter period that the registrant was required to file such reports), and (2) has been subject to such filing requirements for the past 90 days.     Yes ☑     No ☐

Indicate by check mark whether the registrant has submitted electronically every Interactive Data File required to be submitted pursuant to Rule 405 of Regulation S-T (section 232.405 of this chapter) during the preceding 12 months (or for such shorter period that the registrant was required to submit such files).     Yes ☑    No ☐

Indicate by check mark whether the registrant is a large accelerated filer, an accelerated filer, a non-accelerated filer, a smaller reporting company, or an emerging growth company. See the definitions of “large accelerated filer,” “accelerated filer,” “smaller reporting company,” and “emerging growth company” in Rule 12b-2 of the Exchange Act:

Large accelerated filer	☑	Accelerated filer	☐	Smaller reporting company	☐
Non-accelerated filer	☐			Emerging growth company	☐

If an emerging growth company, indicate by check mark if the registrant has elected not to use the extended transition period for complying with any new or revised financial accounting standards provided pursuant to Section 13(a) of the Exchange Act.          ☐

Indicate by check mark whether the registrant is a shell company (as defined in Rule 12b-2 of the Exchange Act).     Yes ☐    No ☑

Indicate the number of shares outstanding of each of the issuer’s classes of common stock, as of the latest practicable date.

208,542,994 shares of common stock, $0.01 par value, as of April 25, 2019

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

TABLE OF CONTENTS

	PART I — FINANCIAL INFORMATION
		Page
ITEM 1.	Financial Statements
	Unaudited condensed consolidated balance sheets	3
	Unaudited condensed consolidated statements of operations	4
	Unaudited condensed consolidated statements of comprehensive loss	5
	Unaudited condensed consolidated statements of changes in stockholders’ equity	6
	Unaudited condensed consolidated statements of cash flows	7
	Notes to unaudited condensed consolidated financial statements	8
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	25
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	34
ITEM 4.	Controls and Procedures	35
	PART II — OTHER INFORMATION
ITEM 1.	Legal Proceedings	36
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	37
ITEM 6.	Exhibits	38
Signature		39

PART I — FINANCIAL INFORMATION

ITEM 1. Financial Statements

The following unaudited condensed consolidated financial statements include all adjustments which are, in the opinion of management, necessary for a fair statement of the results for the interim periods presented.

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED BALANCE SHEETS

(unaudited, in thousands, except share data)

	March 31,			December 31,
	2019			2018
ASSETS
Current assets:
Cash and cash equivalents	$	248,901		$	245,029
Accounts receivable, net of allowance for doubtful accounts of $2,307 and $2,312    at March 31, 2019 and December 31, 2018, respectively		547,993			558,817
Federal and state income taxes receivable		4,083			4,110
Inventory		65,871			65,579
Other		60,883			76,662
Total current assets		927,731			950,197
Property and equipment, net		3,898,518			4,002,549
Right of use asset		28,405			—
Goodwill and intangible assets		476,078			477,640
Deposits on equipment purchases		10,505			12,040
Other		26,515			27,440
Total assets	$	5,367,752		$	5,469,866
LIABILITIES AND STOCKHOLDERS' EQUITY
Current liabilities:
Accounts payable	$	260,378		$	288,962
Federal and state income taxes payable		1,367			1,408
Accrued expenses		240,196			235,946
Lease liability		9,217			-
Total current liabilities		511,158			526,316
Long-term lease liability		23,903			—
Long-term debt, net of debt discount and issuance costs of $5,574 and $5,795    at March 31, 2019 and December 31, 2018, respectively		1,119,426			1,119,205
Deferred tax liabilities, net		299,557			306,161
Other		10,339			12,761
Total liabilities		1,964,383			1,964,443
Commitments and contingencies (see Note 10)
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 267,353,108 and    267,315,526 issued and 208,243,640 and 213,614,430 outstanding at    March 31, 2019 and December 31, 2018, respectively		2,673			2,673
Additional paid-in capital		2,836,492			2,827,154
Retained earnings		1,716,334			1,753,557
Accumulated other comprehensive income		3,431			2,487
Treasury stock, at cost, 59,109,468 and 53,701,096 shares at    March 31, 2019 and December 31, 2018, respectively		(1,155,561	)		(1,080,448	)
Total stockholders' equity		3,403,369			3,505,423
Total liabilities and stockholders' equity	$	5,367,752		$	5,469,866

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

3

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited, in thousands, except per share data)

	Three Months Ended
	March 31,
	2019			2018
Operating revenues:
Contract drilling	$	372,392		$	327,803
Pressure pumping		247,601			406,784
Directional drilling		52,959			48,616
Other		31,219			25,961
Total operating revenues		704,171			809,164
Operating costs and expenses:
Contract drilling		219,202			212,583
Pressure pumping		202,748			320,970
Directional drilling		45,602			37,689
Other		21,773			17,745
Depreciation, depletion, amortization and impairment		214,410			209,892
Selling, general and administrative		32,555			32,817
Merger and integration expenses		—			1,991
Other operating income, net		(8,736	)		(2,421	)
Total operating costs and expenses		727,554			831,266
Operating loss		(23,383	)		(22,102	)
Other income (expense):
Interest income		1,032			1,423
Interest expense, net of amount capitalized		(12,984	)		(13,625	)
Other		117			169
Total other expense		(11,835	)		(12,033	)
Loss before income taxes		(35,218	)		(34,135	)
Income tax expense (benefit)		(6,604	)		282
Net loss	$	(28,614	)	$	(34,417	)
Net loss per common share:
Basic	$	(0.14	)	$	(0.16	)
Diluted	$	(0.14	)	$	(0.16	)
Weighted average number of common shares outstanding:
Basic		211,868			220,783
Diluted		211,868			220,783
Cash dividends per common share	$	0.04		$	0.02

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

4

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS

(unaudited, in thousands)

	Three Months Ended
	March 31,
	2019			2018
Net loss	$	(28,614	)	$	(34,417	)
Other comprehensive income (loss), net of taxes of $0 for all periods:
Foreign currency translation adjustment		944			(1,984	)
Total comprehensive loss	$	(27,670	)	$	(36,401	)

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

5

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY

(unaudited, in thousands)

											Accumulated
	Common Stock					Additional					Other
	Number of					Paid-in		Retained			Comprehensive		Treasury
	Shares			Amount		Capital		Earnings			Income (Loss)		Stock			Total
Balance, December 31, 2018		267,316		$	2,673	$	2,827,154	$	1,753,557		$	2,487	$	(1,080,448	)	$	3,505,423
Net loss		—			—		—		(28,614	)		—		—			(28,614	)
Foreign currency translation adjustment		—			—		—		—			944		—			944
Vesting of restricted stock units		38			—		—		—			—		—			—
Forfeitures of restricted stock		(1	)		—		—		—			—		—			—
Stock-based compensation		—			—		9,338		—			—		—			9,338
Payment of cash dividends		—			—		—		(8,499	)		—		—			(8,499	)
Dividend equivalents		—			—		—		(110	)		—		—			(110	)
Purchase of treasury stock		—			—		—		—			—		(75,113	)		(75,113	)
Balance, March 31, 2019		267,353		$	2,673	$	2,836,492	$	1,716,334		$	3,431	$	(1,155,561	)	$	3,403,369

										Accumulated
	Common Stock				Additional					Other
	Number of				Paid-in		Retained			Comprehensive			Treasury
	Shares		Amount		Capital		Earnings			Income (Loss)			Stock			Total
Balance, December 31, 2017		266,259	$	2,662	$	2,785,823	$	2,105,897		$	6,822		$	(918,711	)	$	3,982,493
Net loss		—		—		—		(34,417	)		—			—			(34,417	)
Foreign currency translation adjustment		—		—		—		—			(1,984	)		—			(1,984	)
Exercise of stock options		40		1		484		—			—			—			485
Stock-based compensation		—		—		9,365		—			—			—			9,365
Payment of cash dividends		—		—		—		(4,443	)		—			—			(4,443	)
Dividend equivalents		—		—		—		(30	)		—			—			(30	)
Purchase of treasury stock		—		—		—		—			—			(16,928	)		(16,928	)
Balance, March 31, 2018		266,299	$	2,663	$	2,795,672	$	2,067,007		$	4,838		$	(935,639	)	$	3,934,541

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

6

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited, in thousands)

	Three Months Ended
	March 31,
	2019			2018
Cash flows from operating activities:
Net loss	$	(28,614	)	$	(34,417	)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion, amortization and impairment		214,410			209,892
Dry holes and abandonments		21			96
Deferred income tax expense (benefit)		(6,604	)		282
Stock-based compensation expense		9,338			9,365
Net gain on asset disposals		(6,545	)		(10,410	)
Amortization of debt discount and issuance costs		221			170
Changes in operating assets and liabilities:
Accounts receivable		10,929			(16,468	)
Income taxes receivable/payable		(14	)		19
Inventory and other assets		6,592			2,709
Accounts payable		(17,858	)		(22,514	)
Accrued expenses		2,871			11,174
Other liabilities		(915	)		67
Net cash provided by operating activities		183,832			149,965
Cash flows from investing activities:
Acquisitions, net of cash acquired		(13	)		(3,800	)
Purchases of property and equipment		(118,341	)		(122,921	)
Proceeds from disposal of assets and insurance claims		22,054			10,294
Net cash used in investing activities		(96,300	)		(116,427	)
Cash flows from financing activities:
Purchases of treasury stock		(75,113	)		(16,928	)
Proceeds from exercise of options		—			485
Dividends paid		(8,499	)		(4,443	)
Debt issuance costs		—			(4,198	)
Proceeds from long-term debt		—			521,194
Proceeds from borrowings under revolving credit facility		—			79,000
Repayment of borrowings under revolving credit facility		—			(347,000	)
Net cash provided by financing activities		(83,612	)		228,110
Effect of foreign exchange rate changes on cash		(48	)		(225	)
Net increase in cash and cash equivalents		3,872			261,423
Cash and cash equivalents at beginning of period		245,029			42,828
Cash and cash equivalents at end of period	$	248,901		$	304,251
Supplemental disclosure of cash flow information:
Net cash (paid) received during the period for:
Interest, net of capitalized interest of $257 in 2019 and $340 in 2018	$	(10,689	)	$	(2,206	)
Income taxes		(15	)		21
Non-cash investing and financing activities:
Receivable from property and equipment insurance	$	—		$	15,000
Net increase (decrease) in payables for purchases of property and equipment		(10,764	)		62,488
Net (increase) decrease in deposits on equipment purchases		1,535			(2,294	)

The accompanying notes are an integral part of these unaudited condensed consolidated financial statements.

7

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

NOTES TO UNAUDITED CONDENSED CONSOLIDATED FINANCIAL STATEMENTS

1. Basis of Presentation

Basis of presentation - The unaudited interim condensed consolidated financial statements include the accounts of Patterson-UTI Energy, Inc. and its wholly-owned subsidiaries (collectively referred to herein as the “Company”). 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 unaudited interim condensed consolidated financial statements have been prepared by management of the Company pursuant to the rules and regulations of the United States Securities and Exchange Commission (“SEC”). Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) have been omitted pursuant to such rules and regulations, although the Company believes the disclosures included either on the face of the financial statements or herein are sufficient to make the information presented not misleading. In the opinion of management, all recurring adjustments considered necessary for a fair statement of the information in conformity with U.S. GAAP have been included. The unaudited condensed consolidated balance sheet as of December 31, 2018, as presented herein, was derived from the audited consolidated balance sheet of the Company, but does not include all disclosures required by U.S. GAAP. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes included in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018. The results of operations for the three months ended March 31, 2019 are not necessarily indicative of the results to be expected for the full year.

The U.S. dollar is the functional currency for all of the Company’s operations except for its Canadian operations, which use the Canadian dollar as its functional currency. The effects of exchange rate changes are reflected in accumulated other comprehensive income, which is a separate component of stockholders’ equity.

Recently Issued Accounting Standards – In May 2014, the Financial Accounting Standards Board (“FASB”) issued an accounting standards update to provide guidance on the recognition of revenue from customers.  Under this guidance, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects what it expects in exchange for the goods or services.  This guidance also requires more detailed disclosures to enable users of the financial statements to understand the nature, amount, timing and uncertainty, if any, of revenue and cash flows arising from contracts with customers.  The requirements in this update are effective during interim and annual periods beginning after December 15, 2017.  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 by class of underlying asset to not recognize the lease liability and related right-of-use asset for leases with a term of one year or less.  The provisions of this standard also apply to situations where the Company is the lessor. The requirements in this update are effective during interim and annual periods beginning after December 15, 2018.  The Company 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 4).  

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.

8

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 for additional information.

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 amendments in the update are effective for public business entities for fiscal years beginning after December 15, 2019, with early adoption permitted. The Company is currently evaluating the impact this new guidance will have on its consolidated financial statements.

2. Acquisitions

Superior QC, LLC (“Superior QC”)

On February 20, 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 of horizontal wellbore placement.  Superior QC’s measurement while drilling (MWD) survey fault detection, isolation and recovery (FDIR) service is a data analytics technology to analyze MWD survey data in real-time and more accurately identify the position of a well.  This acquisition was not material to the Company’s consolidated financial statements.

Current Power Solutions, Inc. (“Current Power”)

On October 25, 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.

3. Revenues

ASC 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 that 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, oilfield technology, electrical controls and automation, and oil and natural gas working interests.  For more information on the Company’s business segments, including disaggregated revenue recognized from contracts with customers, see Note 15.

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.

9

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.

Accounts Receivable and Contract Liabilities

Accounts receivable is the Company’s right to consideration once it becomes unconditional.  Payment terms range from 30 to 60 days.

Accounts receivable balances were $544 million and $554 million as of March 31, 2019 and December 31, 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 Condensed 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 three months ended March 31, 2019 and 2018, approximately $402,000 and $405,000, respectively, was amortized and recorded in drilling revenue.

Contract liability balances for customer prepayments were $6.8 million and $3.0 million as of March 31, 2019 and December 31, 2018, respectively.  Contract liability balances for deferred mobilization payments relating to newly constructed or upgraded rigs were $4.2 million and $4.6 million as of March 31, 2019 and December 31, 2018, respectively. Contract liability balances for customer prepayments are included in “Accounts Payable” and contract liability balances for deferred mobilization payments are included in “Accrued Liabilities” in the Condensed 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.  

4. Leases

     ASC Topic 842 Leases

     On January 1, 2019, the Company adopted the new lease guidance under Topic 842, Leases, using the modified retrospective approach to each lease that existed at the date of initial application as well as leases entered into after that date.  The Company has elected to report all leases at the beginning of the period of adoption and not restate its comparative periods.  This standard does not apply to leases to explore for or use minerals, oil, natural gas and similar non-regenerative resources, including the intangible right to

explore for those natural resources and rights to use the land in which those natural resources are contained.

     The Company has entered into operating leases for operating locations, corporate offices and certain operating equipment.  These leases have remaining lease terms of 1 month to 9 years as of March 31, 2019.  Currently, the Company does not have any finance leases.  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 less than one year.

     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.  

10

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 contains 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 our 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 three months ended March 31, 2019 (in thousands):

	Three Months Ended
	March 31,
	2019
Operating lease cost	$	3,039
Short-term lease expense (1)		276
Total lease expense	$	3,315

(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 three months ended March 31, 2019 is as follows (in thousands):

	Three Months Ended
	March 31,
	2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	2,728
Right of use assets obtained in exchange for lease obligations:
Operating leases	$	-

          Supplemental balance sheet information related to leases as of March 31, 2019 is as follows:

	March 31,
	2019
Weighted Average Remaining Lease Term:
Operating leases	5.0 years
Weighted Average Discount Rate:
Operating leases		4.4	%

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          Maturities of operating lease liabilitiesas of March 31, 2019 are as follows (in thousands):

Year ending December 31,
2019 (excluding the three months ended March 31, 2019)	$	8,062
2020		9,188
2021		6,661
2022		4,622
2023		2,663
Thereafter		6,552
Total lease payments		37,748
Less imputed interest		(4,628	)
Total	$	33,120

          Maturities of operating lease liabilities as of December 31, 2018, as previously disclosed in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018, are as follows (in thousands):

Year ending December 31,
2019	$	11,408
2020		9,069
2021		6,543
2022		4,625
2023		2,663
Thereafter		6,552
Total	$	40,860

5. Inventory

Inventory consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,		December 31,
	2019		2018
Finished goods	$	602	$	347
Work-in-process		6,088		6,375
Raw materials and supplies		59,181		58,857
Inventory	$	65,871	$	65,579

6. Property and Equipment

Property and equipment consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,			December 31,
	2019			2018
Equipment	$	8,392,658		$	8,370,933
Oil and natural gas properties		221,782			219,855
Buildings		186,989			186,736
Land		26,898			26,144
Total property and equipment		8,828,327			8,803,668
Less accumulated depreciation, depletion and impairment		(4,929,809	)		(4,801,119	)
Property and equipment, net	$	3,898,518		$	4,002,549

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.

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The Company concluded that no triggering events occurred during the three months ended March 31, 2019 with respect to its asset groups based on the Company’s results of operations for the three months ended March 31,2019, management’s expectations of operating results in future periods and the prevailing commodity prices at the time. 

7. Goodwill and Intangible Assets

Goodwill — Goodwill by operating segment as of March 31, 2019 and changes for the three months then ended are as follows (in thousands):

	Contract		Other
	Drilling		Operations		Total
Balance at beginning of period	$	395,060		15,696	$	410,756
Changes to goodwill		—		2,104		2,104
Balance at end of period	$	395,060	$	17,800	$	412,860

The goodwill reflected above has increased $2.1 million from the original Current Power purchase price allocation primarily as a result of a measurement period adjustment related to accrued liabilities.  There were no accumulated impairment losses related to goodwill in the contract drilling segment or other operations as of March 31, 2019 or December 31, 2018.

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.

Intangible Assets — The following table presents the gross carrying amount and accumulated amortization of the intangible assets as of March 31, 2019 and December 31, 2018 (in thousands):

	March 31, 2019							December 31, 2018
	Gross					Net		Gross					Net
	Carrying		Accumulated			Carrying		Carrying		Accumulated			Carrying
	Amount		Amortization			Amount		Amount		Amortization			Amount
Customer relationships	$	28,000	$	(12,967	)		15,033	$	28,000	$	(10,719	)	$	17,281
Developed technology		55,772		(7,927	)		47,845		55,772		(6,533	)		49,239
Favorable drilling contracts		-		-			-		22,500		(22,500	)		-
Internal use software		482		(142	)		340		482		(118	)		364
	$	84,254	$	(21,036	)	$	63,218	$	106,754	$	(39,870	)	$	66,884

Amortization expense on intangible assets of approximately $3.7 million and $5.4 million was recorded in the three months ended March 31, 2019 and 2018, respectively.

8. Accrued Expenses

Accrued expenses consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,		December 31,
	2019		2018
Salaries, wages, payroll taxes and benefits	$	58,717	$	58,160
Workers' compensation liability		82,537		83,772
Property, sales, use and other taxes		21,156		25,318
Insurance, other than workers' compensation		9,611		9,531
Accrued interest payable		17,806		15,774
Accrued merger and integration		1,890		2,403
Other		48,479		40,988
Total	$	240,196	$	235,946

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9. Long Term Debt

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 (the “Amendment”), 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.  The Company has the option, subject to certain conditions, to exercise two one-year extensions of the maturity date.

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 March 31, 2019, the Company had no amounts outstanding under the revolving credit facility.  The Company had $81,000 in letters of credit outstanding under the revolving credit facility at March 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 March 31, 2019, the Company had $51.4 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.

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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 & B Senior Notes — On October 5, 2010, the Company completed the issuance and sale of $300 million in aggregate principal amount of its 4.97% Series A Senior Notes due October 5, 2020 (the “Series A Notes”) in a private placement. The Series A Notes bear interest at a rate of 4.97% per annum. The Company pays interest on the Series A Notes on April 5 and October 5 of each year. The Series A Notes will mature on October 5, 2020.

On June 14, 2012, the Company completed the issuance and sale of $300 million in aggregate principal 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 bear interest at a rate of 4.27% per annum. The Company pays interest on the Series B Notes on April 5 and October 5 of each year. The Series B Notes will mature on June 14, 2022.

The Series A Notes and Series B Notes are senior unsecured obligations of the Company which rank equally in right of payment with all other unsubordinated indebtedness of the Company. The Series A Notes and Series B Notes are guaranteed on a senior unsecured basis by each of the existing domestic subsidiaries of the Company other than subsidiaries that are not required to be guarantors under the Credit Agreement. No subsidiaries of the Company are currently required to be a guarantor under the Credit Agreement.

The Series A Notes and Series B Notes are prepayable at the Company’s option, in whole or in part, provided that in the case of a partial prepayment, prepayment must be in an amount not less than 5% of the aggregate principal amount of the notes then outstanding, at any time and from time to time at 100% of the principal amount prepaid, plus accrued and unpaid interest to the prepayment date, plus a “make-whole” premium as specified in the note purchase agreements. The Company must offer to prepay the notes upon the occurrence of any change of control. In addition, the Company must offer to prepay the notes upon the occurrence of certain asset dispositions if the proceeds therefrom are not timely reinvested in productive assets. If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.

The respective note purchase agreements require compliance with two financial covenants. The Company must not permit its debt to capitalization ratio to exceed 50% at any time. The note purchase agreements generally define the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit its interest coverage ratio as of the last day of a fiscal quarter to be less than 2.50 to 1.00. The note purchase agreements generally define the interest coverage ratio as the ratio of EBITDA for the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at March 31, 2019.

Events of default under the note purchase agreements include failure to pay principal or interest when due, failure to comply with the financial and operational covenants, a cross default event, a judgment in excess of a threshold event, the guaranty agreement ceasing to be enforceable, the occurrence of certain ERISA events, a change of control event and bankruptcy and other insolvency events. If an event of default under the note purchase agreements occurs and is continuing, then holders of a majority in principal amount of the respective notes have the right to declare all the notes then-outstanding to be immediately due and payable. In addition, if the Company defaults in payments on any note, then until such defaults are cured, the holder thereof may declare all the notes held by it pursuant to the note purchase agreement to be immediately due and payable.

2028 Senior Notes – On January 19, 2018, the Company completed its offering of $525 million aggregate principal amount of the Company’s 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.  

The Company pays interest on the 2028 Notes on February 1 and August 1 of each year.  The 2028 Notes will mature on February 1, 2028.  The 2028 Notes bear interest at a rate of 3.95% per annum.

The 2028 Notes are 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 2028 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 2028 Notes will be structurally subordinated to the liabilities (including trade payables) of the Company’s subsidiaries that do not guarantee the 2028 Notes.  No subsidiaries of the Company are currently required to be a guarantor under the 2028 Notes.  If subsidiaries of the Company guarantee the 2028 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

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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 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 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date, plus a make-whole premium.  Additionally, commencing on November 1, 2027, the Company, at its option, may redeem the 2028 Notes in whole or in part, at a redemption price equal to 100% of the principal amount of the 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date.

The indenture pursuant to which the 2028 Notes were issued includes covenants that, among other things, limit the Company and its subsidiaries’ ability to incur certain liens, engage in sale and lease-back transactions or consolidate, merge, or transfer all or substantially all of their assets.  These covenants are subject to important qualifications and limitations set forth in the indenture.

Upon the occurrence of a change of control, as defined in the indenture, each holder of the 2028 Notes may require the Company to purchase all or a portion of such holder’s 2028 Notes at a price equal to 101% of their principal amount, plus accrued and unpaid interest, if any, to, but excluding, the repurchase date.

The indenture also provides for events of default which, if any of them occurs, would permit or require the principal of, premium, if any, and accrued interest, if any, on the 2028 Notes to become or to be declared due and payable.

Debt issuance costs –Debt issuance costs are deferred and recognized as interest expense over the term of the underlying debt.  Interest expense related to the amortization of debt issuance costs was approximately $351,000 and $938,000 for the three months ended March 31, 2019 and 2018, respectively.  Amortization of debt issuance costs for the three months ended March 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 2018 Credit Agreement.

Presented below is a schedule of the principal repayment requirements of long-term debt as of March 31, 2019 (in thousands):

Year ending December 31,
2019	$	—
2020		300,000
2021		—
2022		300,000
2023		—
Thereafter		525,000
Total	$	1,125,000

10. Commitments and Contingencies

As of March 31, 2019, the Company maintained letters of credit in the aggregate amount of $51.4 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 March 31, 2019, no amounts had been drawn under the letters of credit.

As of March 31, 2019, the Company had commitments to purchase major equipment and make investments totaling approximately $89.9 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 2019 through 2023. As of March 31, 2019, the remaining obligation under these agreements was approximately $50 million, of which approximately $22.3 million relates to purchases required during the remainder of 2019. 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.

On January 22, 2018, an accident at a drilling site in Pittsburg County, Oklahoma resulted in the losses of life of five people, including three of the Company’s employees. Lawsuits have been filed in the District Court for Pittsburg County, Oklahoma in connection with the five individuals who lost their lives and one of the Company’s employees who was injured in the accident.  The lawsuits have been consolidated for discovery purposes under Cause No. CJ-2018-60 (the “Litigation”).  These lawsuits allege various causes of action against the Company including negligence, gross negligence, knowledge that injury or death was substantially certain, acting with purpose, recklessness, wrongful death and survival, and the plaintiffs seek an unspecified amount of damages, including punitive or exemplary damages, costs, interest, and other relief.  The Company has finalized settlement agreements with four of the plaintiffs who brought wrongful death lawsuits.  The Company disputes the plaintiffs’ allegations against the Company in the

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remaining lawsuits and intends to continue to defend itself vigorously.  Based on the information the Company has available as of the date of this Report, the Company believes that it has adequate insurance to cover the Litigation. However, if this accident is not fully covered by insurance or an enforceable and recoverable indemnity from a third party, it could have a material adverse effect on the Company’s business, financial condition, cash flows and results of operations.

The Company is party to various 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.

11. Stockholders’ Equity

Cash Dividends — The Company paid cash dividends during the three months ended March 31, 2019 and 2018 as follows:

2019:	Per Share		Total
			(in thousands)
Paid on March 21, 2019	$	0.04	$	8,499

2018:	Per Share		Total
			(in thousands)
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

On April 24, 2019, 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 June 20, 2019 to holders of record as of June 6, 2019. 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 February 6, 2019, the Company’s Board of Directors approved another increase of the authorization under the stock buyback program to allow for $250 million of share repurchases.  All purchases executed to date have been through open market transactions.  Purchases under the program are made at management’s discretion, at prevailing prices, subject to market conditions and other factors. Purchases may be made at any time without prior notice.  There is no expiration date associated with the buyback program.  As of March 31, 2019, the Company had remaining authorization to purchase approximately $175 million of the Company’s outstanding common stock under the stock buyback program. Shares of stock purchased under the buyback program are held as treasury shares. The Company acquired shares of stock from employees during the first quarter that are accounted for as treasury stock. These shares were acquired to satisfy payroll withholding obligations upon the vesting of restricted shares and restricted stock units.  These shares were acquired at fair market value. These acquisitions were made pursuant to the terms of the Patterson-UTI Energy, Inc. Amended and Restated 2014 Long-Term Incentive Plan (the “2014 Plan”) and not pursuant to the stock buyback program.  

Treasury stock acquisitions during the three months ended March 31, 2019 were as follows (dollars in thousands):

	Shares		Cost
Treasury shares at beginning of period		53,701,096	$	1,080,448
Purchases pursuant to stock buyback program		5,408,132		75,110
Acquisitions pursuant to long-term incentive plan		240		3
Treasury shares at end of period		59,109,468	$	1,155,561

12. 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

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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.  

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 three months ended March 31, 2019 or 2018.   

Stock option activity from January 1, 2019 to March 31, 2019 follows:

			Weighted
			Average
	Underlying		Exercise Price
	Shares		Per Share
Outstanding at January 1, 2019		5,501,150	$	19.63
Exercised		—	$	-
Expired		—	$	-
Outstanding at March 31, 2019		5,501,150	$	19.63
Exercisable at March 31, 2019		5,432,679	$	19.64

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 from January 1, 2019 to March 31, 2019 follows:

				Weighted
				Average Grant
				Date Fair Value
	Shares			Per Share
Non-vested restricted stock outstanding at January 1, 2019		436,224		$	21.41
Vested		(64,494	)	$	20.61
Forfeited		(1,033	)	$	21.71
Non-vested restricted stock outstanding at March 31, 2019		370,697		$	21.55

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 from January 1, 2019 to March 31, 2019 follows:

						Weighted
						Average Grant
	Time			Performance		Date Fair Value
	Based			Based		Per Share
Non-vested restricted stock units outstanding at January 1, 2019		2,602,608			435,315	$	18.95
Granted		101,448			—	$	10.35
Vested		(38,615	)		—	$	22.95
Forfeited		(46,738	)		—	$	19.23
Non-vested restricted stock units outstanding at March 31, 2019		2,618,703			435,315	$	18.61

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.  

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The performance goals for the Performance Units are tied to the Company’s total shareholder return for the performance period as compared to total shareholder return for a peer group determined by the Compensation Committee.  These goals are considered to be market conditions under the relevant accounting standards and the market conditions were factored into the determination of the fair value of the respective Performance Units.  Generally, the recipients will receive a target number of shares if the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 50^th percentile.  If the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 75^th 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 25^th 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 25^th and 75^th percentile, then the shares to be received by the recipients will be determined using linear interpolation for levels of achievement between these points.  

In April 2018, 381,200 shares were issued to settle the 2015 Performance Units. For the Performance Units granted in April 2016, if the Company’s total shareholder return for the performance period is negative, and, when compared to the peer group is at or above the 25th percentile, then the recipients will receive one-half of the number of shares they would have received had the Company’s total shareholder return been positive.  For the Performance Units granted in May 2017 and April 2018, the payout is based on relative performance and does not have an absolute performance requirement.  

The total target number of shares with respect to the Performance Units for the awards granted in 2015-2018 is set forth below:

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Target number of shares		310,700		186,198		185,000		190,600

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):

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Fair value at date of grant	$	8,004	$	5,780	$	3,854	$	4,052

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 shown below (in thousands):

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Three months ended March 31, 2019	$	667	$	482	$	321	NA
Three months ended March 31, 2018	NA		$	482	$	321	$	338

13. Income Taxes

The Company’s effective income tax rate fluctuates from the U.S. statutory tax rate based on, among other factors, changes in pretax income in jurisdictions with varying statutory tax rates, impact of U.S. state and local taxes, and other differences related to the recognition of income and expense between U.S. GAAP and tax.

The Company’s effective income tax rate for the three months ended March 31, 2019 was 18.8%, compared with (.8)% for the three months ended March 31, 2018. The lower effective income tax rate for the three months ended March 31, 2018 was primarily attributable to changes in forecasted annual pretax income in the first quarter of 2018 as compared to the forecasted annual pretax income in the first quarter of 2019.  The Company also recorded a valuation allowance against the net deferred tax assets of a Canadian subsidiary of the Company due to a change in judgment as to the realizability of these assets in the first quarter of 2018.

The Company continues to monitor income tax developments in the United States and other countries where the Company operates.  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 to be finalized during 2019, as well as additional regulations to be proposed and finalized during 2019.  The Company will incorporate into its future financial statements the impacts, if any, of these regulations and additional authoritative guidance when finalized.

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14. Earnings Per Share

The Company provides a dual presentation of its net loss per common share in its unaudited condensed consolidated statements of operations: basic net loss per common share (“Basic EPS”) and diluted net 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 loss per share for the three months ended March 31, 2019 and 2018 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):

	Three Months Ended
	March 31,
	2019			2018
BASIC EPS:
Net loss attributed to common stockholders	$	(28,614	)	$	(34,417	)
Weighted average number of common shares outstanding, excluding    non-vested shares of restricted stock		211,868			220,783
Basic net loss per common share	$	(0.14	)	$	(0.16	)
DILUTED EPS:
Net loss attributed to common stockholders	$	(28,614	)	$	(34,417	)
Weighted average number of common shares outstanding, excluding    non-vested shares of restricted stock		211,868			220,783
Add dilutive effect of potential common shares		—			—
Weighted average number of diluted common shares outstanding		211,868			220,783
Diluted net loss per common share	$	(0.14	)	$	(0.16	)
Potentially dilutive securities excluded as anti-dilutive		10,033			9,738

15. Business Segments

At March 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.

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The following tables summarize selected financial information relating to the Company’s business segments (in thousands):

	Three Months Ended
	March 31,
	2019			2018
Revenues:
Contract drilling	$	372,743		$	328,153
Pressure pumping		247,601			406,784
Directional drilling		52,959			48,616
Other operations (1)		35,391			29,653
Elimination of intercompany revenues (2)		(4,523	)		(4,042	)
Total revenues	$	704,171		$	809,164
Income (loss) before income taxes:
Contract drilling	$	21,217		$	(17,103	)
Pressure pumping		(18,768	)		25,389
Directional drilling		(5,667	)		(4,913	)
Other operations		(5,204	)		(4,089	)
Corporate		(23,697	)		(23,807	)
Other operating income, net (3)		8,736			2,421
Interest income		1,032			1,423
Interest expense		(12,984	)		(13,625	)
Other		117			169
Loss before income taxes	$	(35,218	)	$	(34,135	)
Depreciation, depletion, amortization and impairment:
Contract drilling	$	130,317		$	130,917
Pressure pumping		60,135			56,522
Directional drilling		10,367			10,902
Other operations		11,788			9,314
Corporate		1,803			2,237
Total depreciation, depletion, amortization and impairment	$	214,410		$	209,892
Capital expenditures:
Contract drilling	$	75,725		$	75,247
Pressure pumping		31,400			24,923
Directional drilling		2,112			12,829
Other operations		7,773			9,396
Corporate		1,331			526
Total capital expenditures	$	118,341		$	122,921

	March 31,		December 31,
	2019		2018
Identifiable assets:
Contract drilling	$	3,725,627	$	3,817,638
Pressure pumping		894,357		921,237
Directional drilling		242,686		239,341
Other operations		179,584		177,374
Corporate (4)		325,498		314,276
Total assets	$	5,367,752	$	5,469,866

(1) Other operations includes the Company’s oilfield rentals business, pipe handling components and related technology business, the electrical controls and automation business, the oil and natural gas working interests and Middle East/North Africa 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.  

(4) Corporate assets primarily include cash on hand and certain property and equipment.

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16. Fair Values of Financial Instruments

The carrying values of cash and cash equivalents, trade receivables and accounts payable approximate fair value due to the short-term maturity of these items. These fair value estimates are considered Level 1 fair value estimates in the fair value hierarchy of fair value accounting.

The estimated fair value of the Company’s outstanding debt balances as of March 31, 2019 and December 31, 2018 is set forth below (in thousands):

	March 31, 2019				December 31, 2018
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value
3.95% Senior Notes	$	525,000	$	501,909	$	525,000	$	482,488
4.97% Series A Senior Notes		300,000		301,459		300,000		300,043
4.27% Series B Senior Notes		300,000		297,875		300,000		293,900
Total debt	$	1,125,000	$	1,101,243	$	1,125,000	$	1,076,431

The fair values of the 3.95% Senior Notes at March 31, 2019 and December 31, 2018 are based on discounted cash flows associated with the notes using the 4.65% market rate of interest at March 31, 2019 and the 5.07% market rate of interest at December 31, 2018.  The fair value estimates of the 3.95% 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 March 31, 2019 and 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 rates used in measuring this fair value were 4.63% at March 31, 2019 and 4.97% at December 31, 2018.  For the Series B Notes, the current market rates used in measuring this fair value were 4.51% at March 31, 2019 and 4.92% at December 31, 2018. These fair value estimates are based on observable market inputs and are considered Level 2 fair value estimates in the fair value hierarchy of fair value accounting.

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SPECIAL NOTE REGARDING FORWARD LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (this “Report”) and other public filings and press releases by us contain “forward-looking statements” within the meaning of the Securities Act of 1933, as amended (the “Securities Act”), the Securities Exchange Act of 1934, as amended (the “Exchange Act”), and the Private Securities Litigation Reform Act of 1995, as amended. As used in this Report, “the Company,” “us,” “we,” our” and like terms refer collectively to Patterson-UTI Energy, Inc. and its consolidated subsidiaries.  Patterson-UTI Energy, Inc. conducts its operations through its wholly-owned subsidiaries and has no employees or independent business operations.  These “forward-looking statements” involve risk and uncertainty. These forward-looking statements include, without limitation, statements relating to: liquidity; revenue and cost expectations and backlog; financing of operations; oil and natural gas prices; rig counts; source and sufficiency of funds required for building new equipment, upgrading existing equipment and additional acquisitions (if opportunities arise); impact of inflation; demand for our services; competition; equipment availability; government regulation; debt service obligations; and other matters. Our forward-looking statements can be identified by the fact that they do not relate strictly to historical or current facts and often use words such as “anticipate,” “believe,” “budgeted,” “continue,” “could,” “estimate,” “expect,” “intend,” “may,” “plan,” “predict,” “potential,” “project,” “pursue,” “should,” “strategy,” “target,” or “will,” or the negative thereof and other words and expressions of similar meaning. The forward-looking statements are based on certain assumptions and analyses we make in light of our experience and our perception of historical trends, current conditions, expected future developments and other factors we believe are appropriate in the circumstances.

Although we believe that the expectations reflected in such forward-looking statements are reasonable, we can give no assurance that such expectations will prove to have been correct. These forward-looking statements involve known and unknown risks, uncertainties and other factors that may cause our actual results, performance or achievements to be materially different from actual future results expressed or implied by the forward-looking statements.  These risks and uncertainties include, among others, risks and uncertainties relating to:

• adverse oil and natural gas industry conditions;

• global economic conditions;

• volatility in customer spending and in oil and natural gas prices that could adversely affect demand for our services and their associated effect on rates;

• excess availability of land drilling rigs, pressure pumping and directional drilling equipment, including as a result of reactivation, improvement or construction;

• competition and demand for our services;

• strength and financial resources of competitors;

• utilization, margins and planned capital expenditures;

• liabilities from operational risks for which we do not have and receive full indemnification or insurance;

• operating hazards attendant to the oil and natural gas business;

• failure by customers to pay or satisfy their contractual obligations (particularly with respect to fixed-term contracts);

• the ability to realize backlog;

• specialization of methods, equipment and services and new technologies;

• shortages, delays in delivery, and interruptions in supply, of equipment and materials;

• cybersecurity events;

• the ability to retain management and field personnel;

• loss of key customers;

• synergies, costs and financial and operating impacts of acquisitions;

• difficulty in building and deploying new equipment;

• governmental regulation;

• environmental risks and ability to satisfy future environmental costs;

• legal proceedings and actions by governmental or other regulatory agencies;

• technology-related disputes;

• the ability to effectively identify and enter new markets;

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• weather;

• operating costs;

• expansion and development trends of the oil and natural gas industry;

• ability to obtain insurance coverage on commercially reasonable terms;

• financial flexibility;

• interest rate volatility;

• adverse credit and equity market conditions;

• availability of capital and the ability to repay indebtedness when due;

• compliance with covenants under our debt agreements; and

• other financial, operational and legal risks and uncertainties detailed from time to time in our filings with the U.S. Securities and Exchange Commission (the “SEC”).

We caution that the foregoing list of factors is not exhaustive.  Additional information concerning these and other risk factors is contained in our Annual Report on Form 10-K for the year ended December 31, 2018 and may be contained in our future filings with the SEC. You are cautioned not to place undue reliance on any of our forward-looking statements. The forward-looking statements speak only as of the date made and, other than as required by law, we undertake no obligation to update publicly or revise any of these forward-looking statements, whether as a result of new information, future events or otherwise.  In the event that we update any forward-looking statement, no inference should be made that we will make additional updates with respect to that statement, related matters or any other forward-looking statements.  All subsequent written and oral forward-looking statements concerning us or other matters and attributable to us or any person acting on our behalf are expressly qualified in their entirety by the cautionary statements above.

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ITEM 2.  Management’s Discussion and Analysis of Financial Condition and Results of Operations

ManagementOverview— We are a Houston, Texas-based oilfield services company that primarily owns and operates one of the largest fleets of land-based drilling rigs in the United States and a large fleet of pressure pumping equipment.  Our contract drilling business operates in the continental United States and western Canada, and, from time to time, we pursue contract drilling opportunities outside of North America.  Our pressure pumping business operates primarily in Texas and the Mid-Continent and Appalachian regions.  We also provide a comprehensive suite of directional drilling services in most major producing onshore oil and gas basins in the United States, and we provide services that improve the statistical accuracy of horizontal wellbore placement.  We have other operations through which we provide oilfield rental tools in select markets in the United States. We also manufacture and sell pipe handling components and related technology to drilling contractors, and provide electrical controls and automation to the energy, marine and mining industries, in North America and other select markets.  In addition, we own and invest, as a non-operating working interest owner, in oil and natural gas assets that are primarily located in Texas and New Mexico.  

Oil prices have recovered from a 12-year low of $26.19 in February 2016 and reached a high of $77.41 in June 2018.  Oil prices remain volatile, as the closing price of oil reached a fourth quarter 2018 high of $76.40 per barrel on October 3, 2018, before declining by 42% over the course of three months to reach a low of $44.48 per barrel in late December 2018.  Oil prices averaged $54.83 per barrel in the first quarter of 2019, and closed at $65.66 per barrel on April 22, 2019.  Despite oil prices in the mid-$60s, drilling and pressure pumping activity has recently declined, largely as a result of reduced customer spending.

Our average active rig count for the first quarter of 2019 was 175 rigs, which included 174 rigs operating in the United States and one rig operating in Canada.  This was a decrease from our average active rig count for the fourth quarter of 2018 of 183, which included 182 rigs in the United States and one rig in Canada.  While oil prices have strengthened and operator cash flow expectations have improved, operators have remained fiscally conservative and rig demand levels remain subdued.  Based on term contracts (contracts with a duration of six months or more) currently in place, we expect an average of 104 rigs operating under term contracts during the second quarter of 2019 and an average of 59 rigs operating under term contracts during the twelve months ending March 31, 2020.

Our pressure pumping activity slowed in the first quarter.  We ended the first quarter with 16 active spreads compared to 20 at the end of the fourth quarter.  As we remain focused on reducing costs and improving cash flow, we took the proactive step of removing spreads from the market until we can redeploy them at attractive economics. 

Our revenues, profitability and cash flows are highly dependent upon prevailing prices for oil and natural gas. During periods of improved oil and natural gas prices, the capital spending budgets of oil and natural gas operators tend to expand, which generally results in increased demand for our services. Conversely, in periods when oil and natural gas prices deteriorate, the demand for our services generally weakens, and we experience downward pressure on pricing for our services.  

The North American oil and natural gas services industry is cyclical and, at times, experiences downturns in demand.  During these periods, there has been substantially more oil and natural gas service equipment available than necessary to meet demand.  As a result, oil and natural gas service contractors have had difficulty sustaining profit margins and, at times, have incurred losses during the downturn periods.  Currently, there is an excess supply of drilling rigs, pressure pumping equipment and directional drilling equipment. We cannot predict either the future level of demand for our oil and natural gas services or future conditions in the oil and natural gas service businesses.

We are also highly impacted by operational risks, competition, the availability of excess equipment, labor issues, weather, the availability of products used in our pressure pumping business, supplier delays and various other factors that could materially adversely affect our business, financial condition, cash flows and results of operations. Please see “Risk Factors” included in Item 1A of our Annual Report on Form 10-K for the fiscal year ended December 31, 2018.

For the three months ended March 31, 2019 and 2018, our operating revenues consisted of the following (dollars in thousands):

	Three Months Ended March 31,
	2019				2018
Contract drilling	$	372,392	52.9	%	$	327,803	40.5	%
Pressure pumping		247,601	35.2	%		406,784	50.3	%
Directional drilling		52,959	7.5	%		48,616	6.0	%
Other operations		31,219	4.4	%		25,961	3.2	%
	$	704,171	100.0	%	$	809,164	100.0	%

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Contract Drilling

Contract drilling revenues accounted for 52.9% of our consolidated first quarter 2019 revenues, and contract drilling revenues increased 13.6% over the comparable 2018 period.  

We have addressed our customers’ needs for drilling horizontal wells in shale and other unconventional resource plays by expanding our areas of operation and improving the capabilities of our drilling fleet during the last several years.  The U.S. land rig industry refers to certain high specification rigs as “super-spec” rigs.  We consider a super-spec rig to be at least a 1,500 horsepower, AC powered rig that has a 750,000 pound hookload, a 7,500 psi circulating system, and is pad capable.  As of March 31, 2019, our rig fleet included 198 APEX^® rigs, of which 150 were considered super-spec rigs.

We maintain a backlog of commitments for contract drilling services under term contracts, which we define as contracts with a duration of six months or more.  Our contract drilling backlog as of March 31, 2019 was approximately $650 million. Approximately 27% of the total March 31, 2019 backlog is reasonably expected to remain at March 31, 2020.  We generally calculate our backlog by multiplying the dayrate under our term drilling contracts by the number of days remaining under the contract.  The calculation does not include any revenues related to fees for other services such as for mobilization, other than initial mobilization, demobilization and customer reimbursables, nor does it include potential reductions in rates for unscheduled standby or during periods in which the rig is moving or incurring maintenance and repair time in excess of what is permitted under the drilling contract.  For contracts that contain variable dayrate pricing, our backlog calculation uses the dayrate in effect for periods where the dayrate is fixed, and, for periods that remain subject to variable pricing, uses the commodity price in effect at March 31, 2019.  In addition, our term drilling contracts are generally subject to termination by the customer on short notice and provide for an early termination payment to us in the event that the contract is terminated by the customer.  For contracts on which we have received an early termination notice, our backlog calculation includes the early termination rate, instead of the dayrate, for the period over which we expect to receive the lower rate.  

Ongoing factors which could continue to adversely affect utilization rates and pricing, even in an environment of high oil and natural gas prices and increased drilling activity, include:

• movement of drilling rigs from region to region,

• reactivation of drilling rigs,

• refurbishment and upgrades of existing drilling rigs,

• development of new technologies that enhance drilling efficiency, and 

• construction of new technology drilling rigs.

Pressure Pumping

Pressure pumping revenues accounted for 35.2% of our consolidated first quarter 2019 revenues and decreased 39.1% from the comparable 2018 period.  As of March 31, 2019, we had approximately 1.6 million horsepower in our pressure pumping fleet. The pressure pumping market showed signs of oversupply in the second half of 2018 and the first quarter of 2019.  In response to oversupplied market conditions, we reduced the number of active pressure pumping spreads to 16 by the end of the first quarter of 2019.

Directional Drilling

Directional drilling revenues accounted for 7.5% of our consolidated first quarter 2019 revenues and increased 8.9% over the comparable 2018 period.  We provide a comprehensive suite of directional drilling services in most major producing onshore oil and gas basins in the United States.  Our directional drilling services include directional drilling, downhole performance motors, measurement-while-drilling, and wireline steering tools, and we provide services that improve the statistical accuracy of horizontal wellbore placement.

Other Operations

Other operations revenues accounted for 4.4% of our consolidated first quarter 2019 revenues and increased 20.3% over the comparable 2018 period.  Our oilfield rentals business, with a fleet of premium oilfield rental tools, provides the largest revenue contribution to our other operations and provides specialized services for land-based oil and natural gas drilling, completion and workover activities.  Other operations also includes the results of our electrical controls and automation business, the results of our pipe handling components and related technology business, and the results of our ownership, as a non-operating working interest owner, in oil and natural gas assets that are primarily located in Texas and New Mexico.

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For the three months ended March 31, 2019 and 2018, our operating income (loss) consisted of the following (in thousands):

	Three Months Ended March 31,
	2019			2018
Contract drilling	$	21,217		$	(17,103	)
Pressure pumping		(18,768	)		25,389
Directional drilling		(5,667	)		(4,913	)
Other operations		(5,204	)		(4,089	)
Corporate		(14,961	)		(21,386	)
	$	(23,383	)	$	(22,102	)

Additional discussion of our operating revenues and operating income (loss) follows in the “Results of Operations” section.

Our consolidated net loss for the first quarter of 2019 was $28.6 million compared to a net loss of $34.4 million for the first quarter of 2018.  The improvement includes an increase in our income tax benefit in 2019.

Results of Operations

The following tables summarize results of operations by business segment for the three months ended March 31, 2019 and 2018:

Contract Drilling	2019		2018			% Change
	(dollars in thousands)
Revenues	$	372,392	$	327,803			13.6	%
Direct operating costs		219,202		212,583			3.1	%
Margin (1)		153,190		115,220			33.0	%
Selling, general and administrative		1,656		1,406			17.8	%
Depreciation, amortization and impairment		130,317		130,917			(0.5	)%
Operating income (loss)	$	21,217	$	(17,103	)	NA
Operating days (2)		15,787		15,218			3.7	%
Average revenue per operating day	$	23.59	$	21.54			9.5	%
Average direct operating costs per operating day	$	13.88	$	13.97			(0.6	)%
Average margin per operating day (1)	$	9.70	$	7.57			28.1	%
Average rigs operating		175		169			3.6	%
Capital expenditures	$	75,725	$	75,247			0.6	%

(1) Margin is defined as revenues less direct operating costs and excludes depreciation, amortization and impairment and selling, general and administrative expenses. Average margin per operating day is defined as margin divided by operating days.

(2) A rig is considered to be operating if it is earning revenue pursuant to a contract on a given day.

Generally, the revenues in our contract drilling segment are most impacted by two primary factors: our average number of rigs operating and our average revenue per operating day.  During the first quarter of 2019, our average number of rigs operating was 175, compared to 169 in the first quarter of 2018. Our average revenue per operating day is largely dependent on the pricing terms of our rig contracts.  

Revenues increased due to an increase in operating days and higher average revenue per operating day.  These increases were supported by our upgrade of additional rigs to super-spec capability.

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Pressure Pumping	2019			2018			% Change
	(dollars in thousands)
Revenues	$	247,601		$	406,784			(39.1	)%
Direct operating costs		202,748			320,970			(36.8	)%
Margin (1)		44,853			85,814			(47.7	)%
Selling, general and administrative		3,486			3,903			(10.7	)%
Depreciation, amortization and impairment		60,135			56,522			6.4	%
Operating income (loss)	$	(18,768	)	$	25,389		NA
Fracturing jobs		164			204			(19.6	)%
Other jobs		263			280			(6.1	)%
Total jobs		427			484			(11.8	)%
Average revenue per fracturing job	$	1,476.55		$	1,966.18			(24.9	)%
Average revenue per other job	$	20.71		$	20.30			2.0	%
Average revenue per total job	$	579.86		$	840.46			(31.0	)%
Average direct operating costs per total job	$	474.82		$	663.16			(28.4	)%
Average margin per total job (1)	$	105.04		$	177.30			(40.8	)%
Margin as a percentage of revenues (1)		18.1	%		21.1	%		(14.2	)%
Capital expenditures	$	31,400		$	24,923			26.0	%

(1) Margin is defined as revenues less direct operating costs and excludes depreciation, amortization and impairment and selling, general and administrative expenses. Average margin per total job is defined as margin divided by total jobs. Margin as a percentage of revenues is defined as margin divided by revenues.

Generally, the revenues in our pressure pumping segment are most impacted by our number of fracturing jobs and the size (including whether or not we provide proppant and other materials) of those jobs, which is reflected in our average revenue per fracturing job.  We completed 164 fracturing jobs during the first quarter of 2019 compared to 204 fracturing jobs in the first quarter of 2018.  Our average revenue per fracturing job was $1.477 million in the first quarter of 2019, compared to $1.966 million in the first quarter of 2018.  Our average revenue per fracturing job was impacted by lower demand, more customers self-sourcing products and decreases in product prices.

The increase in capital expenditures was primarily due to higher maintenance capital expenditures in the first quarter of 2019 primarily as a result of carryover costs from the fourth quarter of 2018 when activity levels were higher.

Directional Drilling	2019			2018			% Change
	(in thousands)
Revenues	$	52,959			48,616			8.9	%
Direct operating costs		45,602			37,689			21.0	%
Margin (1)		7,357			10,927			(32.7	)%
Selling, general and administrative		2,657			4,938			(46.2	)%
Depreciation and amortization		10,367			10,902			(4.9	)%
Operating loss	$	(5,667	)		(4,913	)		15.3	%
Capital expenditures	$	2,112			12,829			(83.5	)%

(1) Margin is defined as revenues less direct operating costs and excludes depreciation and amortization and selling, general and administrative expenses.

Directional drilling revenue increased by $4.3 million from the first quarter of 2018 due primarily to improved pricing for services, an increase in lost-in-hole revenue and revenue from Superior QC, which was acquired in the first quarter of 2018.  Directional drilling direct operating costs increased by $7.9 million from the first quarter of 2018 due primarily to increased repairs and maintenance expense and labor costs.

Selling, general and administrative expense decreased from the first quarter of 2018 primarily as a result of cost reduction efforts.

The decrease in capital expenditures was primarily due to higher capital expenditures in the first quarter of 2018 in response to market demand and needed equipment upgrades.

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Other Operations	2019			2018			% Change
	(in thousands)
Revenues	$	31,219		$	25,961			20.3	%
Direct operating costs		21,773			17,745			22.7	%
Margin (1)		9,446			8,216			15.0	%
Selling, general and administrative		2,862			2,991			(4.3	)%
Depreciation, depletion and impairment		11,788			9,314			26.6	%
Operating loss	$	(5,204	)	$	(4,089	)		27.3	%
Capital expenditures	$	7,773		$	9,396			(17.3	)%

(1) Margin is defined as revenues less direct operating costs and excludes depreciation, depletion and impairment and selling, general and administrative expenses.

Revenues, direct operating costs, and depreciation, depletion and impairment expense from other operations increased primarily as a result of an increase in the volume of services provided, and the acquisition of Current Power in the fourth quarter of 2018.

Corporate	2019			2018			% Change
	(in thousands)
Selling, general and administrative	$	21,894		$	19,579			11.8	%
Merger and integration expenses	$	-		$	1,991			(100.0	)%
Depreciation	$	1,803		$	2,237			(19.4	)%
Other operating income:
Net gain on asset disposals	$	(6,545	)	$	(10,410	)		(37.1	)%
Legal-related expenses and settlements, net of insurance reimbursements		(3,471	)		5,880		NA
Research and development		1,355			2,109			(35.8	)%
Other		(75	)		—		NA
Other operating loss	$	(8,736	)	$	(2,421	)		260.8	%
Interest income	$	1,032		$	1,423			(27.5	)%
Interest expense	$	12,984		$	13,625			(4.7	)%
Other income	$	117		$	169			(30.8	)%
Capital expenditures	$	1,331		$	526			153.0	%

Merger and integration expenses incurred in 2018 are related to the Seventy Seven Energy Inc. (“SSE”) merger and MS Directional, LLC (f/k/a Multi-Shot, LLC) acquisition. Other operating income includes net gains associated with the disposal of assets.  Accordingly, the related gains or losses have been excluded from the results of specific segments. The majority of the net gain on asset disposals during the first quarter of 2019 reflects gains on disposal of drilling equipment.  Legal-related expenses and settlements in 2019 includes proceeds from insurance claims. Legal-related expenses and settlements in 2018 includes insurance deductibles and investigation costs related to an accident at a drilling site in January 2018.  

Income Taxes

Our effective income tax rate fluctuates from the U.S. statutory tax rate based on, among other factors, changes in pretax income in jurisdictions with varying statutory tax rates, impact of U.S. state and local taxes, and other differences related to the recognition of income and expense between U.S. GAAP and tax.  

Our effective income tax rate for the three months ended March 31, 2019 was 18.8% compared with (0.8)% for the three months ended March 31, 2018. The lower effective income tax rate for the three months ended March 31, 2018 was primarily attributable to changes in forecasted annual pretax income in the first quarter of 2018 as compared to the forecasted annual pretax income in the first quarter of 2019.  We also recorded a valuation allowance against the net deferred tax assets of a Canadian subsidiary of the Company due to a change in judgment as to the realizability of these assets in the first quarter of 2018.

We continue to monitor income tax developments in the United States and other countries where we operate.  In December 2017, the United States enacted “H.R.1,” also known as the “Tax Cuts and Jobs Act” (or “U.S. Tax Reform”), which materially impacted our consolidated financial statements by decreasing the U.S. corporate statutory tax rate, and significantly affecting future periods.  We expect several proposed U.S. Treasury regulations under U.S. Tax Reform that were issued during 2018 to be finalized during 2019, as well as additional regulations to be proposed and finalized during 2019.  We will incorporate into our future financial statements the impacts, if any, of these regulations and additional authoritative guidance when finalized.

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Liquidity and Capital Resources

Our liquidity as of March 31, 2019 included approximately $417 million in working capital, including $249 million of cash and cash equivalents, and $600 million available under our revolving credit facility.  

On January 19, 2018, we completed an offering of $525 million aggregate principal amount of our 2028 Notes.  We used $239 million of the net proceeds from the offering to repay amounts outstanding under our revolving credit facility.  As described below, on March 27, 2018, we entered into an amended and restated credit agreement, which 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.

We believe our current liquidity, together with cash expected to be generated from operations, should provide us with sufficient ability to fund our current plans to maintain and make improvements to our existing equipment, service our debt and pay cash dividends for at least the next 12 months.  If we pursue opportunities for growth that require capital, we believe we would be able to satisfy these needs through a combination of working capital, cash flows from operating activities, borrowing capacity under our revolving credit facility or additional debt or equity financing.  However, there can be no assurance that such capital will be available on reasonable terms, if at all.

During the three months ended March 31, 2019, our sources of cash flow included:

• $184 million from operating activities, and

• $22.1 million in proceeds from the disposal of property and equipment and insurance proceeds.

During the three months ended March 31, 2019, we used $8.5 million to pay dividends on our common stock, $75.1 million for the repurchases of our common stock and $118 million:

• to make capital expenditures for the acquisition, betterment and refurbishment of drilling rigs and pressure pumping equipment,

• to acquire and procure equipment and facilities to support our drilling, pressure pumping, directional drilling, oilfield rentals and manufacturing operations, and

• to fund investments in oil and natural gas properties on a non-operating working interest basis.

We paid cash dividends during the three months ended March 31, 2019 as follows:

	Per Share		Total
			(in thousands)
Paid on March 21, 2019	$	0.04	$	8,499

On April 24, 2019, our Board of Directors approved a cash dividend on our common stock in the amount of $0.04 per share to be paid on June 20, 2019 to holders of record as of June 6, 2019.  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 our debt agreements and other factors.

On September 6, 2013, our Board of Directors approved a stock buyback program that authorized purchases of up to $200 million of our common stock in open market or privately negotiated transactions. On July 25, 2018, our Board of Directors approved an increase of the authorization under the stock buyback program to allow for $250 million of future share repurchases.  On February 6, 2019, the Company’s Board of Directors approved another increase of the authorization under the stock buyback program to allow for $250 million of share repurchases.  All purchases executed to date have been through open market transactions. Purchases under the program are made at management’s discretion, at prevailing prices, subject to market conditions and other factors. Purchases may be made at any time without prior notice. Shares of stock purchased under the buyback program are held as treasury shares. There is no expiration date associated with the buyback program. As of March 31, 2019, we had remaining authorization to purchase approximately $175 million of our outstanding common stock under the stock buyback program.

Treasury stock acquisitions during the three months ended March 31, 2019 were as follows (dollars in thousands):

	Shares		Cost
Treasury shares at beginning of period		53,701,096	$	1,080,448
Purchases pursuant to stock buyback program		5,408,132		75,110
Acquisitions pursuant to long-term incentive plan (1)		240		3
Treasury shares at end of period		59,109,468	$	1,155,561

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(1) We withheld 240 shares in the first three months of 2019 with respect to employees’ tax withholding obligations upon vesting of restricted shares and restricted stock units.  These shares were acquired at fair market value.  These acquisitions were made pursuant to the terms of the Patterson-UTI Energy, Inc. Amended and Restated 2014 Long-Term Incentive Plan and not pursuant to the stock buyback program.

Credit Agreement — On March 27, 2018, we entered into an amended and restated credit agreement (the “Credit Agreement”) among us, 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, we 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, we entered into Amendment No. 1 to Amended and Restated Credit Agreement (the “Amendment”), 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.  We have the option, subject to certain conditions, to exercise two one-year extensions of the maturity date.

Loans under the Credit Agreement bear interest by reference, at our 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 our credit rating.  A letter of credit fee is payable by us 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 our credit rating.

None of our subsidiaries 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 we believe are customary for agreements of this nature, including certain restrictions on our ability and each of our subsidiaries to incur debt and grant liens.  If our credit rating is below investment grade, we will become subject to a restricted payment covenant, which would require us 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 our 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 March 31, 2019, we had no amounts outstanding under our revolving credit facility.  We had $81,000 in letters of credit outstanding under our revolving credit facility at March 31, 2019 and, as a result, had available borrowing capacity of approximately $600 million at that date.  

2015 Reimbursement Agreement — On March 16, 2015, we entered into a Reimbursement Agreement (the “Reimbursement Agreement”) with The Bank of Nova Scotia (“Scotiabank”), pursuant to which we may from time to time request that Scotiabank issue an unspecified amount of letters of credit.  As of March 31, 2019, we had $51.4 million in letters of credit outstanding under the Reimbursement Agreement.

Under the terms of the Reimbursement Agreement, we 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 us at the time of issuance at such rates and amounts as are in accordance with Scotiabank’s prevailing practice.  We are obligated to pay to Scotiabank interest on all amounts not paid 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.

We have also agreed that if obligations under the Credit Agreement are secured by liens on any of our subsidiaries’ property, then our 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.

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Pursuant to a Continuing Guaranty dated as of March 16, 2015 (the “Continuing Guaranty”), our payment obligations under the Reimbursement Agreement are jointly and severally guaranteed as to payment and not as to collection by our subsidiariesthat from time to time guarantee payment under the Credit Agreement. None of our subsidiaries are currently required to guarantee payment under the Credit Agreement. 

Series A & B Senior Notes —On October 5, 2010, we completed the issuance and sale of $300 million in aggregate principal amount of our 4.97% Series A Senior Notes due October 5, 2020 (the “Series A Notes”) in a private placement. The Series A Notes bear interest at a rate of 4.97% per annum. We pay interest on the Series A Notes on April 5 and October 5 of each year. The Series A Notes will mature on October 5, 2020.

On June 14, 2012, we completed the issuance and sale of $300 million in aggregate principal amount of our 4.27% Series B Senior Notes due June 14, 2022 (the “Series B Notes”) in a private placement. The Series B Notes bear interest at a rate of 4.27% per annum. We pay interest on the Series B Notes on April 5 and October 5 of each year. The Series B Notes will mature on June 14, 2022.

The Series A Notes and Series B Notes are senior unsecured obligations which rank equally in right of payment with all of our other unsubordinated indebtedness. The Series A Notes and Series B Notes are guaranteed on a senior unsecured basis by each of our domestic subsidiaries other than subsidiaries that are not required to be guarantors under the Credit Agreement. None of our subsidiaries are currently required to be a guarantor under the Credit Agreement. 

The Series A Notes and Series B Notes are prepayable at our option, in whole or in part, provided that in the case of a partial prepayment, prepayment must be in an amount not less than 5% of the aggregate principal amount of the notes then outstanding, at any time and from time to time at 100% of the principal amount prepaid, plus accrued and unpaid interest to the prepayment date, plus a “make-whole” premium as specified in the note purchase agreements. We must offer to prepay the notes upon the occurrence of any change of control. In addition, we must offer to prepay the notes upon the occurrence of certain asset dispositions if the proceeds therefrom are not timely reinvested in productive assets. If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.

The respective note purchase agreements require compliance with two financial covenants. We must not permit our debt to capitalization ratio to exceed 50% at any time. The note purchase agreements generally define the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. We also must not permit our interest coverage ratio as of the last day of a fiscal quarter to be less than 2.50 to 1.00. The note purchase agreements generally define the interest coverage ratio as the ratio of EBITDA for the four prior fiscal quarters to interest charges for the same period. We were in compliance with these covenants at March 31, 2019. We do not expect that the restrictions and covenants will impair, in any material respect, our ability to operate or react to opportunities that might arise.

Events of default under the note purchase agreements include failure to pay principal or interest when due, failure to comply with the financial and operational covenants, a cross default event, a judgment in excess of a threshold event, the guaranty agreement ceasing to be enforceable, the occurrence of certain ERISA events, a change of control event and bankruptcy and other insolvency events. If an event of default under the note purchase agreements occurs and is continuing, then holders of a majority in principal amount of the respective notes have the right to declare all the notes then-outstanding to be immediately due and payable. In addition, if we default in payments on any note, then until such defaults are cured, the holder thereof may declare all the notes held by it pursuant to the note purchase agreement to be immediately due and payable.

2028 Senior Notes —On January 19, 2018, we completed an offering of $525 million aggregate principal amount of our 2028 Notes.  The net proceeds before offering expenses were approximately $521 million, of which we used $239 million to repay amounts outstanding under our revolving credit facility. 

We pay interest on the 2028 Notes on February 1 and August 1 of each year.  The 2028 Notes will mature on February 1, 2028.  The 2028 Notes bear interest at a rate of 3.95% per annum.

The 2028 Notes are senior unsecured obligations, which rank equally with all of our other existing and future senior unsecured debt and will rank senior in right of payment to all of our other future subordinated debt.  The 2028 Notes will be effectively subordinated to any of our future secured debt to the extent of the value of the assets securing such debt.  In addition, the 2028 Notes will be structurally subordinated to the liabilities (including trade payables) of our subsidiaries that do not guarantee the 2028 Notes.  None of our subsidiaries are currently required to be a guarantor under the 2028 Notes.  If our subsidiaries guarantee the 2028 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.

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We, at our option, may redeem the 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 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028Notes to the redemption date, plus a make-whole premium.  Additionally, commencing on November 1, 2027, we, at our option, may redeem the 2028Notes in whole or in part, at a redemption price equal to 100% of the principal amount of the 2028Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date.

The indenture pursuant to which the 2028 Notes were issued includes covenants that, among other things, limit our and our subsidiaries’ ability to incur certain liens, engage in sale and lease-back transactions or consolidate, merge, or transfer all or substantially all of their assets.  These covenants are subject to important qualifications and limitations set forth in the indenture.

Upon the occurrence of a change of control, as defined in the indenture, each holder of the 2028 Notes may require us to purchase all or a portion of such holder’s 2028 Notes at a price equal to 101% of their principal amount, plus accrued and unpaid interest, if any, to, but excluding, the repurchase date.

The indenture also provides for events of default which, if any of them occurs, would permit or require the principal of, premium, if any, and accrued interest, if any, on the 2028 Notes to become or to be declared due and payable.

Commitments— As of March 31, 2019, we maintained letters of credit in the aggregate amount of $51.4 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 March 31, 2019, no amounts had been drawn under the letters of credit.

As of March 31, 2019, we had commitments to purchase major equipment and make investments totaling approximately $89.9 million for our drilling, pressure pumping, directional drilling and oilfield rentals businesses.

Our pressure pumping business has entered into agreements to purchase minimum quantities of proppants and chemicals from certain vendors. The agreements expire in years 2019 through 2023. As of March 31, 2019, the remaining obligation under these agreements was approximately $50 million, of which approximately $22.3 million relates to purchases required during the remainder of 2019. In the event the required minimum quantities are not purchased during any contract year, we could be required to make a liquidated damages payment to the respective vendor for any shortfall.

Trading and Investing — We have not engaged in trading activities that include high-risk securities, such as derivatives and non-exchange traded contracts. We invest cash primarily in highly liquid, short-term investments such as overnight deposits and money market accounts.

Adjusted EBITDA

Adjusted earnings before interest, taxes, depreciation and amortization (“Adjusted EBITDA”) is not defined by accounting principles generally accepted in the United States of America (“U.S. GAAP”).  We define Adjusted EBITDA as net income (loss) plus net interest expense, income tax expense (benefit) and depreciation, depletion, amortization and impairment expense (including impairment of goodwill).  We present Adjusted EBITDA because we believe it provides to both management and investors additional information with respect to the performance of our fundamental business activities and a comparison of the results of our operations from period to period and against our peers without regard to our financing methods or capital structure.  We exclude the items listed above from net income (loss) in arriving at Adjusted EBITDA because these amounts can vary substantially from company to company within our industry depending upon accounting methods and book values of assets, capital structures and the method by which the assets were acquired.  Adjusted EBITDA should not be construed as an alternative to the U.S. GAAP measure of net income (loss).  Our computations of Adjusted EBITDA may not be the same as other similarly titled measures of other companies.  Set forth below is a reconciliation of the non-U.S. GAAP financial measure of Adjusted EBITDA to the U.S. GAAP financial measure of net income (loss).

	Three Months Ended
	March 31,
	2019			2018
	(in thousands)
Net loss	$	(28,614	)	$	(34,417	)
Income tax expense (benefit)		(6,604	)		282
Net interest expense		11,952			12,202
Depreciation, depletion, amortization and impairment		214,410			209,892
Adjusted EBITDA	$	191,144		$	187,959

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Critical Accounting Policies

In February 2016, the FASB issued an accounting standard update to provide guidance for the accounting for leasing transactions. The standard requires the lessee to recognize a lease liability along with a right-of-use asset for all leases with a term longer than one year.  A lessee is permitted to make an accounting policy election by class of underlying asset to not recognize the lease liability and related right-of-use asset for leases with a term of one year or less.  We adopted this new leasing guidance effective January 1, 2019 utilizing the modified retrospective approach.  Please see Note 4 to our unaudited condensed consolidated financial statements for additional details of our adoption.

In addition to established accounting policies, our condensed consolidated financial statements are impacted by certain estimates and assumptions made by management.

Recently Issued Accounting Standards

Please see Note 1 to our unaudited condensed consolidated financial statements for a discussion of recently issued accounting standards.

Volatility of Oil and Natural Gas Prices and its Impact on Operations and Financial Condition

Our revenue, profitability and cash flows are highly dependent upon prevailing prices for oil and natural gas and expectations about future prices.  For many years, oil and natural gas prices and markets have been extremely volatile.  Prices are affected by many factors beyond our control.  The closing price of oil was as high as $107.95 per barrel of WTI in June 2014.  Prices began to fall in the third quarter of 2014 and reached a twelve-year low of $26.19 in February 2016.  Oil prices have recovered from the lows experienced in the first quarter of 2016. Oil prices reached a high of $77.41 in June 2018.  Oil prices remain volatile, as the closing price of oil reached a fourth quarter 2018 high of $76.40 per barrel on October 3, 2018, before declining by 42% over the course of three months to reach a low of $44.48 per barrel in late December 2018. Oil prices averaged $54.83 per barrel in the first quarter of 2019 and closed at $65.66 on April 22, 2019.  U.S. rig counts increased in response to improved oil prices in early 2018. Despite oil prices in the mid-$60s, drilling and pressure pumping activity has recently declined, largely as a result of reduced customer spending.  

We expect oil and natural gas prices to continue to be volatile and to affect our financial condition, operations and ability to access sources of capital.  Higher oil and natural gas prices do not necessarily result in increased activity because demand for our services is generally driven by our customers’ expectations of future oil and natural gas prices.  A decline in demand for oil and natural gas, prolonged low oil or natural gas prices or expectations of decreases in oil and natural gas prices, would likely result in reduced capital expenditures by our customers and decreased demand for our services, which could have a material adverse effect on our operating results, financial condition and cash flows.  Even during periods of high prices for oil and natural gas, companies exploring for oil and natural gas may cancel or curtail programs, or reduce their levels of capital expenditures for exploration and production for a variety of reasons, which could reduce demand for our services.  

ITEM 3.  Quantitative and Qualitative Disclosures About Market Risk

As of March 31, 2019, we would have had exposure to interest rate market risk associated with any borrowings that we had under the Credit Agreement and the Reimbursement Agreement.

Loans under the Credit Agreement bear interest by reference, at our 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 on our credit rating. As of March 31, 2019, the applicable margin on LIBOR rate loans was 1.5% and the applicable margin on base rate loans was 0.5%.  As of March 31, 2019, we had no amounts outstanding under our revolving credit facility. The interest rate on borrowings outstanding under our revolving credit facility is variable and adjusts at each interest payment date based on our election of LIBOR or the base rate.

Under the Reimbursement Agreement, we will reimburse Scotiabank on demand for any amounts that Scotiabank has disbursed under any letters of credit.  We are obligated to pay Scotiabank interest on all amounts not paid by us on the date of demand or when otherwise due at the LIBOR rate plus 2.25% per annum.  As of March 31, 2019, no amounts had been disbursed under any letters of credit.

We conduct a portion of our business in Canadian dollars. The exchange rate between Canadian dollars and U.S. dollars has fluctuated during the last several years. If the value of the Canadian dollar against the U.S. dollar weakens, revenues and earnings of our Canadian operations will be reduced and the value of our Canadian net assets will decline when they are translated to U.S. dollars. This currency risk is not material to our financial condition or results of operations.

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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.

ITEM 4. Controls and Procedures

Disclosure Controls and Procedures — We maintain disclosure controls and procedures (as such terms are defined in Rules 13a-15(e) and 15d-15(e) promulgated under the Exchange Act), designed to ensure that the information required to be disclosed in the reports that we file with the SEC under the Exchange Act is recorded, processed, summarized and reported within the time periods specified in the SEC’s rules and forms, and that such information is accumulated and communicated to our management, including our Chief Executive Officer (“CEO”) and Chief Financial Officer (“CFO”), as appropriate, to allow timely decisions regarding required disclosure.

Under the supervision and with the participation of our management, including our CEO and CFO, we conducted an evaluation of the effectiveness of our disclosure controls and procedures as of the end of the period covered by this Quarterly Report on Form 10‑Q. Based on that evaluation, our CEO and CFO concluded that our disclosure controls and procedures were effective as of March 31, 2019.

Changes in Internal Control Over Financial Reporting —There were no changes in our internal control over financial reporting during our most recently completed fiscal quarter that have materially affected, or are reasonably likely to materially affect, our internal control over financial reporting, as defined in Rule 13a-15(f) under the Exchange Act.

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PART II — OTHER INFORMATION

ITEM 1. Legal Proceedings

On January 22, 2018, an accident at a drilling site in Pittsburg County, Oklahoma resulted in the losses of life of five people, including three of our employees. The EPA, OSHA and the CSB initiated investigations related to this accident.  The EPA and the CSB investigations are ongoing, and we are cooperating with the agencies regarding these investigations.

On July 18, 2018, OSHA issued a citation containing alleged violations, proposed abatement dates and an aggregate proposed penalty of approximately $74,000. We have filed a notice of contest with OSHA that contests all citation items, abatement dates and proposed penalties.  The Department of Labor filed a complaint on OSHA’s behalf seeking enforcement of the citation as issued.  We have filed an answer to the complaint and are litigating our contest of the citation items.  The ultimate resolution of the OSHA citation items is not known at this time, and we are unable to determine what alleged violations and proposed penalties will be modified or eliminated, if any.

Lawsuits have been filed in the District Court for Pittsburg County, Oklahoma in connection with the five individuals who lost their lives and one of our employees who was injured in the accident.  The lawsuits have been consolidated for discovery purposes under Cause No. CJ-2018-60 (the “Litigation”).  These lawsuits allege various causes of action against us including negligence, gross negligence, knowledge that injury or death was substantially certain, acting with purpose, recklessness, wrongful death and survival, and the plaintiffs seek an unspecified amount of damages, including punitive or exemplary damages, costs, interest, and other relief. We have finalized settlement agreements with four of the plaintiffs who brought wrongful death lawsuits. We dispute the plaintiffs’ allegations against us in the remaining lawsuits and intend to continue to defend ourselves vigorously.  Based on the information we have available as of the date of this Report, we believe that we have adequate insurance to cover the Litigation. However, if this accident is not fully covered by insurance or an enforceable and recoverable indemnity from a third party, it could have a material adverse effect on our business, financial condition, cash flows and results of operations.

Additionally, we are party to various legal proceedings arising in the normal course of our business.  

We do not believe that the outcome of these proceedings, either individually or in the aggregate, will have a material adverse effect on our financial condition, cash flows and results of operations.

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ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds

The table below sets forth the information with respect to purchases of our common stock made by us during the quarter ended March 31, 2019.

							Approximate Dollar
					Total Number of		Value of Shares
					Shares (or Units)		That May Yet Be
					Purchased as Part		Purchased Under the
	Total		Average Price		of Publicly		Plans or
	Number of Shares		Paid per		Announced Plans		Programs (in
Period Covered	Purchased (1)		Share		or Programs		thousands)(2)
January 2019		240	$	12.72		—	$	150,263
February 2019		1,175,000	$	14.01		1,175,000	$	233,534
March 2019		4,233,132	$	13.85		4,233,132	$	174,890
Total		5,408,372				5,408,132	$	174,890

(1) We withheld 240 shares in January 2019 with respect to employees’ tax withholding obligations upon vesting of restricted shares and restricted stock units.  These shares were acquired at fair market value pursuant to the terms of the Patterson-UTI Energy, Inc. Amended and Restated 2014 Long-Term Incentive Plan and not pursuant to the stock buyback program.

(2) On September 9, 2013, we announced that our Board of Directors approved a stock buyback program authorizing purchases of up to $200 million of our common stock in open market or privately negotiated transactions. On July 26, 2018, we announced that our Board of Directors approved an increase of the authorization under the stock buyback program to allow for $250 million of future share repurchases.  On February 6, 2019, the Company’s Board of Directors approved another increase of the authorization under the stock buyback program to allow for $250 million of share repurchases.  All purchases executed to date have been through open market transactions.  Purchases under the program are made at management’s discretion, at prevailing prices, subject to market conditions and other factors.  Purchases may be made at any time without prior notice.  Shares of stock purchased under the buyback program are held as treasury shares.  There is no expiration date associated with the buyback program.  

37

ITEM 6. Exhibits

The following exhibits are filed herewith or incorporated by reference, as indicated:

3.1	Restated Certificate of Incorporation, as amended (filed August 9, 2004 as Exhibit 3.1 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2004 and incorporated herein by reference).
3.2	Certificate of Amendment to Restated Certificate of Incorporation, as amended (filed August 9, 2004 as Exhibit 3.2 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2004 and incorporated herein by reference).
3.3	Certificate of Elimination with respect to Series A Participating Preferred Stock (filed October 27, 2011 as Exhibit 3.1 to the Company’s Current Report on Form 8-K and incorporated herein by reference).
3.4	Certificate of Amendment to Restated Certificate of Incorporation, as amended (filed July 30, 2018 as Exhibit 3.4 to the Company’s Quarterly Report on Form 10-Q for the quarterly period ended June 30, 2018 and incorporated herein by reference).
3.5	Fourth Amended and Restated Bylaws of Patterson-UTI Energy, Inc., effective February 6, 2019 (filed February 12, 2019 as Exhibit 3.1 to the Company’s Current Report on Form 8-K and incorporated herein by reference).
10.1	Amendment No. 1 to Amended and Restated Credit Agreement, dated March 26, 2019, among Patterson-UTI Energy, Inc., as borrower, Wells Fargo Bank, National Association, as administrative agent, letter of credit issuer, swing line lender and lender and each of the other letter of credit issuers and lenders party thereto (filed March 26, 2019 as Exhibit 10.1 to the Company’s Current Report on Form 8-K and incorporated herein by reference).
31.1*	Certification of Chief Executive Officer pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended.
31.2*	Certification of Chief Financial Officer pursuant to Rule 13a-14(a)/15d-14(a) of the Securities Exchange Act of 1934, as amended.
32.1*	Certification of Chief Executive Officer and Chief Financial Officer pursuant to 18 USC Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002.
101*	The following materials from Patterson-UTI Energy, Inc.’s Quarterly Report on Form 10-Q for the quarter ended March 31, 2019, formatted in XBRL (Extensible Business Reporting Language): (i) the Condensed Consolidated Balance Sheets, (ii) the Condensed Consolidated Statements of Operations, (iii) the Condensed Consolidated Statements of Comprehensive Loss, (iv) the Condensed Consolidated Statements of Changes in Stockholders’ Equity, (v) the Condensed Consolidated Statements of Cash Flows, and (vi) Notes to Condensed Consolidated Financial Statements.

* filed herewith

38

SIGNATURE

Pursuant to the requirements of the Securities Exchange Act of 1934, the registrant has duly caused this report to be signed on its behalf by the undersigned thereunto duly authorized.

PATTERSON-UTI ENERGY, INC.
By:	/s/ C. Andrew Smith
	C. Andrew Smith
	Executive Vice President and
	Chief Financial Officer
	(Principal Financial and Accounting Officer and Duly Authorized Officer)

Date: April 29, 2019

39

EX-31.1

EXHIBIT 31.1

CERTIFICATIONS

I, William Andrew Hendricks, Jr., certify that:

1. I have reviewed this quarterly report on Form 10-Q of Patterson-UTI Energy, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/ William Andrew Hendricks, Jr.

William Andrew Hendricks, Jr.

President and Chief Executive Officer

Date: April 29, 2019

EX-31.2

EXHIBIT 31.2

CERTIFICATIONS

I, C. Andrew Smith, certify that:

1. I have reviewed this quarterly report on Form 10-Q of Patterson-UTI Energy, Inc.;

2. Based on my knowledge, this report does not contain any untrue statement of a material fact or omit to state a material fact necessary to make the statements made, in light of the circumstances under which such statements were made, not misleading with respect to the period covered by this report;

3. Based on my knowledge, the financial statements, and other financial information included in this report, fairly present in all material respects the financial condition, results of operations and cash flows of the registrant as of, and for, the periods presented in this report;

4. The registrant’s other certifying officer(s) and I are responsible for establishing and maintaining disclosure controls and procedures (as defined in Exchange Act Rules 13a-15(e) and 15d-15(e)) and internal control over financial reporting (as defined in Exchange Act Rules 13a-15(f) and 15d-15(f)) for the registrant and have:

(a) Designed such disclosure controls and procedures, or caused such disclosure controls and procedures to be designed under our supervision, to ensure that material information relating to the registrant, including its consolidated subsidiaries, is made known to us by others within those entities, particularly during the period in which this report is being prepared;

(b) Designed such internal control over financial reporting, or caused such internal control over financial reporting to be designed under our supervision, to provide reasonable assurance regarding the reliability of financial reporting and the preparation of financial statements for external purposes in accordance with generally accepted accounting principles;

(c) Evaluated the effectiveness of the registrant’s disclosure controls and procedures and presented in this report our conclusions about the effectiveness of the disclosure controls and procedures, as of the end of the period covered by this report based on such evaluation; and

(d) Disclosed in this report any change in the registrant’s internal control over financial reporting that occurred during the registrant’s most recent fiscal quarter (the registrant’s fourth fiscal quarter in the case of an annual report) that has materially affected, or is reasonably likely to materially affect, the registrant’s internal control over financial reporting; and

5. The registrant’s other certifying officer(s) and I have disclosed, based on our most recent evaluation of internal control over financial reporting, to the registrant’s auditors and the audit committee of the registrant’s board of directors (or persons performing the equivalent functions):

(a) All significant deficiencies and material weaknesses in the design or operation of internal control over financial reporting which are reasonably likely to adversely affect the registrant’s ability to record, process, summarize and report financial information; and

(b) Any fraud, whether or not material, that involves management or other employees who have a significant role in the registrant’s internal control over financial reporting.

/s/ C. Andrew Smith

C. Andrew Smith

Executive Vice President and

Chief Financial Officer

Date: April 29, 2019

EX-32.1

EXHIBIT 32.1

CERTIFICATION PURSUANT TO

18 U.S.C. SECTION 1350,

AS ADOPTED PURSUANT TO

SECTION 906 OF THE SARBANES-OXLEY ACT OF 2002

NOT FILED PURSUANT TO THE SECURITIES EXCHANGE ACT OF 1934

In connection with the quarterly report of Patterson-UTI Energy, Inc. (the “Company”) on Form 10-Q for the period ended March 31, 2019, as filed with the Securities and Exchange Commission on the date hereof (the “Report”), William Andrew Hendricks, Jr., Chief Executive Officer, and C. Andrew Smith, Chief Financial Officer, of the Company, each certify, pursuant to 18 U.S.C. Section 1350, as adopted pursuant to Section 906 of the Sarbanes-Oxley Act of 2002, that, to his knowledge:

(1) The Report fully complies with the requirements of section 13(a) or 15(d) of the Securities Exchange Act of 1934; and

(2) The information contained in the Report fairly presents, in all material respects, the financial condition and results of operations of the Company.

A signed original of this written statement required by Section 906 has been provided to the Company and will be retained by the Company and furnished to the Securities and Exchange Commission upon request. The foregoing is being furnished solely pursuant to said Section 906 and Rule 13a-14(b) promulgated under the Securities Exchange Act of 1934, as amended, and is not being filed as part of the Report or as a separate disclosure document.

/s/ William Andrew Hendricks, Jr.

William Andrew Hendricks, Jr.

Chief Executive Officer

April 29, 2019

/s/ C. Andrew Smith

C. Andrew Smith

Chief Financial Officer

April 29, 2019

XML

Document and Entity Information - shares	3 Months Ended
	Mar. 31, 2019	Apr. 25, 2019
Document And Entity Information [Abstract]
Document Type	10-Q
Amendment Flag	false
Document Period End Date	Mar. 31, 2019
Document Fiscal Year Focus	2019
Document Fiscal Period Focus	Q1
Trading Symbol	PTEN
Entity Registrant Name	PATTERSON UTI ENERGY INC
Entity Central Index Key	0000889900
Current Fiscal Year End Date	--12-31
Entity Filer Category	Large Accelerated Filer
Entity Small Business	false
Entity Emerging Growth Company	false
Entity Common Stock, Shares Outstanding		208,542,994

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Current assets:
Cash and cash equivalents	$ 248,901	$ 245,029
Accounts receivable, net of allowance for doubtful accounts of $2,307 and $2,312 at March 31, 2019 and December 31, 2018, respectively	547,993	558,817
Federal and state income taxes receivable	4,083	4,110
Inventory	65,871	65,579
Other	60,883	76,662
Total current assets	927,731	950,197
Property and equipment, net	3,898,518	4,002,549
Right of use asset	28,405
Goodwill and intangible assets	476,078	477,640
Deposits on equipment purchases	10,505	12,040
Other	26,515	27,440
Total assets	5,367,752	5,469,866
Current liabilities:
Accounts payable	260,378	288,962
Federal and state income taxes payable	1,367	1,408
Accrued expenses	240,196	235,946
Lease liability	9,217
Total current liabilities	511,158	526,316
Long-term lease liability	23,903
Long-term debt, net of debt discount and issuance costs of $5,574 and $5,795 at March 31, 2019 and December 31, 2018, respectively	1,119,426	1,119,205
Deferred tax liabilities, net	299,557	306,161
Other	10,339	12,761
Total liabilities	1,964,383	1,964,443
Commitments and contingencies (see Note 10)
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 267,353,108 and 267,315,526 issued and 208,243,640 and 213,614,430 outstanding at March 31, 2019 and December 31, 2018, respectively	2,673	2,673
Additional paid-in capital	2,836,492	2,827,154
Retained earnings	1,716,334	1,753,557
Accumulated other comprehensive income	3,431	2,487
Treasury stock, at cost, 59,109,468 and 53,701,096 shares at March 31, 2019 and December 31, 2018, respectively	(1,155,561)	(1,080,448)
Total stockholders' equity	3,403,369	3,505,423
Total liabilities and stockholders' equity	$ 5,367,752	$ 5,469,866

XML

CONDENSED CONSOLIDATED BALANCE SHEETS (Parenthetical) (Unaudited) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Statement Of Financial Position [Abstract]
Accounts receivable, allowance for doubtful accounts	$ 2,307	$ 2,312
Long-term debt, debt discount and issuance costs	$ 5,574	$ 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	267,353,108	267,315,526
Common stock, outstanding	208,243,640	213,614,430
Treasury stock, shares	59,109,468	53,701,096

XML

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS (Unaudited) - USD ($) shares in Thousands, $ in Thousands		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Operating revenues:
Total operating revenues		$ 704,171	$ 809,164
Operating costs and expenses:
Depreciation, depletion, amortization and impairment		214,410	209,892
Selling, general and administrative		32,555	32,817
Merger and integration expenses			1,991
Other operating income, net	[1]	(8,736)	(2,421)
Total operating costs and expenses		727,554	831,266
Operating loss		(23,383)	(22,102)
Other income (expense):
Interest income		1,032	1,423
Interest expense, net of amount capitalized		(12,984)	(13,625)
Other		117	169
Total other expense		(11,835)	(12,033)
Loss before income taxes		(35,218)	(34,135)
Income tax expense (benefit)		(6,604)	282
Net loss		$ (28,614)	$ (34,417)
Net loss per common share:
Basic		$ (0.14)	$ (0.16)
Diluted		$ (0.14)	$ (0.16)
Weighted average number of common shares outstanding:
Basic		211,868	220,783
Diluted		211,868	220,783
Cash dividends per common share		$ 0.04	$ 0.02
Contract Drilling
Operating revenues:
Total operating revenues		$ 372,392	$ 327,803
Operating costs and expenses:
Operating costs and expenses		219,202	212,583
Pressure Pumping
Operating revenues:
Total operating revenues		247,601	406,784
Operating costs and expenses:
Operating costs and expenses		202,748	320,970
Directional Drilling
Operating revenues:
Total operating revenues		52,959	48,616
Operating costs and expenses:
Operating costs and expenses		45,602	37,689
Other
Operating revenues:
Total operating revenues		31,219	25,961
Operating costs and expenses:
Operating costs and expenses		$ 21,773	$ 17,745

[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.

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement Of Income And Comprehensive Income [Abstract]
Net loss	$ (28,614)	$ (34,417)
Other comprehensive income (loss), net of taxes of $0 for all periods:
Foreign currency translation adjustment	944	(1,984)
Total comprehensive loss	$ (27,670)	$ (36,401)

XML

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE LOSS (Parenthetical) (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement Of Income And Comprehensive Income [Abstract]
Other comprehensive income (loss), taxes	$ 0	$ 0

XML

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS' EQUITY (Unaudited) - USD ($) $ in Thousands	Total	Common Stock	Additional Paid-in Capital	Retained Earnings	Accumulated Other Comprehensive Income (Loss)	Treasury Stock
Beginning Balance at Dec. 31, 2017	$ 3,982,493	$ 2,662	$ 2,785,823	$ 2,105,897	$ 6,822	$ (918,711)
Beginning Balance (in shares) at Dec. 31, 2017		266,259,000
Net loss	(34,417)			(34,417)
Foreign currency translation adjustment	(1,984)				(1,984)
Exercise of stock options	485	$ 1	484
Exercise of stock options (in shares)		40,000
Stock-based compensation	9,365		9,365
Payment of cash dividends	(4,443)			(4,443)
Dividend equivalents	(30)			(30)
Purchase of treasury stock	(16,928)					(16,928)
Ending Balance at Mar. 31, 2018	3,934,541	$ 2,663	2,795,672	2,067,007	4,838	(935,639)
Ending Balance (in shares) at Mar. 31, 2018		266,299,000
Beginning Balance at Dec. 31, 2017	3,982,493	$ 2,662	2,785,823	2,105,897	6,822	(918,711)
Beginning Balance (in shares) at Dec. 31, 2017		266,259,000
Payment of cash dividends	(30,589)
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 loss	$ (28,614)			(28,614)
Foreign currency translation adjustment	$ 944				944
Exercise of stock options (in shares)	0
Vesting of restricted stock units (in shares)		38,000
Forfeitures of restricted stock (in shares)		(1,000)
Stock-based compensation	$ 9,338		9,338
Payment of cash dividends	(8,499)			(8,499)
Dividend equivalents	(110)			(110)
Purchase of treasury stock	(75,113)					(75,113)
Ending Balance at Mar. 31, 2019	$ 3,403,369	$ 2,673	$ 2,836,492	$ 1,716,334	$ 3,431	$ (1,155,561)
Ending Balance (in shares) at Mar. 31, 2019	267,353,108	267,353,000

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Cash flows from operating activities:
Net loss	$ (28,614)	$ (34,417)
Adjustments to reconcile net loss to net cash provided by operating activities:
Depreciation, depletion, amortization and impairment	214,410	209,892
Dry holes and abandonments	21	96
Deferred income tax expense (benefit)	(6,604)	282
Stock-based compensation expense	9,338	9,365
Net gain on asset disposals	(6,545)	(10,410)
Amortization of debt discount and issuance costs	221	170
Changes in operating assets and liabilities:
Accounts receivable	10,929	(16,468)
Income taxes receivable/payable	(14)	19
Inventory and other assets	6,592	2,709
Accounts payable	(17,858)	(22,514)
Accrued expenses	2,871	11,174
Other liabilities	(915)	67
Net cash provided by operating activities	183,832	149,965
Cash flows from investing activities:
Acquisitions, net of cash acquired	(13)	(3,800)
Purchases of property and equipment	(118,341)	(122,921)
Proceeds from disposal of assets and insurance claims	22,054	10,294
Net cash used in investing activities	(96,300)	(116,427)
Cash flows from financing activities:
Purchases of treasury stock	(75,113)	(16,928)
Proceeds from exercise of options		485
Dividends paid	(8,499)	(4,443)
Debt issuance costs		(4,198)
Proceeds from long-term debt		521,194
Proceeds from borrowings under revolving credit facility		79,000
Repayment of borrowings under revolving credit facility		(347,000)
Net cash provided by financing activities	(83,612)	228,110
Effect of foreign exchange rate changes on cash	(48)	(225)
Net increase in cash and cash equivalents	3,872	261,423
Cash and cash equivalents at beginning of period	245,029	42,828
Cash and cash equivalents at end of period	248,901	304,251
Net cash (paid) received during the period for:
Interest, net of capitalized interest of $257 in 2019 and $340 in 2018	(10,689)	(2,206)
Income taxes	(15)	21
Non-cash investing and financing activities:
Receivable from property and equipment insurance		15,000
Net increase (decrease) in payables for purchases of property and equipment	(10,764)	62,488
Net (increase) decrease in deposits on equipment purchases	$ 1,535	$ (2,294)

XML

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS (Parenthetical) (Unaudited) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Statement Of Cash Flows [Abstract]
Interest expense, capitalized interest	$ 257	$ 340

XML

Basis of Presentation

3 Months Ended

Mar. 31, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Basis of Presentation

1. Basis of Presentation

Basis of presentation - The unaudited interim condensed consolidated financial statements include the accounts of Patterson-UTI Energy, Inc. and its wholly-owned subsidiaries (collectively referred to herein as the “Company”). 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 unaudited interim condensed consolidated financial statements have been prepared by management of the Company pursuant to the rules and regulations of the United States Securities and Exchange Commission (“SEC”). Certain information and footnote disclosures normally included in financial statements prepared in accordance with accounting principles generally accepted in the United States of America (“U.S. GAAP”) have been omitted pursuant to such rules and regulations, although the Company believes the disclosures included either on the face of the financial statements or herein are sufficient to make the information presented not misleading. In the opinion of management, all recurring adjustments considered necessary for a fair statement of the information in conformity with U.S. GAAP have been included. The unaudited condensed consolidated balance sheet as of December 31, 2018, as presented herein, was derived from the audited consolidated balance sheet of the Company, but does not include all disclosures required by U.S. GAAP. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes included in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018. The results of operations for the three months ended March 31, 2019 are not necessarily indicative of the results to be expected for the full year.

The U.S. dollar is the functional currency for all of the Company’s operations except for its Canadian operations, which use the Canadian dollar as its functional currency. The effects of exchange rate changes are reflected in accumulated other comprehensive income, which is a separate component of stockholders’ equity.

Recently Issued Accounting Standards – In May 2014, the Financial Accounting Standards Board (“FASB”) issued an accounting standards update to provide guidance on the recognition of revenue from customers.  Under this guidance, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects what it expects in exchange for the goods or services.  This guidance also requires more detailed disclosures to enable users of the financial statements to understand the nature, amount, timing and uncertainty, if any, of revenue and cash flows arising from contracts with customers.  The requirements in this update are effective during interim and annual periods beginning after December 15, 2017.  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 by class of underlying asset to not recognize the lease liability and related right-of-use asset for leases with a term of one year or less.  The provisions of this standard also apply to situations where the Company is the lessor. The requirements in this update are effective during interim and annual periods beginning after December 15, 2018.  The Company 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 4).  

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 for additional information.

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 amendments in the update are effective for public business entities for fiscal years beginning after December 15, 2019, with early adoption permitted. The Company is currently evaluating the impact this new guidance will have on its consolidated financial statements.

XML

Acquisitions

3 Months Ended

Mar. 31, 2019

Business Combinations [Abstract]

Acquisitions

2. Acquisitions

Superior QC, LLC (“Superior QC”)

On February 20, 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 of horizontal wellbore placement.  Superior QC’s measurement while drilling (MWD) survey fault detection, isolation and recovery (FDIR) service is a data analytics technology to analyze MWD survey data in real-time and more accurately identify the position of a well.  This acquisition was not material to the Company’s consolidated financial statements.

Current Power Solutions, Inc. (“Current Power”)

On October 25, 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.

XML

Revenues

3 Months Ended

Mar. 31, 2019

Revenue From Contract With Customer [Abstract]

Revenues

3. Revenues

ASC 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 that 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, oilfield technology, electrical controls and automation, and oil and natural gas working interests.  For more information on the Company’s business segments, including disaggregated revenue recognized from contracts with customers, see Note 15.

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.

Accounts Receivable and Contract Liabilities

Accounts receivable is the Company’s right to consideration once it becomes unconditional.  Payment terms range from 30 to 60 days.

Accounts receivable balances were $544 million and $554 million as of March 31, 2019 and December 31, 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 Condensed 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 three months ended March 31, 2019 and 2018, approximately $402,000 and $405,000, respectively, was amortized and recorded in drilling revenue.

Contract liability balances for customer prepayments were $6.8 million and $3.0 million as of March 31, 2019 and December 31, 2018, respectively.  Contract liability balances for deferred mobilization payments relating to newly constructed or upgraded rigs were $4.2 million and $4.6 million as of March 31, 2019 and December 31, 2018, respectively. Contract liability balances for customer prepayments are included in “Accounts Payable” and contract liability balances for deferred mobilization payments are included in “Accrued Liabilities” in the Condensed 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.  

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Leases

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Leases

4. Leases

     ASC Topic 842 Leases

     On January 1, 2019, the Company adopted the new lease guidance under Topic 842, Leases, using the modified retrospective approach to each lease that existed at the date of initial application as well as leases entered into after that date.  The Company has elected to report all leases at the beginning of the period of adoption and not restate its comparative periods.  This standard does not apply to leases to explore for or use minerals, oil, natural gas and similar non-regenerative resources, including the intangible right to

explore for those natural resources and rights to use the land in which those natural resources are contained.

     The Company has entered into operating leases for operating locations, corporate offices and certain operating equipment.  These leases have remaining lease terms of 1 month to 9 years as of March 31, 2019.  Currently, the Company does not have any finance leases.  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 less than one year.

     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.  

     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 contains 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 our 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 three months ended March 31, 2019 (in thousands):

	Three Months Ended
	March 31,
	2019
Operating lease cost	$	3,039
Short-term lease expense (1)		276
Total lease expense	$	3,315

(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 three months ended March 31, 2019 is as follows (in thousands):

	Three Months Ended
	March 31,
	2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	2,728
Right of use assets obtained in exchange for lease obligations:
Operating leases	$	-

          Supplemental balance sheet information related to leases as of March 31, 2019 is as follows:

	March 31,
	2019
Weighted Average Remaining Lease Term:
Operating leases	5.0 years
Weighted Average Discount Rate:
Operating leases		4.4	%

          Maturities of operating lease liabilities as of March 31, 2019 are as follows (in thousands):

Year ending December 31,
2019 (excluding the three months ended March 31, 2019)	$	8,062
2020		9,188
2021		6,661
2022		4,622
2023		2,663
Thereafter		6,552
Total lease payments		37,748
Less imputed interest		(4,628	)
Total	$	33,120

          Maturities of operating lease liabilities as of December 31, 2018, as previously disclosed in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018, are as follows (in thousands):

Year ending December 31,
2019	$	11,408
2020		9,069
2021		6,543
2022		4,625
2023		2,663
Thereafter		6,552
Total	$	40,860

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Inventory

3 Months Ended

Mar. 31, 2019

Inventory Disclosure [Abstract]

Inventory

5. Inventory

Inventory consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,		December 31,
	2019		2018
Finished goods	$	602	$	347
Work-in-process		6,088		6,375
Raw materials and supplies		59,181		58,857
Inventory	$	65,871	$	65,579

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Property and Equipment

3 Months Ended

Mar. 31, 2019

Property Plant And Equipment [Abstract]

Property and Equipment

6. Property and Equipment

Property and equipment consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,			December 31,
	2019			2018
Equipment	$	8,392,658		$	8,370,933
Oil and natural gas properties		221,782			219,855
Buildings		186,989			186,736
Land		26,898			26,144
Total property and equipment		8,828,327			8,803,668
Less accumulated depreciation, depletion and impairment		(4,929,809	)		(4,801,119	)
Property and equipment, net	$	3,898,518		$	4,002,549

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.

The Company concluded that no triggering events occurred during the three months ended March 31, 2019 with respect to its asset groups based on the Company’s results of operations for the three months ended March 31, 2019, management’s expectations of operating results in future periods and the prevailing commodity prices at the time. 

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Goodwill and Intangible Assets

3 Months Ended

Mar. 31, 2019

Goodwill And Intangible Assets Disclosure [Abstract]

Goodwill and Intangible Assets

7. Goodwill and Intangible Assets

Goodwill — Goodwill by operating segment as of March 31, 2019 and changes for the three months then ended are as follows (in thousands):

	Contract		Other
	Drilling		Operations		Total
Balance at beginning of period	$	395,060		15,696	$	410,756
Changes to goodwill		—		2,104		2,104
Balance at end of period	$	395,060	$	17,800	$	412,860

The goodwill reflected above has increased $2.1 million from the original Current Power purchase price allocation primarily as a result of a measurement period adjustment related to accrued liabilities.  There were no accumulated impairment losses related to goodwill in the contract drilling segment or other operations as of March 31, 2019 or December 31, 2018.

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.

Intangible Assets — The following table presents the gross carrying amount and accumulated amortization of the intangible assets as of March 31, 2019 and December 31, 2018 (in thousands):

	March 31, 2019							December 31, 2018
	Gross					Net		Gross					Net
	Carrying		Accumulated			Carrying		Carrying		Accumulated			Carrying
	Amount		Amortization			Amount		Amount		Amortization			Amount
Customer relationships	$	28,000	$	(12,967	)		15,033	$	28,000	$	(10,719	)	$	17,281
Developed technology		55,772		(7,927	)		47,845		55,772		(6,533	)		49,239
Favorable drilling contracts		-		-			-		22,500		(22,500	)		-
Internal use software		482		(142	)		340		482		(118	)		364
	$	84,254	$	(21,036	)	$	63,218	$	106,754	$	(39,870	)	$	66,884

Amortization expense on intangible assets of approximately $3.7 million and $5.4 million was recorded in the three months ended March 31, 2019 and 2018, respectively.

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Accrued Expenses

3 Months Ended

Mar. 31, 2019

Payables And Accruals [Abstract]

Accrued Expenses

8. Accrued Expenses

Accrued expenses consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,		December 31,
	2019		2018
Salaries, wages, payroll taxes and benefits	$	58,717	$	58,160
Workers' compensation liability		82,537		83,772
Property, sales, use and other taxes		21,156		25,318
Insurance, other than workers' compensation		9,611		9,531
Accrued interest payable		17,806		15,774
Accrued merger and integration		1,890		2,403
Other		48,479		40,988
Total	$	240,196	$	235,946

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Long Term Debt

3 Months Ended

Mar. 31, 2019

Debt Disclosure [Abstract]

Long Term Debt

9. Long Term Debt

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 (the “Amendment”), 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.  The Company has the option, subject to certain conditions, to exercise two one-year extensions of the maturity date.

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 March 31, 2019, the Company had no amounts outstanding under the revolving credit facility.  The Company had $81,000 in letters of credit outstanding under the revolving credit facility at March 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 March 31, 2019, the Company had $51.4 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 & B Senior Notes — On October 5, 2010, the Company completed the issuance and sale of $300 million in aggregate principal amount of its 4.97% Series A Senior Notes due October 5, 2020 (the “Series A Notes”) in a private placement. The Series A Notes bear interest at a rate of 4.97% per annum. The Company pays interest on the Series A Notes on April 5 and October 5 of each year. The Series A Notes will mature on October 5, 2020.

On June 14, 2012, the Company completed the issuance and sale of $300 million in aggregate principal 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 bear interest at a rate of 4.27% per annum. The Company pays interest on the Series B Notes on April 5 and October 5 of each year. The Series B Notes will mature on June 14, 2022.

The Series A Notes and Series B Notes are senior unsecured obligations of the Company which rank equally in right of payment with all other unsubordinated indebtedness of the Company. The Series A Notes and Series B Notes are guaranteed on a senior unsecured basis by each of the existing domestic subsidiaries of the Company other than subsidiaries that are not required to be guarantors under the Credit Agreement. No subsidiaries of the Company are currently required to be a guarantor under the Credit Agreement.

The Series A Notes and Series B Notes are prepayable at the Company’s option, in whole or in part, provided that in the case of a partial prepayment, prepayment must be in an amount not less than 5% of the aggregate principal amount of the notes then outstanding, at any time and from time to time at 100% of the principal amount prepaid, plus accrued and unpaid interest to the prepayment date, plus a “make-whole” premium as specified in the note purchase agreements. The Company must offer to prepay the notes upon the occurrence of any change of control. In addition, the Company must offer to prepay the notes upon the occurrence of certain asset dispositions if the proceeds therefrom are not timely reinvested in productive assets. If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.

The respective note purchase agreements require compliance with two financial covenants. The Company must not permit its debt to capitalization ratio to exceed 50% at any time. The note purchase agreements generally define the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit its interest coverage ratio as of the last day of a fiscal quarter to be less than 2.50 to 1.00. The note purchase agreements generally define the interest coverage ratio as the ratio of EBITDA for the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at March 31, 2019.

Events of default under the note purchase agreements include failure to pay principal or interest when due, failure to comply with the financial and operational covenants, a cross default event, a judgment in excess of a threshold event, the guaranty agreement ceasing to be enforceable, the occurrence of certain ERISA events, a change of control event and bankruptcy and other insolvency events. If an event of default under the note purchase agreements occurs and is continuing, then holders of a majority in principal amount of the respective notes have the right to declare all the notes then-outstanding to be immediately due and payable. In addition, if the Company defaults in payments on any note, then until such defaults are cured, the holder thereof may declare all the notes held by it pursuant to the note purchase agreement to be immediately due and payable.

2028 Senior Notes – On January 19, 2018, the Company completed its offering of $525 million aggregate principal amount of the Company’s 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.  

The Company pays interest on the 2028 Notes on February 1 and August 1 of each year.  The 2028 Notes will mature on February 1, 2028.  The 2028 Notes bear interest at a rate of 3.95% per annum.

The 2028 Notes are 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 2028 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 2028 Notes will be structurally subordinated to the liabilities (including trade payables) of the Company’s subsidiaries that do not guarantee the 2028 Notes.  No subsidiaries of the Company are currently required to be a guarantor under the 2028 Notes.  If subsidiaries of the Company guarantee the 2028 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 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 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date, plus a make-whole premium.  Additionally, commencing on November 1, 2027, the Company, at its option, may redeem the 2028 Notes in whole or in part, at a redemption price equal to 100% of the principal amount of the 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date.

The indenture pursuant to which the 2028 Notes were issued includes covenants that, among other things, limit the Company and its subsidiaries’ ability to incur certain liens, engage in sale and lease-back transactions or consolidate, merge, or transfer all or substantially all of their assets.  These covenants are subject to important qualifications and limitations set forth in the indenture.

Upon the occurrence of a change of control, as defined in the indenture, each holder of the 2028 Notes may require the Company to purchase all or a portion of such holder’s 2028 Notes at a price equal to 101% of their principal amount, plus accrued and unpaid interest, if any, to, but excluding, the repurchase date.

The indenture also provides for events of default which, if any of them occurs, would permit or require the principal of, premium, if any, and accrued interest, if any, on the 2028 Notes to become or to be declared due and payable.

Debt issuance costs –Debt issuance costs are deferred and recognized as interest expense over the term of the underlying debt.  Interest expense related to the amortization of debt issuance costs was approximately $351,000 and $938,000 for the three months ended March 31, 2019 and 2018, respectively.  Amortization of debt issuance costs for the three months ended March 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 2018 Credit Agreement.

Presented below is a schedule of the principal repayment requirements of long-term debt as of March 31, 2019 (in thousands):

Year ending December 31,
2019	$	—
2020		300,000
2021		—
2022		300,000
2023		—
Thereafter		525,000
Total	$	1,125,000

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Commitments and Contingencies

3 Months Ended

Mar. 31, 2019

Commitments And Contingencies Disclosure [Abstract]

Commitments and Contingencies

10. Commitments and Contingencies

As of March 31, 2019, the Company maintained letters of credit in the aggregate amount of $51.4 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 March 31, 2019, no amounts had been drawn under the letters of credit.

As of March 31, 2019, the Company had commitments to purchase major equipment and make investments totaling approximately $89.9 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 2019 through 2023. As of March 31, 2019, the remaining obligation under these agreements was approximately $50 million, of which approximately $22.3 million relates to purchases required during the remainder of 2019. 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.

On January 22, 2018, an accident at a drilling site in Pittsburg County, Oklahoma resulted in the losses of life of five people, including three of the Company’s employees. Lawsuits have been filed in the District Court for Pittsburg County, Oklahoma in connection with the five individuals who lost their lives and one of the Company’s employees who was injured in the accident.  The lawsuits have been consolidated for discovery purposes under Cause No. CJ-2018-60 (the “Litigation”).  These lawsuits allege various causes of action against the Company including negligence, gross negligence, knowledge that injury or death was substantially certain, acting with purpose, recklessness, wrongful death and survival, and the plaintiffs seek an unspecified amount of damages, including punitive or exemplary damages, costs, interest, and other relief.  The Company has finalized settlement agreements with four of the plaintiffs who brought wrongful death lawsuits.  The Company disputes the plaintiffs’ allegations against the Company in the remaining lawsuits and intends to continue to defend itself vigorously.  Based on the information the Company has available as of the date of this Report, the Company believes that it has adequate insurance to cover the Litigation. However, if this accident is not fully covered by insurance or an enforceable and recoverable indemnity from a third party, it could have a material adverse effect on the Company’s business, financial condition, cash flows and results of operations.

The Company is party to various 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.

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Stockholders' Equity

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Stockholders' Equity

11. Stockholders’ Equity

Cash Dividends — The Company paid cash dividends during the three months ended March 31, 2019 and 2018 as follows:

2019:	Per Share		Total
			(in thousands)
Paid on March 21, 2019	$	0.04	$	8,499

2018:	Per Share		Total
			(in thousands)
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

On April 24, 2019, 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 June 20, 2019 to holders of record as of June 6, 2019. 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 February 6, 2019, the Company’s Board of Directors approved another increase of the authorization under the stock buyback program to allow for $250 million of share repurchases.  All purchases executed to date have been through open market transactions.  Purchases under the program are made at management’s discretion, at prevailing prices, subject to market conditions and other factors. Purchases may be made at any time without prior notice.  There is no expiration date associated with the buyback program.  As of March 31, 2019, the Company had remaining authorization to purchase approximately $175 million of the Company’s outstanding common stock under the stock buyback program. Shares of stock purchased under the buyback program are held as treasury shares. The Company acquired shares of stock from employees during the first quarter that are accounted for as treasury stock. These shares were acquired to satisfy payroll withholding obligations upon the vesting of restricted shares and restricted stock units.  These shares were acquired at fair market value. These acquisitions were made pursuant to the terms of the Patterson-UTI Energy, Inc. Amended and Restated 2014 Long-Term Incentive Plan (the “2014 Plan”) and not pursuant to the stock buyback program.  

Treasury stock acquisitions during the three months ended March 31, 2019 were as follows (dollars in thousands):

	Shares		Cost
Treasury shares at beginning of period		53,701,096	$	1,080,448
Purchases pursuant to stock buyback program		5,408,132		75,110
Acquisitions pursuant to long-term incentive plan		240		3
Treasury shares at end of period		59,109,468	$	1,155,561

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Stock-based Compensation

3 Months Ended

Mar. 31, 2019

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Stock-based Compensation

12. 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.  

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 three months ended March 31, 2019 or 2018.   

Stock option activity from January 1, 2019 to March 31, 2019 follows:

			Weighted
			Average
	Underlying		Exercise Price
	Shares		Per Share
Outstanding at January 1, 2019		5,501,150	$	19.63
Exercised		—	$	-
Expired		—	$	-
Outstanding at March 31, 2019		5,501,150	$	19.63
Exercisable at March 31, 2019		5,432,679	$	19.64

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 from January 1, 2019 to March 31, 2019 follows:

				Weighted
				Average Grant
				Date Fair Value
	Shares			Per Share
Non-vested restricted stock outstanding at January 1, 2019		436,224		$	21.41
Vested		(64,494	)	$	20.61
Forfeited		(1,033	)	$	21.71
Non-vested restricted stock outstanding at March 31, 2019		370,697		$	21.55

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 from January 1, 2019 to March 31, 2019 follows:

						Weighted
						Average Grant
	Time			Performance		Date Fair Value
	Based			Based		Per Share
Non-vested restricted stock units outstanding at January 1, 2019		2,602,608			435,315	$	18.95
Granted		101,448			—	$	10.35
Vested		(38,615	)		—	$	22.95
Forfeited		(46,738	)		—	$	19.23
Non-vested restricted stock units outstanding at March 31, 2019		2,618,703			435,315	$	18.61

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.  Generally, the recipients will receive a target number of shares if the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 50^th percentile.  If the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 75^th 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 25^th 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 25^th and 75^th percentile, then the shares to be received by the recipients will be determined using linear interpolation for levels of achievement between these points.  

In April 2018, 381,200 shares were issued to settle the 2015 Performance Units. For the Performance Units granted in April 2016, if the Company’s total shareholder return for the performance period is negative, and, when compared to the peer group is at or above the 25th percentile, then the recipients will receive one-half of the number of shares they would have received had the Company’s total shareholder return been positive.  For the Performance Units granted in May 2017 and April 2018, the payout is based on relative performance and does not have an absolute performance requirement.  

The total target number of shares with respect to the Performance Units for the awards granted in 2015-2018 is set forth below:

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Target number of shares		310,700		186,198		185,000		190,600

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):

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Fair value at date of grant	$	8,004	$	5,780	$	3,854	$	4,052

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 shown below (in thousands):

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Three months ended March 31, 2019	$	667	$	482	$	321	NA
Three months ended March 31, 2018	NA		$	482	$	321	$	338

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Income Taxes

3 Months Ended

Mar. 31, 2019

Income Tax Disclosure [Abstract]

Income Taxes

13. Income Taxes

The Company’s effective income tax rate fluctuates from the U.S. statutory tax rate based on, among other factors, changes in pretax income in jurisdictions with varying statutory tax rates, impact of U.S. state and local taxes, and other differences related to the recognition of income and expense between U.S. GAAP and tax.

The Company’s effective income tax rate for the three months ended March 31, 2019 was 18.8%, compared with (.8)% for the three months ended March 31, 2018. The lower effective income tax rate for the three months ended March 31, 2018 was primarily attributable to changes in forecasted annual pretax income in the first quarter of 2018 as compared to the forecasted annual pretax income in the first quarter of 2019.  The Company also recorded a valuation allowance against the net deferred tax assets of a Canadian subsidiary of the Company due to a change in judgment as to the realizability of these assets in the first quarter of 2018.

The Company continues to monitor income tax developments in the United States and other countries where the Company operates.  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 to be finalized during 2019, as well as additional regulations to be proposed and finalized during 2019.  The Company will incorporate into its future financial statements the impacts, if any, of these regulations and additional authoritative guidance when finalized.

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Earnings Per Share

3 Months Ended

Mar. 31, 2019

Earnings Per Share [Abstract]

Earnings Per Share

14. Earnings Per Share

The Company provides a dual presentation of its net loss per common share in its unaudited condensed consolidated statements of operations: basic net loss per common share (“Basic EPS”) and diluted net 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 loss per share for the three months ended March 31, 2019 and 2018 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):

	Three Months Ended
	March 31,
	2019			2018
BASIC EPS:
Net loss attributed to common stockholders	$	(28,614	)	$	(34,417	)
Weighted average number of common shares outstanding, excluding    non-vested shares of restricted stock		211,868			220,783
Basic net loss per common share	$	(0.14	)	$	(0.16	)
DILUTED EPS:
Net loss attributed to common stockholders	$	(28,614	)	$	(34,417	)
Weighted average number of common shares outstanding, excluding    non-vested shares of restricted stock		211,868			220,783
Add dilutive effect of potential common shares		—			—
Weighted average number of diluted common shares outstanding		211,868			220,783
Diluted net loss per common share	$	(0.14	)	$	(0.16	)
Potentially dilutive securities excluded as anti-dilutive		10,033			9,738

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Business Segments

3 Months Ended

Mar. 31, 2019

Segment Reporting [Abstract]

Business Segments

15. Business Segments

At March 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.

The following tables summarize selected financial information relating to the Company’s business segments (in thousands):

	Three Months Ended
	March 31,
	2019			2018
Revenues:
Contract drilling	$	372,743		$	328,153
Pressure pumping		247,601			406,784
Directional drilling		52,959			48,616
Other operations (1)		35,391			29,653
Elimination of intercompany revenues (2)		(4,523	)		(4,042	)
Total revenues	$	704,171		$	809,164
Income (loss) before income taxes:
Contract drilling	$	21,217		$	(17,103	)
Pressure pumping		(18,768	)		25,389
Directional drilling		(5,667	)		(4,913	)
Other operations		(5,204	)		(4,089	)
Corporate		(23,697	)		(23,807	)
Other operating income, net (3)		8,736			2,421
Interest income		1,032			1,423
Interest expense		(12,984	)		(13,625	)
Other		117			169
Loss before income taxes	$	(35,218	)	$	(34,135	)
Depreciation, depletion, amortization and impairment:
Contract drilling	$	130,317		$	130,917
Pressure pumping		60,135			56,522
Directional drilling		10,367			10,902
Other operations		11,788			9,314
Corporate		1,803			2,237
Total depreciation, depletion, amortization and impairment	$	214,410		$	209,892
Capital expenditures:
Contract drilling	$	75,725		$	75,247
Pressure pumping		31,400			24,923
Directional drilling		2,112			12,829
Other operations		7,773			9,396
Corporate		1,331			526
Total capital expenditures	$	118,341		$	122,921

	March 31,		December 31,
	2019		2018
Identifiable assets:
Contract drilling	$	3,725,627	$	3,817,638
Pressure pumping		894,357		921,237
Directional drilling		242,686		239,341
Other operations		179,584		177,374
Corporate (4)		325,498		314,276
Total assets	$	5,367,752	$	5,469,866

(1) Other operations includes the Company’s oilfield rentals business, pipe handling components and related technology business, the electrical controls and automation business, the oil and natural gas working interests and Middle East/North Africa 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.  

(4) Corporate assets primarily include cash on hand and certain property and equipment.

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Fair Values of Financial Instruments

3 Months Ended

Mar. 31, 2019

Fair Value Disclosures [Abstract]

Fair Values of Financial Instruments

16. Fair Values of Financial Instruments

The carrying values of cash and cash equivalents, trade receivables and accounts payable approximate fair value due to the short-term maturity of these items. These fair value estimates are considered Level 1 fair value estimates in the fair value hierarchy of fair value accounting.

The estimated fair value of the Company’s outstanding debt balances as of March 31, 2019 and December 31, 2018 is set forth below (in thousands):

	March 31, 2019				December 31, 2018
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value
3.95% Senior Notes	$	525,000	$	501,909	$	525,000	$	482,488
4.97% Series A Senior Notes		300,000		301,459		300,000		300,043
4.27% Series B Senior Notes		300,000		297,875		300,000		293,900
Total debt	$	1,125,000	$	1,101,243	$	1,125,000	$	1,076,431

The fair values of the 3.95% Senior Notes at March 31, 2019 and December 31, 2018 are based on discounted cash flows associated with the notes using the 4.65% market rate of interest at March 31, 2019 and the 5.07% market rate of interest at December 31, 2018.  The fair value estimates of the 3.95% 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 March 31, 2019 and 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 rates used in measuring this fair value were 4.63% at March 31, 2019 and 4.97% at December 31, 2018.  For the Series B Notes, the current market rates used in measuring this fair value were 4.51% at March 31, 2019 and 4.92% at December 31, 2018. These fair value estimates are based on observable market inputs and are considered Level 2 fair value estimates in the fair value hierarchy of fair value accounting.

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Basis of Presentation (Policies)

3 Months Ended

Mar. 31, 2019

Organization Consolidation And Presentation Of Financial Statements [Abstract]

Recently Issued Accounting Standards

Recently Issued Accounting Standards – In May 2014, the Financial Accounting Standards Board (“FASB”) issued an accounting standards update to provide guidance on the recognition of revenue from customers.  Under this guidance, an entity will recognize revenue when it transfers promised goods or services to customers in an amount that reflects what it expects in exchange for the goods or services.  This guidance also requires more detailed disclosures to enable users of the financial statements to understand the nature, amount, timing and uncertainty, if any, of revenue and cash flows arising from contracts with customers.  The requirements in this update are effective during interim and annual periods beginning after December 15, 2017.  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 by class of underlying asset to not recognize the lease liability and related right-of-use asset for leases with a term of one year or less.  The provisions of this standard also apply to situations where the Company is the lessor. The requirements in this update are effective during interim and annual periods beginning after December 15, 2018.  The Company 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 4).  

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 for additional information.

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 amendments in the update are effective for public business entities for fiscal years beginning after December 15, 2019, with early adoption permitted. The Company is currently evaluating the impact this new guidance will have on its consolidated financial statements.

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Leases (Tables)

3 Months Ended

Mar. 31, 2019

Leases [Abstract]

Summary of Lease Expense

Lease expense consisted of the following for the three months ended March 31, 2019 (in thousands):

	Three Months Ended
	March 31,
	2019
Operating lease cost	$	3,039
Short-term lease expense (1)		276
Total lease expense	$	3,315

(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 three months ended March 31, 2019 is as follows (in thousands):

	Three Months Ended
	March 31,
	2019
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	2,728
Right of use assets obtained in exchange for lease obligations:
Operating leases	$	-

Summary of Supplemental Balance Sheet Information Related to Leases

          Supplemental balance sheet information related to leases as of March 31, 2019 is as follows:

	March 31,
	2019
Weighted Average Remaining Lease Term:
Operating leases	5.0 years
Weighted Average Discount Rate:
Operating leases		4.4	%

Summary of Maturities of Operating Lease Liabilities

          Maturities of operating lease liabilities as of March 31, 2019 are as follows (in thousands):

Year ending December 31,
2019 (excluding the three months ended March 31, 2019)	$	8,062
2020		9,188
2021		6,661
2022		4,622
2023		2,663
Thereafter		6,552
Total lease payments		37,748
Less imputed interest		(4,628	)
Total	$	33,120

Summary of Maturities of Operating Lease Liabilities Previously Disclosed

          Maturities of operating lease liabilities as of December 31, 2018, as previously disclosed in the Company’s Annual Report on Form 10-K for the fiscal year ended December 31, 2018, are as follows (in thousands):

Year ending December 31,
2019	$	11,408
2020		9,069
2021		6,543
2022		4,625
2023		2,663
Thereafter		6,552
Total	$	40,860

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Inventory (Tables)

3 Months Ended

Mar. 31, 2019

Inventory Disclosure [Abstract]

Inventory

Inventory consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,		December 31,
	2019		2018
Finished goods	$	602	$	347
Work-in-process		6,088		6,375
Raw materials and supplies		59,181		58,857
Inventory	$	65,871	$	65,579

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Property and Equipment (Tables)

3 Months Ended

Mar. 31, 2019

Property Plant And Equipment [Abstract]

Property and Equipment

Property and equipment consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,			December 31,
	2019			2018
Equipment	$	8,392,658		$	8,370,933
Oil and natural gas properties		221,782			219,855
Buildings		186,989			186,736
Land		26,898			26,144
Total property and equipment		8,828,327			8,803,668
Less accumulated depreciation, depletion and impairment		(4,929,809	)		(4,801,119	)
Property and equipment, net	$	3,898,518		$	4,002,549

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Goodwill and Intangible Assets (Tables)

3 Months Ended

Mar. 31, 2019

Goodwill And Intangible Assets Disclosure [Abstract]

Goodwill by Operating Segment

Goodwill — Goodwill by operating segment as of March 31, 2019 and changes for the three months then ended are as follows (in thousands):

	Contract		Other
	Drilling		Operations		Total
Balance at beginning of period	$	395,060		15,696	$	410,756
Changes to goodwill		—		2,104		2,104
Balance at end of period	$	395,060	$	17,800	$	412,860

Gross Carrying Amount and Accumulated Amortization of Intangible Assets

Intangible Assets — The following table presents the gross carrying amount and accumulated amortization of the intangible assets as of March 31, 2019 and December 31, 2018 (in thousands):

	March 31, 2019							December 31, 2018
	Gross					Net		Gross					Net
	Carrying		Accumulated			Carrying		Carrying		Accumulated			Carrying
	Amount		Amortization			Amount		Amount		Amortization			Amount
Customer relationships	$	28,000	$	(12,967	)		15,033	$	28,000	$	(10,719	)	$	17,281
Developed technology		55,772		(7,927	)		47,845		55,772		(6,533	)		49,239
Favorable drilling contracts		-		-			-		22,500		(22,500	)		-
Internal use software		482		(142	)		340		482		(118	)		364
	$	84,254	$	(21,036	)	$	63,218	$	106,754	$	(39,870	)	$	66,884

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Accrued Expenses (Tables)

3 Months Ended

Mar. 31, 2019

Payables And Accruals [Abstract]

Summary of Accrued Expenses

Accrued expenses consisted of the following at March 31, 2019 and December 31, 2018 (in thousands):

	March 31,		December 31,
	2019		2018
Salaries, wages, payroll taxes and benefits	$	58,717	$	58,160
Workers' compensation liability		82,537		83,772
Property, sales, use and other taxes		21,156		25,318
Insurance, other than workers' compensation		9,611		9,531
Accrued interest payable		17,806		15,774
Accrued merger and integration		1,890		2,403
Other		48,479		40,988
Total	$	240,196	$	235,946

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Long Term Debt (Tables)

3 Months Ended

Mar. 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 as of March 31, 2019 (in thousands):

Year ending December 31,
2019	$	—
2020		300,000
2021		—
2022		300,000
2023		—
Thereafter		525,000
Total	$	1,125,000

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Stockholders' Equity (Tables)

3 Months Ended

Mar. 31, 2019

Equity [Abstract]

Cash Dividends

Cash Dividends — The Company paid cash dividends during the three months ended March 31, 2019 and 2018 as follows:

2019:	Per Share		Total
			(in thousands)
Paid on March 21, 2019	$	0.04	$	8,499

2018:	Per Share		Total
			(in thousands)
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

Treasury Stock Acquisition

Treasury stock acquisitions during the three months ended March 31, 2019 were as follows (dollars in thousands):

	Shares		Cost
Treasury shares at beginning of period		53,701,096	$	1,080,448
Purchases pursuant to stock buyback program		5,408,132		75,110
Acquisitions pursuant to long-term incentive plan		240		3
Treasury shares at end of period		59,109,468	$	1,155,561

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Stock-based Compensation (Tables)

3 Months Ended

Mar. 31, 2019

Disclosure Of Compensation Related Costs Sharebased Payments [Abstract]

Stock Option Activity

Stock option activity from January 1, 2019 to March 31, 2019 follows:

			Weighted
			Average
	Underlying		Exercise Price
	Shares		Per Share
Outstanding at January 1, 2019		5,501,150	$	19.63
Exercised		—	$	-
Expired		—	$	-
Outstanding at March 31, 2019		5,501,150	$	19.63
Exercisable at March 31, 2019		5,432,679	$	19.64

Restricted Stock Activity

Restricted stock activity from January 1, 2019 to March 31, 2019 follows:

				Weighted
				Average Grant
				Date Fair Value
	Shares			Per Share
Non-vested restricted stock outstanding at January 1, 2019		436,224		$	21.41
Vested		(64,494	)	$	20.61
Forfeited		(1,033	)	$	21.71
Non-vested restricted stock outstanding at March 31, 2019		370,697		$	21.55

Restricted Stock Unit Activity

Restricted stock unit activity from January 1, 2019 to March 31, 2019 follows:

						Weighted
						Average Grant
	Time			Performance		Date Fair Value
	Based			Based		Per Share
Non-vested restricted stock units outstanding at January 1, 2019		2,602,608			435,315	$	18.95
Granted		101,448			—	$	10.35
Vested		(38,615	)		—	$	22.95
Forfeited		(46,738	)		—	$	19.23
Non-vested restricted stock units outstanding at March 31, 2019		2,618,703			435,315	$	18.61

Performance Units

The total target number of shares with respect to the Performance Units for the awards granted in 2015-2018 is set forth below:

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Target number of shares		310,700		186,198		185,000		190,600

Fair Value of Performance Units

The fair value of the Performance Units is set forth below (in thousands):

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Fair value at date of grant	$	8,004	$	5,780	$	3,854	$	4,052

Compensation Expense Associated with Performance Units

Compensation expense associated with the Performance Units is shown below (in thousands):

	2018		2017		2016		2015
	Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards
Three months ended March 31, 2019	$	667	$	482	$	321	NA
Three months ended March 31, 2018	NA		$	482	$	321	$	338

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Earnings Per Share (Tables)

3 Months Ended

Mar. 31, 2019

Earnings Per Share [Abstract]

Calculation of Basic and Diluted Net Loss per Share

The following table presents information necessary to calculate net loss per share for the three months ended March 31, 2019 and 2018 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):

	Three Months Ended
	March 31,
	2019			2018
BASIC EPS:
Net loss attributed to common stockholders	$	(28,614	)	$	(34,417	)
Weighted average number of common shares outstanding, excluding    non-vested shares of restricted stock		211,868			220,783
Basic net loss per common share	$	(0.14	)	$	(0.16	)
DILUTED EPS:
Net loss attributed to common stockholders	$	(28,614	)	$	(34,417	)
Weighted average number of common shares outstanding, excluding    non-vested shares of restricted stock		211,868			220,783
Add dilutive effect of potential common shares		—			—
Weighted average number of diluted common shares outstanding		211,868			220,783
Diluted net loss per common share	$	(0.14	)	$	(0.16	)
Potentially dilutive securities excluded as anti-dilutive		10,033			9,738

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Business Segments (Tables)

3 Months Ended

Mar. 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):

	Three Months Ended
	March 31,
	2019			2018
Revenues:
Contract drilling	$	372,743		$	328,153
Pressure pumping		247,601			406,784
Directional drilling		52,959			48,616
Other operations (1)		35,391			29,653
Elimination of intercompany revenues (2)		(4,523	)		(4,042	)
Total revenues	$	704,171		$	809,164
Income (loss) before income taxes:
Contract drilling	$	21,217		$	(17,103	)
Pressure pumping		(18,768	)		25,389
Directional drilling		(5,667	)		(4,913	)
Other operations		(5,204	)		(4,089	)
Corporate		(23,697	)		(23,807	)
Other operating income, net (3)		8,736			2,421
Interest income		1,032			1,423
Interest expense		(12,984	)		(13,625	)
Other		117			169
Loss before income taxes	$	(35,218	)	$	(34,135	)
Depreciation, depletion, amortization and impairment:
Contract drilling	$	130,317		$	130,917
Pressure pumping		60,135			56,522
Directional drilling		10,367			10,902
Other operations		11,788			9,314
Corporate		1,803			2,237
Total depreciation, depletion, amortization and impairment	$	214,410		$	209,892
Capital expenditures:
Contract drilling	$	75,725		$	75,247
Pressure pumping		31,400			24,923
Directional drilling		2,112			12,829
Other operations		7,773			9,396
Corporate		1,331			526
Total capital expenditures	$	118,341		$	122,921

	March 31,		December 31,
	2019		2018
Identifiable assets:
Contract drilling	$	3,725,627	$	3,817,638
Pressure pumping		894,357		921,237
Directional drilling		242,686		239,341
Other operations		179,584		177,374
Corporate (4)		325,498		314,276
Total assets	$	5,367,752	$	5,469,866

(1) Other operations includes the Company’s oilfield rentals business, pipe handling components and related technology business, the electrical controls and automation business, the oil and natural gas working interests and Middle East/North Africa 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.  

(4) Corporate assets primarily include cash on hand and certain property and equipment.

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Fair Values of Financial Instruments (Tables)

3 Months Ended

Mar. 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 March 31, 2019 and December 31, 2018 is set forth below (in thousands):

	March 31, 2019				December 31, 2018
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value
3.95% Senior Notes	$	525,000	$	501,909	$	525,000	$	482,488
4.97% Series A Senior Notes		300,000		301,459		300,000		300,043
4.27% Series B Senior Notes		300,000		297,875		300,000		293,900
Total debt	$	1,125,000	$	1,101,243	$	1,125,000	$	1,076,431

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Acquisitions - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019
Superior QC
Business Acquisition [Line Items]
Business acquisition date	Feb. 20, 2018
Current Power Solutions Inc.
Business Acquisition [Line Items]
Business acquisition date	Oct. 25, 2018

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Revenues - Additional Information (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Disaggregation Of Revenue [Line Items]
Accounts receivable balances	$ 547,993,000		$ 558,817,000
Amount amortized and recorded in drilling revenue	704,171,000	$ 809,164,000
Contract Drilling
Disaggregation Of Revenue [Line Items]
Amount amortized and recorded in drilling revenue	372,392,000	327,803,000
ASC Topic 606 Revenue from Contracts with Customers
Disaggregation Of Revenue [Line Items]
Accounts receivable balances	544,000,000		554,000,000
ASC Topic 606 Revenue from Contracts with Customers | Customer Prepayments
Disaggregation Of Revenue [Line Items]
Contract liability balances included in accounts payable and accrued liabilities	6,800,000		3,000,000
ASC Topic 606 Revenue from Contracts with Customers | Deferred Mobilization Payments
Disaggregation Of Revenue [Line Items]
Contract liability balances included in accounts payable and accrued liabilities	4,200,000		$ 4,600,000
ASC Topic 606 Revenue from Contracts with Customers | Contract Drilling
Disaggregation Of Revenue [Line Items]
Amount amortized and recorded in drilling revenue	$ 402,000	$ 405,000
Maximum
Disaggregation Of Revenue [Line Items]
Accounts receivable payment terms	60 days
Minimum
Disaggregation Of Revenue [Line Items]
Accounts receivable payment terms	30 days

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Leases - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019
Minimum
Lessee Lease Description [Line Items]
Operating leasing arrangements initial term	1 year
Leases remaining lease terms	1 month
Maximum
Lessee Lease Description [Line Items]
Leases remaining lease terms	9 years

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Leases - Summary of Lease Expense (Detail) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Leases [Abstract]
Operating lease cost	$ 3,039
Short-term lease expense	276	[1]
Total lease expense	$ 3,315

[1] Short-term lease expense represents expense related to leases with a contract term of one year or less.

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Leases - Summary of Supplemental Cashflow Information Related to Leases (Detail) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$ 2,728

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Leases - Summary of Supplemental Balance Sheet Information Related to Leases (Detail)	Mar. 31, 2019
Weighted Average Remaining Lease Term:
Operating leases	5 years
Weighted Average Discount Rate:
Operating leases	4.40%

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Leases - Summary of Maturities of Operating Lease Liabilities (Detail) $ in Thousands	Mar. 31, 2019 USD ($)
Leases [Abstract]
2019 (excluding the three months ended March 31, 2019)	$ 8,062
2020	9,188
2021	6,661
2022	4,622
2023	2,663
Thereafter	6,552
Total lease payments	37,748
Less imputed interest	(4,628)
Total	$ 33,120

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Leases - Summary of Maturities of Operating Lease Liabilities Previously Disclosed (Detail) $ in Thousands	Dec. 31, 2018 USD ($)
Leases [Abstract]
2019	$ 11,408
2020	9,069
2021	6,543
2022	4,625
2023	2,663
Thereafter	6,552
Total	$ 40,860

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Inventory (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Inventory Net [Abstract]
Finished goods	$ 602	$ 347
Work-in-process	6,088	6,375
Raw materials and supplies	59,181	58,857
Inventory	$ 65,871	$ 65,579

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Property and Equipment (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Property Plant And Equipment [Line Items]
Total property and equipment	$ 8,828,327	$ 8,803,668
Less accumulated depreciation, depletion and impairment	(4,929,809)	(4,801,119)
Property and equipment, net	3,898,518	4,002,549
Equipment
Property Plant And Equipment [Line Items]
Total property and equipment	8,392,658	8,370,933
Oil and natural gas properties
Property Plant And Equipment [Line Items]
Total property and equipment	221,782	219,855
Buildings
Property Plant And Equipment [Line Items]
Total property and equipment	186,989	186,736
Land
Property Plant And Equipment [Line Items]
Total property and equipment	$ 26,898	$ 26,144

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Goodwill by Operating Segment (Detail) $ in Thousands	3 Months Ended
	Mar. 31, 2019 USD ($)
Goodwill [Line Items]
Balance at beginning of period	$ 410,756
Changes to goodwill	2,104
Balance at end of period	412,860
Contract Drilling
Goodwill [Line Items]
Balance at beginning of period	395,060
Balance at end of period	395,060
Other Operations
Goodwill [Line Items]
Balance at beginning of period	15,696
Changes to goodwill	2,104
Balance at end of period	$ 17,800

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Goodwill and Intangible Assets - Additional Information (Detail) - USD ($)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Goodwill And Intangible Assets Disclosure [Line Items]
Increase in goodwill	$ 2,104,000
Amortization expense on intangible assets	3,700,000	$ 5,400,000
Contract Drilling
Goodwill And Intangible Assets Disclosure [Line Items]
Accumulated impairment losses	0		$ 0
Other Operations
Goodwill And Intangible Assets Disclosure [Line Items]
Increase in goodwill	2,104,000
Accumulated impairment losses	$ 0		$ 0

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Gross Carrying Amount and Accumulated Amortization of Intangible Assets (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	$ 84,254	$ 106,754
Accumulated Amortization	(21,036)	(39,870)
Net Carrying Amount	63,218	66,884
Customer Relationships
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	28,000	28,000
Accumulated Amortization	(12,967)	(10,719)
Net Carrying Amount	15,033	17,281
Developed Technology
Acquired Finite Lived Intangible Assets [Line Items]
Gross Carrying Amount	55,772	55,772
Accumulated Amortization	(7,927)	(6,533)
Net Carrying Amount	47,845	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	(142)	(118)
Net Carrying Amount	$ 340	$ 364

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Summary of Accrued Expenses (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Payables And Accruals [Abstract]
Salaries, wages, payroll taxes and benefits	$ 58,717	$ 58,160
Workers' compensation liability	82,537	83,772
Property, sales, use and other taxes	21,156	25,318
Insurance, other than workers' compensation	9,611	9,531
Accrued interest payable	17,806	15,774
Accrued merger and integration	1,890	2,403
Other	48,479	40,988
Accrued expenses	$ 240,196	$ 235,946

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Long Term Debt - Credit Facilities - Additional Information (Detail)				3 Months Ended
	Mar. 26, 2019	Mar. 27, 2018 USD ($) Option	Mar. 16, 2015	Mar. 31, 2019 USD ($)
Debt Instrument [Line Items]
Letters of credit outstanding				$ 51,400,000
Letter of Credit
Debt Instrument [Line Items]
Line of credit, amount outstanding				0
Revolving Credit Facility
Debt Instrument [Line Items]
Line of credit, amount outstanding				0
Line of credit, available borrowing capacity				$ 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, 2024	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
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				$ 51,400,000
Reimbursement Agreement | London Interbank Offered Rate (LIBOR)
Debt Instrument [Line Items]
Debt instrument, basis spread on variable rate			2.25%

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Long Term Debt - Senior Notes - Additional Information (Detail)				3 Months Ended
	Jan. 19, 2018 USD ($)	Jun. 14, 2012 USD ($) Covenant	Oct. 05, 2010 USD ($) Covenant	Mar. 31, 2019 USD ($)	Mar. 31, 2018 USD ($)	Dec. 31, 2018
Debt Instrument [Line Items]
Repayment of borrowings					$ 347,000,000
Proceeds from borrowings, before offering expenses					79,000,000
Interest expense related to amortization of debt issuance costs				$ 351,000	938,000
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]
Debt maturity date			Oct. 05, 2020
Long-term debt, aggregate principal amount			$ 300,000,000
Debt interest rate			4.97%
Semi-annual interest payment, first payment date				April 5
Semi-annual interest payment, second payment date				October 5
Notes issuance date			Oct. 05, 2010
Description of the prepayment terms				Notes are prepayable at the Company’s option, in whole or in part, provided that in the case of a partial prepayment, prepayment must be in an amount not less than 5% of the aggregate principal amount of the notes then outstanding, at any time and from time to time at 100% of the principal amount prepaid, plus accrued and unpaid interest to the prepayment date, plus a “make-whole” premium as specified in the note purchase agreements. The Company must offer to prepay the notes upon the occurrence of any change of control. In addition, the Company must offer to prepay the notes upon the occurrence of certain asset dispositions if the proceeds therefrom are not timely reinvested in productive assets. If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.
Debt instrument, redemption percentage			100.00%
Description of the acceptance terms				If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.
Acceptance terms, percent of principal before accrued and unpaid interest			100.00%
Number of compliance covenants | Covenant			2
Note purchase agreement, financial covenant description				The Company must not permit its debt to capitalization ratio to exceed 50% at any time. The note purchase agreements generally define the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit its interest coverage ratio as of the last day of a fiscal quarter to be less than 2.50 to 1.00. The note purchase agreements generally define the interest coverage ratio as the ratio of EBITDA for the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at March 31, 2019.
4.97% Series A Senior Notes, Due October 5th 2020 | Minimum
Debt Instrument [Line Items]
Debt instrument, prepayment percentage of aggregate principal amount			5.00%
Interest coverage ratio that the Company must exceed on the last day of the fiscal quarter			2.50%
4.97% Series A Senior Notes, Due October 5th 2020 | Maximum
Debt Instrument [Line Items]
Debt to capitalization ratio, percentage the Company must not exceed at any time			50.00%
4.27% Series B Senior Notes, Due June 14th 2022
Debt Instrument [Line Items]
Debt maturity date		Jun. 14, 2022
Long-term debt, aggregate principal amount		$ 300,000,000
Debt interest rate		4.27%
Semi-annual interest payment, first payment date				April 5
Semi-annual interest payment, second payment date				October 5
Notes issuance date		Jun. 14, 2012
Description of the prepayment terms				Notes are prepayable at the Company’s option, in whole or in part, provided that in the case of a partial prepayment, prepayment must be in an amount not less than 5% of the aggregate principal amount of the notes then outstanding, at any time and from time to time at 100% of the principal amount prepaid, plus accrued and unpaid interest to the prepayment date, plus a “make-whole” premium as specified in the note purchase agreements. The Company must offer to prepay the notes upon the occurrence of any change of control. In addition, the Company must offer to prepay the notes upon the occurrence of certain asset dispositions if the proceeds therefrom are not timely reinvested in productive assets. If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.
Debt instrument, redemption percentage		100.00%
Description of the acceptance terms				If any offer to prepay is accepted, the purchase price of each prepaid note is 100% of the principal amount thereof, plus accrued and unpaid interest thereon to the prepayment date.
Acceptance terms, percent of principal before accrued and unpaid interest		100.00%
Number of compliance covenants | Covenant		2
Note purchase agreement, financial covenant description				The Company must not permit its debt to capitalization ratio to exceed 50% at any time. The note purchase agreements generally define the debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the last day of the most recently ended fiscal quarter. The Company also must not permit its interest coverage ratio as of the last day of a fiscal quarter to be less than 2.50 to 1.00. The note purchase agreements generally define the interest coverage ratio as the ratio of EBITDA for the four prior fiscal quarters to interest charges for the same period. The Company was in compliance with these covenants at March 31, 2019.
4.27% Series B Senior Notes, Due June 14th 2022 | Minimum
Debt Instrument [Line Items]
Debt instrument, prepayment percentage of aggregate principal amount		5.00%
Interest coverage ratio that the Company must exceed on the last day of the fiscal quarter		2.50%
4.27% Series B Senior Notes, Due June 14th 2022 | Maximum
Debt Instrument [Line Items]
Debt to capitalization ratio, percentage the Company must not exceed at any time		50.00%
3.95% Senior Notes Due 2028
Debt Instrument [Line Items]
Debt maturity date	Feb. 01, 2028
Long-term debt, aggregate principal amount	$ 525,000,000
Debt interest rate	3.95%			3.95%		3.95%
Debt instrument, redemption percentage	100.00%
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 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 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date, plus a make-whole premium. Additionally, commencing on November 1, 2027, the Company, at its option, may redeem the 2028 Notes in whole or in part, at a redemption price equal to 100% of the principal amount of the 2028 Notes to be redeemed, plus accrued and unpaid interest, if any, on those 2028 Notes to the redemption date.
Debt instrument redemption upon the occurrence of change of control, description				Upon the occurrence of a change of control, as defined in the indenture, each holder of the 2028 Notes may require the Company to purchase all or a portion of such holder’s 2028 Notes at a price equal to 101% of their principal amount, plus accrued and unpaid interest, if any, to, but excluding, the repurchase date.
Redemption price percentage of principal amount of debt instrument on change of control	101.00%
Previous Credit Agreement
Debt Instrument [Line Items]
Interest expense related to amortization of debt issuance costs					$ 317,000

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Schedule of Principal Repayment Requirements of Long-Term Debt (Detail) $ in Thousands	Mar. 31, 2019 USD ($)
Debt Disclosure [Abstract]
2020	$ 300,000
2022	300,000
Thereafter	525,000
Total	$ 1,125,000

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Commitments and Contingencies - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019 USD ($) Plaintiff
Commitments and Contingencies Disclosure [Line Items]
Letters of credit, collateral for retrospective premiums and retained losses	$ 51,400,000
Commitments to purchase major equipment and investments	$ 89,900,000
Agreement expire description	The agreements expire in years 2019 through 2023.
Current obligation	$ 50,000,000
Purchase obligations for remainder of 2019	$ 22,300,000
Number of plaintiffs finalized for settlement alleging wrongful death lawsuits | Plaintiff	4
Letter of Credit
Commitments and Contingencies Disclosure [Line Items]
Amount drawn under letters of credit	$ 0

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Cash Dividends (Detail) - USD ($) $ / shares in Units, $ in Thousands	3 Months Ended		12 Months Ended
	Mar. 31, 2019	Mar. 31, 2018	Dec. 31, 2018
Dividends Payable [Line Items]
Cash dividends paid, per share	$ 0.04	$ 0.02	$ 0.14
Cash dividends paid	$ 8,499	$ 4,443	$ 30,589
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 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

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Stockholders' Equity - Additional Information (Detail) - USD ($)	Apr. 24, 2019	Mar. 31, 2019	Feb. 06, 2019	Jul. 25, 2018	Sep. 06, 2013
2013 program
Class Of Stock [Line Items]
Amount approved for repurchases under stock buyback program			$ 250,000,000	$ 250,000,000
Remaining amount approved for repurchases under stock buyback program		$ 175,000,000
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	Apr. 24, 2019
Dividend per share, declared	$ 0.04
Dividend payment date	Jun. 20, 2019
Dividend record date	Jun. 06, 2019

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Treasury Stock Acquisition (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Schedule of Treasury Stock [Line Items]
Treasury shares at beginning of period	53,701,096
Treasury shares at end of period	59,109,468
Treasury shares at beginning of period	$ 1,080,448
Treasury stock acquired, cost	75,113	$ 16,928
Treasury shares at end of period	$ 1,155,561
Stock Buyback Program
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, shares	5,408,132
Treasury stock acquired, cost	$ 75,110
Long Term Incentive Plan
Schedule of Treasury Stock [Line Items]
Treasury stock acquired, shares	240
Treasury stock acquired, cost	$ 3

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Stock-based Compensation - Additional Information (Detail) - shares	1 Months Ended	3 Months Ended
	Apr. 30, 2018	Mar. 31, 2019	Mar. 31, 2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Number of stock option granted		0	0
Performance Units Awards
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Performance period		3 years
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		Generally, the recipients will receive a target number of shares if the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 50th percentile. If the Company’s total shareholder return during the performance period, when compared to the peer group, is at the 75th percentile or higher, then the recipients will receive two times the target number of shares.

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Stock Option Activity (Detail)	3 Months Ended
	Mar. 31, 2019 $ / shares shares
Shares
Outstanding at beginning of period | shares	5,501,150
Exercised | shares	0
Expired | shares	0
Outstanding at end of period | shares	5,501,150
Exercisable at end of year | shares	5,432,679
Weighted Average Exercise Price Per Share
Outstanding at beginning of period | $ / shares	$ 19.63
Exercised | $ / shares	0
Expired | $ / shares	0
Outstanding at end of period | $ / shares	19.63
Exercisable at end of year | $ / shares	$ 19.64

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Restricted Stock Activity (Detail) - Restricted Stock Awards	3 Months Ended
	Mar. 31, 2019 $ / shares shares
Shares
Outstanding at beginning of period | shares	436,224
Vested | shares	(64,494)
Forfeited | shares	(1,033)
Outstanding at end of period | shares	370,697
Weighted Average Grant Date Fair Value Per Share
Outstanding at beginning of period | $ / shares	$ 21.41
Vested | $ / shares	20.61
Forfeited | $ / shares	21.71
Outstanding at end of period | $ / shares	$ 21.55

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Restricted Stock Unit Activity (Detail)	3 Months Ended
	Mar. 31, 2019 $ / shares shares
Time Based Restricted Stock Units
Shares
Outstanding at beginning of period	2,602,608
Granted	101,448
Vested	(38,615)
Forfeited	(46,738)
Outstanding at end of period	2,618,703
Performance Based Restricted Stock Units
Shares
Outstanding at beginning of period	435,315
Outstanding at end of period	435,315
Restricted Stock Units (RSUs)
Weighted Average Grant Date Fair Value Per Share
Outstanding at beginning of period | $ / shares	$ 18.95
Granted | $ / shares	10.35
Vested | $ / shares	22.95
Forfeited | $ / shares	19.23
Outstanding at end of period | $ / shares	$ 18.61

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Performance Units (Detail)	3 Months Ended
	Mar. 31, 2019 shares
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

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

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Compensation Expense Associated with Performance Units (Detail) - Performance Units Awards - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
2018
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	$ 667
2017
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	482	$ 482
2016
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units	$ 321	321
2015
Share Based Compensation Arrangement By Share Based Payment Award [Line Items]
Stock-based compensation expense associated with Performance Units		$ 338

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Income Taxes - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Income Tax Disclosure [Abstract]
Effective income tax rate	18.80%	(0.80%)

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Earnings Per Share - Calculation of Basic and Diluted Net Loss per Share (Detail) - USD ($) $ / shares in Units, shares in Thousands, $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
BASIC EPS:
Net loss attributed to common stockholders	$ (28,614)	$ (34,417)
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock	211,868	220,783
Basic net loss per common share	$ (0.14)	$ (0.16)
DILUTED EPS:
Net loss attributed to common stockholders	$ (28,614)	$ (34,417)
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock	211,868	220,783
Weighted average number of diluted common shares outstanding	211,868	220,783
Diluted net loss per common share	$ (0.14)	$ (0.16)
Potentially dilutive securities excluded as anti-dilutive	10,033	9,738

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Business Segments - Additional Information (Detail)	3 Months Ended
	Mar. 31, 2019 Segment
Segment Reporting [Abstract]
Number of reportable business segments	3

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Business Segments - Revenues (Detail) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues		$ 704,171	$ 809,164
Contract Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues		372,392	327,803
Pressure Pumping
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues		247,601	406,784
Directional Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues		52,959	48,616
Operating Segments | Contract Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues		372,743	328,153
Operating Segments | Pressure Pumping
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues		247,601	406,784
Operating Segments | Directional Drilling
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues		52,959	48,616
Other Operations
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues	[1]	35,391	29,653
Intersegment Elimination
Segment Reporting Revenue Reconciling Item [Line Items]
Total revenues	[2]	$ (4,523)	$ (4,042)

[1] Other operations includes the Company’s oilfield rentals business, pipe handling components and related technology business, the electrical controls and automation business, the oil and natural gas working interests and Middle East/North Africa 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.

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Business Segments - Income (Loss) Before Income Taxes (Detail) - USD ($) $ in Thousands		3 Months Ended
		Mar. 31, 2019	Mar. 31, 2018
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		$ (23,383)	$ (22,102)
Other operating income, net	[1]	8,736	2,421
Interest income		1,032	1,423
Interest expense		(12,984)	(13,625)
Other		117	169
Loss before income taxes		(35,218)	(34,135)
Corporate
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		(23,697)	(23,807)
Operating Segments | Contract Drilling
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		21,217	(17,103)
Operating Segments | Pressure Pumping
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		(18,768)	25,389
Operating Segments | Directional Drilling
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		(5,667)	(4,913)
Other Operations
Segment Reporting Reconciling Item For Operating Profit Loss From Segment To Consolidated [Line Items]
Operating income (loss)		$ (5,204)	$ (4,089)

[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.

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Business Segments - Depreciation, Depletion, Amortization and Impairment (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	$ 214,410	$ 209,892
Corporate
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	1,803	2,237
Operating Segments | Contract Drilling
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	130,317	130,917
Operating Segments | Pressure Pumping
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	60,135	56,522
Operating Segments | Directional Drilling
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	10,367	10,902
Other Operations
Segment Reporting Information [Line Items]
Depreciation, depletion, amortization and impairment	$ 11,788	$ 9,314

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Business Segments - Capital Expenditures (Detail) - USD ($) $ in Thousands	3 Months Ended
	Mar. 31, 2019	Mar. 31, 2018
Segment Reporting Information [Line Items]
Capital expenditures	$ 118,341	$ 122,921
Corporate
Segment Reporting Information [Line Items]
Capital expenditures	1,331	526
Operating Segments | Contract Drilling
Segment Reporting Information [Line Items]
Capital expenditures	75,725	75,247
Operating Segments | Pressure Pumping
Segment Reporting Information [Line Items]
Capital expenditures	31,400	24,923
Operating Segments | Directional Drilling
Segment Reporting Information [Line Items]
Capital expenditures	2,112	12,829
Other Operations
Segment Reporting Information [Line Items]
Capital expenditures	$ 7,773	$ 9,396

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Business Segments - Identifiable Assets (Detail) - USD ($) $ in Thousands		Mar. 31, 2019	Dec. 31, 2018
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		$ 5,367,752	$ 5,469,866
Corporate
Segment Reporting Asset Reconciling Item [Line Items]
Total assets	[1]	325,498	314,276
Operating Segments | Contract Drilling
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		3,725,627	3,817,638
Operating Segments | Pressure Pumping
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		894,357	921,237
Operating Segments | Directional Drilling
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		242,686	239,341
Other Operations
Segment Reporting Asset Reconciling Item [Line Items]
Total assets		$ 179,584	$ 177,374

[1] Corporate assets primarily include cash on hand and certain property and

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Estimated Fair Value of Outstanding Debt Balances (Detail) - USD ($) $ in Thousands	Mar. 31, 2019	Dec. 31, 2018
Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	$ 1,125,000	$ 1,125,000
Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	1,101,243	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	501,909	482,488
4.97% Series A Senior Notes, Due October 5th 2020 | Carrying Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	300,000	300,000
4.97% Series A Senior Notes, Due October 5th 2020 | Fair Value
Fair Value Balance Sheet Grouping Financial Statement Captions [Line Items]
Total debt	301,459	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	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	$ 297,875	$ 293,900

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Fair Values of Financial Instruments - Additional Information (Detail)	3 Months Ended	12 Months Ended
	Mar. 31, 2019	Dec. 31, 2018	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	4.65%	5.07%
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	4.63%	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	4.51%	4.92%