Patterson-UTI Energy 10Q 2023 Q3 Quarterly report

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 September 30, 2023


☐		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 1-39270

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)

Securities registered pursuant to Section 12(b) of the Act:


Title of each class	Trading Symbol	Name of each exchange on which registered
Common Stock, $0.01 Par Value	PTEN	The Nasdaq Global Select Market

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.

417,283,463 shares of common stock, $0.01 par value, as of November 3, 2023.

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 income (loss)	5
	Unaudited condensed consolidated statements of changes in stockholders’ equity	6
	Unaudited condensed consolidated statements of cash flows	8
	Notes to unaudited condensed consolidated financial statements	9
ITEM 2.	Management’s Discussion and Analysis of Financial Condition and Results of Operations	32
ITEM 3.	Quantitative and Qualitative Disclosures About Market Risk	46
ITEM 4.	Controls and Procedures	47

	PART II — OTHER INFORMATION

ITEM 1.	Legal Proceedings	48
ITEM 1A.	Risk Factors	48
ITEM 2.	Unregistered Sales of Equity Securities and Use of Proceeds	50
ITEM 5.	Other Information	51
ITEM 6.	Exhibits	52
Signature

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)


	September 30,			December 31,
	2023			2022
ASSETS
Current assets:
Cash, cash equivalents and restricted cash	$	67,048		$	137,553
Accounts receivable, net of allowance for credit losses of $2,600 and $2,875 at September 30, 2023 and December 31, 2022, respectively		1,010,034			565,520
Inventory		186,514			65,377
Other current assets		160,677			60,969
Total current assets		1,424,273			829,419
Property and equipment, net		3,388,002			2,260,576
Operating lease right of use asset		48,045			20,841
Finance lease right of use asset		57,139			—
Goodwill		1,372,997			—
Intangible assets, net		1,074,958			5,845
Deposits on equipment purchases		28,966			13,051
Other assets		18,497			10,881
Deferred tax assets, net		7,697			3,210
Total assets	$	7,420,574		$	3,143,823
LIABILITIES AND STOCKHOLDERS’ EQUITY
Current liabilities:
Accounts payable	$	579,724		$	237,056
Accrued liabilities		389,934			308,787
Operating lease liability		12,626			5,123
Finance lease liability		42,801			—
Current maturities of long-term debt		12,049			—
Total current liabilities		1,037,134			550,966
Long-term operating lease liability		38,895			19,594
Long-term finance lease liability		12,959			—
Long-term debt, net of debt discount and issuance costs of $8,801 and $5,468 at September 30, 2023 and December 31, 2022, respectively		1,228,209			830,937
Deferred tax liabilities, net		217,681			28,738
Other liabilities		26,082			48,065
Total liabilities	$	2,560,960			1,478,300
Commitments and contingencies (see Note 10)
Stockholders’ equity:
Preferred stock, par value $0.01; authorized 1,000,000 shares, no shares issued		—			—
Common stock, par value $0.01; authorized 800,000,000 and 400,000,000 shares with 515,844,897 and 302,325,853 issued and 417,303,286 and 213,567,131 outstanding at September 30, 2023 and December 31, 2022, respectively		5,158			3,023
Additional paid-in capital		6,395,867			3,202,973
Retained earnings (deficit)		28,921			(87,394	)
Accumulated other comprehensive loss		(656	)		—
Treasury stock, at cost, 98,541,611 and 88,758,722 shares at September 30, 2023 and December 31, 2022, respectively		(1,578,077	)		(1,453,079	)
Total stockholders’ equity attributable to controlling interests		4,851,213			1,665,523
Noncontrolling interest		8,401			—
Total equity		4,859,614			1,665,523
Total liabilities and stockholders’ equity	$	7,420,574		$	3,143,823

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

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF OPERATIONS

(unaudited, in thousands, except per share data)


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2023			2022			2023			2022
Operating revenues:
Drilling Services	$	488,775		$	418,025		$	1,456,161		$	1,083,329
Completion Services		459,574			287,664			1,003,083			715,630
Drilling Products		46,570			—			46,570			—
Other		16,533			21,814			56,325			60,157
Total operating revenues		1,011,452			727,503			2,562,139			1,859,116
Operating costs and expenses:
Drilling Services		279,927			279,232			842,761			741,317
Completion Services		368,869			211,704			785,458			560,627
Drilling Products		32,071			—			32,071			—
Other		10,591			9,685			31,912			28,789
Depreciation, depletion, amortization and impairment		197,635			122,150			452,629			360,641
Selling, general and administrative		45,102			28,472			108,925			82,012
Merger and integration expense		70,188			24			78,128			2,069
Other operating income, net		(2,635	)		(109	)		(9,994	)		(10,565	)
Total operating costs and expenses		1,001,748			651,158			2,321,890			1,764,890
Operating income		9,704			76,345			240,249			94,226

Other income (expense):
Interest income		2,131			58			4,583			87
Interest expense, net of amount capitalized		(15,625	)		(10,975	)		(34,189	)		(32,198	)
Other		(618	)		(1,774	)		3,191			(2,644	)
Total other expense		(14,112	)		(12,691	)		(26,415	)		(34,755	)

Income (loss) before income taxes		(4,408	)		63,654			213,834			59,471

Income tax expense (benefit)		(4,130	)		2,202			29,820			4,910

Net income (loss)		(278	)		61,452			184,014			54,561

Net loss attributable to noncontrolling interest		(328	)		—			(328	)		—

Net income attributable to common stockholders	$	50		$	61,452		$	184,342		$	54,561

Net income attributable to common stockholder per common share:
Basic	$	0.00		$	0.28		$	0.79		$	0.25
Diluted	$	0.00		$	0.28		$	0.79		$	0.25

Weighted average number of common shares outstanding:
Basic		280,218			216,822			233,631			216,090
Diluted		281,984			220,454			234,488			219,381
Cash dividends per common share	$	0.08		$	0.04		$	0.24		$	0.12

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

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF COMPREHENSIVE INCOME (LOSS)

(unaudited, in thousands)


	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2023			2022		2023			2022
Net income (loss)	$	(278	)	$	61,452	$	184,014		$	54,561
Other comprehensive income (loss):
Foreign currency translation adjustment, net of taxes of $0 for all periods		(656	)		—		(656	)		1,793
Release of cumulative translation adjustment, net of taxes of $0 and $3,770, into net income (loss) for three and nine months ended September 30, 2022		—			—		—			(7,708	)
Comprehensive income (loss)		(934	)		61,452		183,358			48,646
Less: comprehensive loss attributable to noncontrolling interest		(328	)		—		(328	)		—
Comprehensive income (loss) attributable to common stockholders	$	(606	)	$	61,452	$	183,686		$	48,646

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

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CHANGES IN STOCKHOLDERS’ EQUITY

(unaudited, in thousands)


	Common Stock				Additional			Retained			Accumulated Other
	Number of				Paid-in			(Deficit)			Comprehensive			Treasury			Noncontrolling
	Shares		Amount		Capital			Earnings			Loss			Stock			Interest			Total
Balance, December 31, 2022		302,326	$	3,023	$	3,202,973		$	(87,394	)	$	—		$	(1,453,079	)	$	—		$	1,665,523
Net income		—		—		—			99,678			—			—			—			99,678
Vesting of restricted stock units		89		1		(1	)		—			—			—			—			—
Stock-based compensation		—		—		(758	)		—			—			—			—			(758	)
Payment of cash dividends ($0.08 per share)		—		—		—			(16,916	)		—			—			—			(16,916	)
Dividend equivalents		—		—		—			(263	)		—			—			—			(263	)
Purchase of treasury stock		—		—		—			—			—			(74,307	)		—			(74,307	)
Balance, March 31, 2023		302,415	$	3,024	$	3,202,214		$	(4,895	)	$	—		$	(1,527,386	)	$	—		$	1,672,957
Net income		—		—		—			84,614			—			—			—			84,614
Issuance of restricted stock		1,001		10		(10	)		—			—			—			—			—
Vesting of restricted stock units		1,512		15		(15	)		—			—			—			—			—
Stock-based compensation		—		—		6,738			—			—			—			—			6,738
Payment of cash dividends ($0.08 per share)		—		—		—			(16,591	)		—			—			—			(16,591	)
Dividend equivalents		—		—		—			(229	)		—			—			—			(229	)
Purchase of treasury stock		—		—		—			—			—			(27,320	)		—			(27,320	)
Balance, June 30, 2023		304,928	$	3,049	$	3,208,927		$	62,899		$	—		$	(1,554,706	)	$	—		$	1,720,169
Net income (loss)		—		—		—			50			—			—			(328	)		(278	)
Noncontrolling interest		—		—		—			—			—			—			8,729			8,729
Foreign currency translation adjustment		—		—		—			—			(656	)		—			—			(656	)
Issuance of common stock - Ulterra acquisition		34,900		349		521,057			—			—			—			—			521,406
Issuance of common stock - NexTier merger		172,224		1,722		2,566,150			—			—			—			—			2,567,872
Issuance of replacement awards related to NexTier merger		—		—		72,413			—			—			—			—			72,413
Vesting of restricted stock units		3,793		38		(38	)		—			—			—			—			—
Stock-based compensation		—		—		27,358			—			—			—			—			27,358
Payment of cash dividends ($0.08 per share)		—		—		—			(33,217	)		—			—			—			(33,217	)
Dividend equivalents		—		—		—			(811	)		—			—			—			(811	)
Purchase of treasury stock		—		—		—			—			—			(23,371	)		—			(23,371	)
Balance, September 30, 2023		515,845	$	5,158	$	6,395,867		$	28,921		$	(656	)	$	(1,578,077	)	$	8,401		$	4,859,614




	Common Stock				Additional						Accumulated Other
	Number of				Paid-in			Retained			Comprehensive			Treasury
	Shares		Amount		Capital			Deficit			Income			Stock			Total
Balance, December 31, 2021		299,269	$	2,993	$	3,171,536		$	(198,316	)	$	5,915		$	(1,372,641	)	$	1,609,487
Net loss		—		—		—			(28,777	)		—			—			(28,777	)
Foreign currency translation adjustment		—		—		—			—			115			—			115
Vesting of restricted stock units		150		1		(1	)		—			—			—			—
Stock-based compensation		—		—		4,642			—			—			—			4,642
Payment of cash dividends ($0.04 per share)		—		—		—			(8,611	)		—			—			(8,611	)
Dividend equivalents		—		—		—			(144	)		—			—			(144	)
Purchase of treasury stock		—		—		—			—			—			(13	)		(13	)
Balance, March 31, 2022		299,419	$	2,994	$	3,176,177		$	(235,848	)	$	6,030		$	(1,372,654	)	$	1,576,699
Net income		—		—		—			21,886			—			—			21,886
Foreign currency translation adjustment		—		—		—			—			1,678			—			1,678
Release of cumulative translation adjustment		—		—		—			—			(7,708	)		—			(7,708	)
Issuance of restricted stock		980		10		(10	)		—			—			—			—
Vesting of restricted stock units		1,287		13		(13	)		—			—			—			—
Exercise of stock options		640		6		10,362			—			—			—			10,368
Stock-based compensation		—		—		5,162			—			—			—			5,162
Payment of cash dividends ($0.04 per share)		—		—		—			(8,652	)		—			—			(8,652	)
Dividend equivalents		—		—		—			(100	)		—			—			(100	)
Purchase of treasury stock		—		—		—			—			—			(23,252	)		(23,252	)
Balance, June 30, 2022		302,326	$	3,023	$	3,191,678		$	(222,714	)	$	—		$	(1,395,906	)	$	1,576,081
Net income		—		—		—			61,452			—			—			61,452
Stock-based compensation		—		—		5,656			—			—			—			5,656
Payment of cash dividends ($0.04 per share)		—		—		—			(8,673	)		—			—			(8,673	)
Dividend equivalents		—		—		—			(131	)		—			—			(131	)
Balance, September 30, 2022		302,326	$	3,023	$	3,197,334		$	(170,066	)	$	—		$	(1,395,906	)	$	1,634,385

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

PATTERSON-UTI ENERGY, INC. AND SUBSIDIARIES

CONDENSED CONSOLIDATED STATEMENTS OF CASH FLOWS

(unaudited, in thousands)


	Nine Months Ended
	September 30,
��	2023			2022
Cash flows from operating activities:
Net income	$	184,014		$	54,561
Adjustments to reconcile net income to net cash provided by operating activities:
Depreciation, depletion, amortization and impairment		452,629			360,641
Deferred income tax expense		22,323			930
Stock-based compensation		33,338			15,460
Net loss (gain) on asset disposals		427			(10,558	)
Gain on early debt extinguishment		(1,112	)		—
Other		(76	)		745
Changes in operating assets and liabilities:
Accounts receivable		45,207			(190,142	)
Inventory		(29,355	)		(18,061	)
Other current assets		(30,053	)		(2,214	)
Other assets		16,460			7,877
Accounts payable		(29,388	)		59,469
Accrued liabilities		(71,689	)		(50,067	)
Other liabilities		(39,443	)		34,606
Net cash provided by operating activities		553,282			263,247

Cash flows from investing activities:
Acquisitions, net of cash acquired - NexTier		(65,185	)		—
Acquisitions, net of cash acquired - Ulterra		(357,314	)		—
Purchases of property and equipment		(410,417	)		(317,553	)
Proceeds from disposal of assets		19,566			20,305
Other		(286	)		(2,404	)
Net cash used in investing activities		(813,636	)		(299,652	)

Cash flows from financing activities:
Purchases of treasury stock		(124,286	)		(12,897	)
Dividends paid		(66,724	)		(25,936	)
Proceeds from borrowings under revolving credit facility		420,000			90,000
Repayment of borrowings under revolving credit facility		(420,000	)		(90,000	)
Debt issuance costs		(1,953	)		—
Proceeds from issuance of senior notes		396,412			—
Repayment of senior notes		(7,837	)		—
Other		(7,301	)		—
Net cash provided by (used in) financing activities		188,311			(38,833	)
Effect of foreign exchange rate changes on cash, cash equivalents and restricted cash		1,538			449
Net decrease in cash, cash equivalents and restricted cash		(70,505	)		(74,789	)
Cash, cash equivalents and restricted cash at beginning of period		137,553			117,524
Cash, cash equivalents and restricted cash at end of period	$	67,048		$	42,735

Supplemental disclosure of cash flow information:
Net cash received (paid) during the period for:
Interest, net of capitalized interest of $1,350 in 2023 and $689 in 2022	$	(29,269	)		(31,332	)
Income taxes		(27,454	)		(1,166	)
Non-cash investing and financing activities:
Net (decrease) increase in payables for purchases of property and equipment	$	(10,083	)		14,175
Net decrease (increase) in deposits on equipment purchases		7,214			(7,556	)
Cashless exercise of stock options		—			10,368
Purchases of property and equipment through exchange of lease right of use asset		3,241			—
Derecognition of right of use asset		(3,241	)		—
Issuance of common stock for business combinations		3,161,691			—

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

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 and consolidating interest of a joint venture (collectively referred to herein as “we,” “us,” “our,” “ours” and like terms). All intercompany accounts and transactions have been eliminated. As used in these notes, “we,” “us,” “our,” “ours” and like terms refer 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. Certain immaterial prior year amounts have been reclassified to conform to current year presentation.

The U.S. dollar is the reporting currency and functional currency for most of our operations except certain of our foreign subsidiaries, which use their local currencies as their functional currency. Assets and liabilities of these foreign subsidiaries are translated into U.S. dollars using the exchange rates in effect as of the balance sheet date. The effects of exchange rate changes are reflected in accumulated other comprehensive income, which is a separate component of stockholders’ equity.

The unaudited interim condensed consolidated financial statements have been prepared by us 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 (“GAAP”) have been omitted pursuant to such rules and regulations, although we believe 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 GAAP have been included. The unaudited condensed consolidated balance sheet as of December 31, 2022, as presented herein, was derived from our audited consolidated balance sheet but does not include all disclosures required by GAAP. These unaudited condensed consolidated financial statements should be read in conjunction with the consolidated financial statements and related notes included in our Annual Report on Form 10-K/A for the fiscal year ended December 31, 2022 (our “Annual Report”). The results of operations for the three and nine months ended September 30, 2023 are not necessarily indicative of the results to be expected for the full year.

On August 14, 2023, we completed our acquisition (the “Ulterra acquisition”) of Ulterra Drilling Technologies, L.P. (“Ulterra”). Ulterra is a global provider of specialized drill bit solutions. On September 1, 2023, we completed our merger (the “NexTier merger”) with NexTier Oilfield Solutions Inc. (“NexTier”). NexTier is a predominately U.S. land-focused oilfield service company, with a diverse set of well completion and production services across a variety of active basins. See Note 2 for additional details on the acquisition and merger.

The unaudited condensed consolidated financial statements include the results of Ulterra from August 14, 2023 to September 30, 2023, and the results of NexTier from September 1, 2023 to September 30, 2023.

There have been no material changes to our critical accounting policies from those disclosed in our Annual Report, except as follows, which were principally driven by the acquisition of Ulterra and merger with NexTier:

Restricted cash — Restricted cash includes amounts restricted as cash collateral for the issuance of standby letters of credit.

The following table provides a reconciliation of cash and restricted cash reported within the condensed consolidated balance sheet that sum to the total of such amounts shown in the statement of cash flows for the nine months ended September 30, 2023 and 2022:


	Nine Months Ended
	September 30,
	2023		2022
Cash and cash equivalents	$	61,856	$	42,735
Restricted cash		5,192		—
Total cash, cash equivalents and restricted cash	$	67,048	$	42,735

Revenues — As a result of the Ulterra acquisition, our revenues now include a significant amount of rental revenue included within the new “Drilling products” segment. See Note 3 for details.

Goodwill — As a result of both the Ulterra acquisition and the NexTier merger, we have recognized goodwill. Goodwill from acquisitions is recorded as the excess of the consideration transferred plus the fair value of any non-controlling interest in the acquiree at the acquisition date over the fair values of the identifiable net assets acquired. Goodwill is considered to have an indefinite useful economic life and is not amortized. We assess impairment of goodwill at least annually or on an interim basis if events or circumstances indicate that the fair value of goodwill may have decreased below its carrying value. See Note 7.

Leases — In the third quarter of 2023, as part of the Ulterra acquisition and the NexTier merger we acquired several operating and finance leases. We inherited NexTier’s and Ulterra’s lease classifications as of the time of each respective acquisition. We have elected as an accounting policy election by class of underlying assets to not recognize assets or liabilities at the acquisition date for leases that had a remaining lease term of twelve months or less. This includes not recognizing an intangible asset if the terms of an operating lease are favorable relative to market terms or a liability if the terms are unfavorable relative to market terms. See Notes 2 and 13 for details.

For finance leases, we amortize the right-of-use asset on a straight-line basis over the earlier of the useful life of the right-of-use asset or the end of the lease term and record this amortization in depreciation and amortization expense in the condensed consolidated statements of operations. If available, we use the rate implicit in the lease at commencement date to discount the lease payments. If the implicit rate is not available, we use our incremental borrowing rate based on the information available at the commencement date in the determination of the present value of future lease payments. We include the term of any renewal option for the right-of-use asset and lease liability if it is reasonably certain that we will exercise the option. We also include the term of any termination option for the right-of-use asset and lease liability if it is not reasonably certain we will exercise the option. By our policy election, right-of-use assets and lease liabilities with an initial term of one year or less are not recognized for leasing arrangements, and non-lease and lease components are treated as a single lease component instead of bifurcating those components. For finance leases where we have determined we are reasonably certain to exercise a purchase option to acquire the underlying asset, we amortize the right-of-use asset over the lease term and record this amortization in “Depreciation, depletion, amortization and impairment” in the condensed consolidated statements of operations. We adjust the lease liability to reflect lease payments made during the period and interest incurred on the lease liability using the effective interest method. The incurred interest expense is recorded in “Interest expense” in the condensed consolidated statements of operations.

Change in Accounting Estimate — In the third quarter of 2023, we changed the estimated of useful lives of certain property and equipment within our completion services segment. The change in the estimated useful lives was necessitated by recent trends in increased intensity and pumping hours per day of certain components used in servicing larger jobs. We determined the estimated useful life of fluid ends is now less than one year, which results in these components no longer being capitalized to property and equipment but instead recorded to inventory and expensed as direct operating costs as they are consumed. Additionally, we shortened the estimated useful lives of certain other completions components that remain in property and equipment, which resulted in a decrease in the weighted average estimated useful lives of these assets from nine years to seven years. The effect of our change in estimated useful lives of these assets was a decrease in operating income of $24.2 million, a decrease in net income of $19.1 million for the three and nine months ended September 30, 2023 resulting in a decrease in basic and diluted earnings per share of $0.07 and $0.08 per share, respectively.

Recently Adopted Accounting Standards — In October 2021, the FASB issued an accounting standards update, which requires contract assets and contract liabilities (i.e., deferred revenue) acquired in a business combination to be recognized and measured by the acquirer on the acquisition date in accordance with ASC 606, Revenue from Contracts with Customers. Generally, this new guidance will result in the acquirer recognizing contract assets and contract liabilities at the same amounts recorded by the acquiree. Historically, such amounts were recognized by the acquirer at fair value in acquisition accounting. The amendments should be applied prospectively to acquisitions occurring on or after the effective date. The amendments in the update are effective for public business entities for fiscal years beginning after December 15, 2022, with early adoption permitted. We adopted this new guidance on January 1, 2023, and there was no material impact on our consolidated financial statements.

Recently Issued Accounting Standards — In March 2020, the FASB issued an accounting standards update to provide temporary optional expedients that simplify the accounting for contract modifications to existing debt agreements expected to arise from the market transition from LIBOR to alternative reference rates. The amendments in the update are effective as of March 12, 2020 through December 31, 2022 and may be applied to contract modifications from the beginning of an interim period that includes or is subsequent to March 12, 2020. In December 2022, the FASB issued an update, which deferred the sunset date to December 31, 2024. We do not expect this new guidance will have a material impact on our consolidated financial statements.

2. Business Combinations

Ulterra Drilling Technologies, L.P.

On August 14, 2023, we completed the Ulterra acquisition. Total consideration for the acquisition included the issuance of 34.9 million shares of our common stock and payment of approximately $376 million of cash, which based on the closing price of our common stock of $14.94 on August 14, 2023, valued the transaction at approximately $897 million.

The total fair value of the consideration transferred was determined as follows (in thousands, except stock price):


Shares of our common stock issued to Ulterra		34,900
Our common stock price on August 14, 2023	$	14.94
Common stock equity consideration	$	521,406
Plus net cash consideration (1)		375,740
Total consideration transferred	$	897,146

(1)

Net cash consideration included $370 million cash consideration as adjusted for customary purchase price adjustments set forth in the Ulterra merger agreement relating to cash, net working capital, indebtedness and transaction expenses of Ulterra as of the closing. The adjustment is subject to a post-closing target net working capital adjustment in accordance with the Ulterra merger agreement.

The acquisition has been accounted for as a business combination using the acquisition method. Under the acquisition method of accounting, the fair value of the consideration transferred is allocated to the tangible and intangible assets acquired and the liabilities assumed based on their estimated fair values as of the acquisition date.

The aggregate purchase price noted above was allocated to the major categories of assets acquired and liabilities assumed based on preliminary estimated fair values as of the date of the business combination. We applied significant judgment in estimating the fair value of assets acquired and liabilities assumed, which involved the use of significant estimates and assumptions with respect to future rig counts, estimated economic useful lives, operating and capital cost estimates, and a weighted average discount rate reflecting the cost of capital for market participants of 10.5%. The carrying amounts of cash and cash equivalents, accounts receivable, other assets, accounts payable and accrued liabilities approximate their fair values due to their nature or the short-term maturity of instruments. The remaining assets acquired and liabilities assumed are based on inputs that are not observable in the market and thus represent Level 3 inputs. The fair value of inventory and rental equipment was determined using a replacement cost approach. Intangible assets primarily consist of customer relationships and developed technology, the fair values of which were determined using an income approach. Property and equipment was valued using a combination of indirect cost and a market approach. Certain data necessary to complete the purchase price allocation is not yet available, including final tax returns that provide the underlying tax basis of Ulterra’s assets and liabilities. We will complete the purchase price allocation during the 12-month period following the acquisition date.


Assets acquired:
Cash and cash equivalents	$	18,426
Accounts receivable		68,467
Inventory (1)		36,313
Rental equipment (2)		109,055
Property and equipment		27,583
Intangible assets		313,000
Operating lease right of use asset		7,513
Finance lease right of use asset		5,228
Other assets		14,274
Total assets acquired		599,859

Liabilities assumed:
Accounts payable		23,258
Accrued liabilities		26,475
Operating lease liability		7,513
Finance lease liability		5,228
Deferred tax liabilities		82,851
Total liabilities assumed		145,325
Less: noncontrolling interest		(8,729	)
Net assets acquired		445,805
Goodwill		451,341
Total consideration transferred	$	897,146

(1)

We recorded an adjustment of $5.5 million to write-up acquired drill bits classified as inventory to estimated fair value. This adjustment will be recorded as direct operating expense as acquired drill bits are sold.

(2)

We recorded an adjustment of $74.4 million to write-up acquired drill bits classified as long-lived assets to estimated fair value. This adjustment will be depreciated as acquired drill bits are rented over a weighted-average estimated useful life of 7.5 runs.

The goodwill recognized in the acquisition represents the excess of the gross consideration transferred over the fair value of the underlying net tangible and identifiable intangible assets acquired and liabilities assumed. Goodwill of $451.3 million represents the potential for new growth opportunities internationally with the acquisition of Ulterra as well as the recognition of deferred taxes for the difference between the fair value of the assets acquired and liabilities assumed and the respective carry-over tax basis. Goodwill is not deductible for tax purposes. All of the goodwill was assigned to our Drilling Products segment. See Note 7.

Approximately $46.6 million of revenues and $6.6 million of net loss attributed to the Ulterra acquisition are included in the consolidated statements of operations for the period from the closing date on August 14, 2023 through September 30, 2023. During the nine months ended September 30, 2023, we incurred costs related to the Ulterra acquisition totaling $5.2 million, which are included in our consolidated statements of operations as “Merger and integration expense.”

A portion of the fair value consideration transferred has been provisionally assigned to identifiable intangible assets as follows:


	Fair Value		Weighted Average Useful Life
	(in thousands)		(in years)
Customer relationships	$	245,000		15
Trade name		16,000		11
Developed technology		52,000		8
Intangible assets	$	313,000

Pro Forma

The following pro forma condensed combined financial information was derived from our and Ulterra’s historical financial statements and gives effect to the acquisition as if it had occurred on January 1, 2022. The below information reflects pro forma adjustments based on available information and certain assumptions we believe are reasonable, including (i) adjustments related to the depreciation and amortization of the step up to fair value of $77.6 million for acquired intangibles, $74.4 million for acquired drill bits classified as long-lived assets, and $5.5 million for acquired drill bits classified as inventory, (ii) removal of $12.8 million of historical interest expense of the acquired entity and (iii) $7.9 million of tax benefit relating to the aforementioned pro forma adjustments.

The pro forma results of operations do not include any anticipated cost savings or other synergies that may result from the Ulterra acquisition nor do they include any estimated costs that will be incurred to integrate Ulterra operations. The pro forma results of operations include our merger and integration expense of $5.2 million as if they had been incurred in the first quarter of 2022.

The pro forma condensed combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the Ulterra acquisition taken place on January 1, 2022. Furthermore, the financial information is not intended to be a projection of future results. The following table summarizes our selected financial information on a pro forma basis (in thousands, except per share data):


	Three Months Ended					Nine Months Ended
	September 30,					September 30,
	2023			2022		2023		2022
	(Unaudited)
Revenues	$	1,052,282		$	824,902	$	2,785,279	$	2,135,922
Net income (loss)	$	(27,925	)	$	58,762	$	163,904	$	54,365

NexTier Oilfield Solutions Inc.

On September 1, 2023, we completed the NexTier merger. Under the terms of the merger agreement, NexTier became our wholly-owned subsidiary. Each share of NexTier common stock issued and outstanding immediately prior to the effective time of the merger was converted into the right to receive 0.752 shares of our common stock. Additionally, certain equity awards that were granted and outstanding under NexTier long-term incentive plans were assumed by us, and such equity awards were converted into equity awards in respect of our common stock in accordance with the merger agreement.

NexTier is a predominately U.S. land-focused oilfield service company, with a diverse set of well completion and production services across a variety of active basins.

The total fair value of the consideration transferred was determined as follows (in thousands, except exchange ratio and stock price):


Number of shares of NexTier common stock outstanding as of September 1, 2023		229,022
Multiplied by the exchange ratio		0.752
Number of shares of Patterson-UTI common stock issued in connection with the merger		172,224
Patterson-UTI common stock price on September 1, 2023	$	14.91
Common stock equity consideration		2,567,872
Acceleration of RSU awards		1,997
Fair value of replacement equity awards (1)		70,416
NexTier long-term debt repaid by Patterson-UTI		161,000
Consideration transferred	$	2,801,285

(1)

In connection with the merger, each of the share-based awards held by legacy NexTier employees were replaced with our share-based awards on the merger date. The fair value of the replacement awards has been allocated between each employee’s pre-combination and post-combination services. Amounts allocated to pre-combination services have been included as consideration transferred as part of the merger. See Note 12 for replacement awards details.

The transaction has been accounted for as a business combination using the acquisition method with Patterson-UTI determined to be the acquirer. Under the acquisition method of accounting, the fair value of the consideration transferred is allocated to the tangible and intangible assets acquired and the liabilities assumed based on their estimated fair values as of the acquisition date.

The aggregate purchase price noted above was allocated to the major categories of assets acquired and liabilities assumed based on preliminary estimated fair values as of the date of the business combination. We applied significant judgment in estimating the fair value of assets acquired and liabilities assumed, which involved the use of significant estimates and assumptions with respect to future rig counts, estimated economic useful lives, operating and capital cost estimates, and a weighted average discount rate reflecting the cost of capital for market participants of 14.0%. The carrying amounts of cash and cash equivalents, accounts receivable, inventory, other assets, accounts payable, accrued liabilities, and other liabilities approximate their fair values due to their nature or the short-term maturity of instruments. The remaining assets acquired and liabilities assumed are based on inputs that are not observable in the market and thus represent Level 3 inputs. The fair value of property and equipment was determined using a combination of replacement cost and indirect cost. Intangible assets were valued using an income approach. Certain data necessary to complete the purchase price

allocation is not yet available, including final tax returns that provide the underlying tax basis of NexTier’s assets and liabilities. We will complete the purchase price allocation during the 12-month period following the acquisition date.


Assets acquired:
Cash and cash equivalents	$	95,815
Accounts receivable		420,200
Inventory		71,930
Property and equipment (1)		1,045,610
Intangible assets		768,000
Operating lease right of use asset		19,091
Finance lease right of use asset		50,733
Other assets		84,677
Total assets acquired		2,556,056

Liabilities assumed:
Accounts payable		358,873
Accrued liabilities		130,597
Operating lease liability		19,091
Finance lease liability		50,733
Deferred tax liabilities		82,785
Long-term debt		22,533
Other liabilities		11,815
Total liabilities assumed		676,427
Net assets acquired		1,879,629
Goodwill		921,656
Total consideration transferred	$	2,801,285

(1)

We recorded an adjustment of $262.7 million to write-up acquired property and equipment to estimated fair value. This adjustment will be depreciated on a straight-line basis over a weighted average period of six years.

The goodwill recognized in the merger represents the excess of the gross consideration transferred over the fair value of the underlying net tangible and identifiable intangible assets acquired and liabilities assumed. Goodwill of $921.7 million largely consisted of the expected synergies and economies of scale from the combined operations of Patterson-UTI and NexTier as well as the recognition of deferred taxes for the difference between the fair value of the assets acquired and liabilities assumed and the respective carry-over tax basis. The goodwill is not deductible for tax purposes. All of the goodwill was assigned to our completion services segment. See Note 7.

Approximately $272.1 million of revenues and $9.6 million of net loss attributed to the NexTier merger are included in the consolidated statements of operations for the period from the closing date on September 1, 2023 through September 30, 2023. During the nine months ended September 30, 2023, we incurred costs related to the NexTier merger totaling $72.9 million, which are included in our consolidated statements of operations as “Merger and integration expense.”

A portion of the fair value consideration transferred has been provisionally assigned to identifiable intangible assets as follows:


	Fair Value		Weighted Average Useful Life
	(in thousands)		(in years)
Customer relationships	$	540,000		10
Trade name		85,000		10
Developed technology		143,000		8
Intangible assets	$	768,000

Pro Forma

The following pro forma condensed combined financial information was derived from our and NexTier's historical financial statements and gives effect to the acquisition as if it had occurred on January 1, 2022. The below information reflects pro forma adjustments based on available information and certain assumptions we believe are reasonable, including (i) adjustments related to the depreciation and amortization of the step up to fair value of $720.7 million for acquired intangibles and $262.7 million for acquired

property and equipment, (ii) removal of $17.7 million of historical interest expense of the acquired entity and (iii) $8.4 million of tax expense relating to the aforementioned pro forma adjustments.

The pro forma results of operations do not include any anticipated cost savings or other synergies that may result from the NexTier merger nor do they include any estimated costs that will be incurred to integrate NexTier operations. The pro forma results of operations include our merger and integration expense of $72.9 million.

The pro forma condensed combined financial information has been included for comparative purposes and is not necessarily indicative of the results that might have actually occurred had the NexTier merger taken place on January 1, 2022. Furthermore, the financial information is not intended to be a projection of future results. The following table summarizes our selected financial information on a pro forma basis (in thousands, except per share data):


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
	(Unaudited)
Revenues	$	1,589,056	$	1,623,513	$	5,020,507	$	4,233,081
Net income	$	69,256	$	140,250	$	625,020	$	45,461

3. Revenues

ASC Topic 606 Revenue from Contracts with Customers

Drilling Services and Completion Services — revenue is recognized based on our customers’ ability to benefit from our services in an amount that reflects the consideration we expect to receive in exchange for those services. This typically happens when the service is performed. The services we provide represent a series of distinct services, generally provided daily, that are substantially the same, with the same pattern of transfer to the customer. Because our customers benefit equally throughout the service period, generally measured in days, and our efforts in providing services are incurred relatively evenly over the period of performance, revenue is recognized as we provide services to the customer.

ASC Topic 842 Revenue from Equipment Rentals

Drilling Products Revenue — revenues are primarily generated from the rental of drilling equipment, comprised of drill bits and downhole tools. These arrangements provide the customer with the right to control the use of identified asset. Generally, the lease terms in such arrangements are for periods of two to three days and do not provide customers with options to purchase the underlying asset.

Other — we are a non-operating working interest owner of oil and natural gas properties primarily located in Texas and New Mexico. The ownership terms are outlined in joint operating agreements for each well between the operator of the well and the various interest owners, including us, who are considered non-operators of the well. We receive revenue each period for our 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.

Accounts Receivable and Contract Liabilities

Accounts receivable is our right to consideration once it becomes unconditional. Payment terms typically range from 30 to 60 days.

Accounts receivable balances were $957 million and $561 million as of September 30, 2023 and December 31, 2022, respectively. These balances do not include amounts related to our oil and gas working interests nor do they include amounts related to our lease revenues under Topic 842 as those contracts are excluded from Topic 606. Accounts receivable balances are included in “Accounts receivable” in our unaudited condensed consolidated balance sheets.

We do not have any significant contract asset balances. 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 reactivation or initial mobilization of newly constructed or upgraded rigs that were moved on location to the initial well site. These payments are allocated to the overall performance obligation and amortized over the initial term of the contract. Total contract liability balances were $23.7 million and $148 million as of September 30, 2023 and December 31, 2022, respectively. We recognized $135 million of revenue in the nine months ended September 30, 2023 that was included in the contract liability balance at the beginning of the period, of which the recognition of $28.9 million in the three months ended September 30, 2023 was due to deferred revenue from a customer prepayment, which became recognizable after the customer changed its drilling schedule. Revenue related to our contract liabilities balance is expected to be recognized through 2026. The $16.6 million current portion of our contract liability balance is included in “Accrued liabilities” and $7.1 million noncurrent portion of our contract liability balance is included in “Other liabilities” in our unaudited condensed consolidated balance sheets.

Contract Costs

Costs incurred for newly constructed rigs 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.

Remaining Performance Obligations

We maintain a backlog of commitments for contract drilling under term contracts, which we define as contracts with a duration of six months or more. Our contract drilling backlog in the United States as of September 30, 2023 was approximately $760 million. Approximately 24% of the total contract drilling backlog in the United States at September 30, 2023 is reasonably expected to remain at September 30, 2024. 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 commodity pricing or other related indices in effect at September 30, 2023. 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 notice for the rig to be placed on standby, our backlog calculation uses the standby rate for the period over which we expect to receive the standby rate. 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. Please see “Our Current Backlog of Contract Drilling Revenue May Decline and May Not Ultimately Be Realized, as Fixed-Term Contracts May in Certain Instances Be Terminated Without an Early Termination Payment” included in Item 1A of our Annual Report.

4. Inventory

Inventory consisted of the following at September 30, 2023 and December 31, 2022 (in thousands):


	September 30, 2023		December 31, 2022
Raw materials and supplies	$	152,732	$	63,008
Work-in-process		6,321		2,341
Finished goods		27,461		28
Inventory	$	186,514	$	65,377

5. Other Current Assets

Other current assets consisted of the following at September 30, 2023 and December 31, 2022 (in thousands):


	September 30, 2023		December 31, 2022
Federal and state income taxes receivable	$	20,814	$	399
Workers’ compensation receivable		32,249		34,632
Prepaid expenses		57,268		11,960
Refundable tax credit		11,083		10,914
Insurance claim receivable		9,749		—
Other		29,514		3,064
Other current assets	$	160,677	$	60,969

6. Property and Equipment

Property and equipment consisted of the following at September 30, 2023 and December 31, 2022 (in thousands):


	September 30, 2023			December 31, 2022
Equipment	$	8,492,234		$	7,551,099
Oil and natural gas properties		255,797			236,156
Buildings		251,503			175,212
Rental equipment		107,389			—
Land		38,676			23,610
Total property and equipment		9,145,599			7,986,077
Less accumulated depreciation, depletion, amortization and impairment		(5,757,597	)		(5,725,501	)
Property and equipment, net	$	3,388,002		$	2,260,576

Depreciation and depletion expense on property and equipment of approximately $188 million and $121 million was recorded in the three months ended September 30, 2023 and 2022, respectively. Depreciation and depletion expense on property and equipment of approximately $436 million and $356 million was recorded in the nine months ended September 30, 2023 and 2022, respectively.

We review our 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. We estimate future cash flows over the life of the respective assets or asset groupings in our assessment of impairment. These estimates of cash flows are based on historical cyclical trends in the industry as well as our 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. We recorded a $0.4 million and a $6.2 million impairment expense recorded in our oil and natural gas business during the three and nine months ended September 30, 2023, respectively. We recorded a $2.5 million and a $3.7 million impairment expense recorded in our oil and natural gas business during the three and nine months ended September 30, 2022, respectively.

7. Goodwill and Intangible Assets

Goodwill — Goodwill by operating segment as of September 30, 2023 and changes for the nine months then ended are as follows (in thousands):


	Completion		Drilling
	Services		Products		Total
Balance at beginning of period	$	—	$	—	$	—
Goodwill acquired		921,656		451,341		1,372,997
Balance at end of period	$	921,656	$	451,341	$	1,372,997

Goodwill is evaluated at least annually 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. Our reporting units for impairment testing are our operating segments. We determine 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, we 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 our intangible assets as of September 30, 2023 and December 31, 2022 (in thousands):


	September 30, 2023							December 31, 2022
	Gross					Net		Gross					Net
	Carrying		Accumulated			Carrying		Carrying		Accumulated			Carrying
	Amount		Amortization			Amount		Amount		Amortization			Amount
Customer relationships	$	785,866	$	(7,915	)	$	777,951	$	1,800	$	(1,071	)	$	729
Developed technology		202,772		(6,404	)		196,368		7,772		(3,773	)		3,999
Trade name		101,000		(1,083	)		99,917		—		—			—
Other		1,352		(630	)		722		1,450		(333	)		1,117
Intangible assets, net	$	1,090,990	$	(16,032	)	$	1,074,958	$	11,022	$	(5,177	)	$	5,845

Amortization expense on intangible assets of approximately $10.1 million and $0.3 million was recorded in the three months ended September 30, 2023 and 2022, respectively. Amortization expense on intangible assets of approximately $10.9 million and $1.0 million was recorded in the nine months ended September 30, 2023 and 2022, respectively.

8. Accrued Liabilities

Accrued liabilities consisted of the following at September 30, 2023 and December 31, 2022 (in thousands):


	September 30, 2023		December 31, 2022
Salaries, wages, payroll taxes and benefits	$	134,742	$	73,308
Workers’ compensation liability		73,830		67,853
Property, sales, use and other taxes		67,503		10,119
Insurance, other than workers’ compensation		11,692		3,644
Accrued interest payable		12,384		10,522
Deferred revenue		16,571		110,215
Federal and state income taxes payable		1,329		4,644
Accrued merger and integration expense		30,003		—
Other		41,880		28,482
Accrued liabilities	$	389,934	$	308,787

9. Long-Term Debt

Long-term debt consisted of the following at September 30, 2023 and December 31, 2022 (in thousands):


	September 30, 2023			December 31, 2022
3.95% Senior Notes Due 2028	$	482,505		$	488,505
5.15% Senior Notes Due 2029		344,895			347,900
7.15% Senior Notes Due 2033		400,000			—
Equipment Loans Due 2025		21,659			—
		1,249,059			836,405
Less deferred financing costs and discounts		(8,801	)		(5,468	)
Less current portion		(12,049	)		—
Total	$	1,228,209		$	830,937

Credit Agreement — On August 29, 2023, we entered into Amendment No. 4 to Amended and Restated Credit Agreement (the “Credit Agreement Amendment”), which amended our Amended and Restated Credit Agreement, dated as of March 27, 2018 (as amended, the “Credit Agreement”), by and among us, as borrower, Wells Fargo Bank, National Association, as administrative agent, letter of credit issuer, swing line lender and a lender and each of the other letter of credit issuers and lenders party thereto.

under the Credit Agreement and (ii) extended the maturity date for $85 million of revolving credit commitments of certain lenders under the Credit Agreement from March 27, 2025 to March 27, 2026. As a result, of the $600 million of revolving credit commitments under the Credit Agreement, the maturity date for $501.7 million of such commitments is March 27, 2026; the maturity date for $48.3 million of such commitments is March 27, 2025; and the maturity date for the remaining $50 million of such commitments is March 27, 2024.

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 $100 million and a swing line facility that, at any time outstanding, is limited to the lesser of $50 million and the amount of the swing line provider’s unused commitment. 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.

Loans under the Credit Agreement bear interest by reference, at our election, to the SOFR rate (subject to a 0.10% per annum adjustment) or base rate, in each case subject to a 0% floor. The applicable margin on SOFR 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 September 30, 2023, the applicable margin on SOFR rate loans was 1.75% and the applicable margin on base rate loans was 0.75%. A letter of credit fee is payable by us equal to the applicable margin for SOFR 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, which does not qualify for certain limited exceptions and is otherwise, in the aggregate with all other similar debt, in excess of Priority Debt (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 the ability of each of our subsidiaries to grant liens and on the ability of each of our non-guarantor subsidiaries to incur debt. If our credit rating is below investment grade at both Moody’s and S&P, we will become subject to a restricted payment covenant, which would generally 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. Restricted payments include, among other things, dividend payments, repurchases of our common stock, distributions to holders of our common stock or any other payment or other distribution to third parties on account of our or our subsidiaries’ equity interests. Our credit rating is currently investment grade at both credit rating agencies. The Credit Agreement also requires that our total debt to capitalization ratio, expressed as a percentage, not exceed 50% as of the last day of each fiscal quarter. The Credit Agreement generally defines the total debt to capitalization ratio as the ratio of (a) total borrowed money indebtedness to (b) the sum of such indebtedness plus consolidated net worth, with consolidated net worth determined as of the end of the most recently ended fiscal quarter. We were in compliance with these covenants at September 30, 2023.

As of September 30, 2023, we had no borrowings outstanding under our revolving credit facility. We had $2.5 million in letters of credit outstanding under the Credit Agreement at September 30, 2023 and, as a result, had available borrowing capacity of $597.5 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 September 30, 2023, we had $87.7 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 by us 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. A letter of credit fee is payable by us equal to 1.50% times the amount of outstanding letters of credit.

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, our payment obligations under the Reimbursement Agreement are jointly and severally guaranteed as to payment and not as to collection by our subsidiaries that from time to time guarantee payment under the Credit Agreement. None of our subsidiaries are currently required to guarantee payment under the Credit Agreement.

2028 Senior Notes, 2029 Senior Notes and 2033 Senior Notes — On January 19, 2018, we completed an offering of $525 million in aggregate principal amount of our 3.95% Senior Notes due 2028 (the “2028 Notes”). On November 15, 2019, we completed an offering of $350 million in aggregate principal amount of our 5.15% Senior Notes due 2029 (the “2029 Notes”). On September 13, 2023, we completed an offering of $400 million in aggregate principal amount of our 7.15% Senior Notes due 2033 (the “2033 Notes”). The net proceeds before offering expenses from the offering of the 2033 Notes were approximately $396 million, which we used 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.

We pay interest on the 2029 Notes on May 15 and November 15 of each year. The 2029 Notes will mature on November 15, 2029. The 2029 Notes bear interest at a rate of 5.15% per annum.

We pay interest on the 2033 Notes on April 1 and October 1 of each year. The 2033 Notes will mature on October 1, 2033. The 2033 Notes bear interest at a rate of 7.15% per annum.

The 2028 Notes, 2029 Notes and 2033 Notes (together, the “Senior Notes”) are our 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 Senior 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 Senior Notes will be structurally subordinated to the liabilities (including trade payables) of our subsidiaries that do not guarantee the Senior Notes. None of our subsidiaries are currently required to be a guarantor under the Senior Notes. If our subsidiaries guarantee the Senior Notes in the future, such guarantees (the “Guarantees”) will rank equally in right of payment with all of the guarantors’ future unsecured senior debt and senior in right of payment to all of the guarantors’ future subordinated debt. The Guarantees will be effectively subordinated to any of the guarantors’ future secured debt to the extent of the value of the assets securing such debt.

At our option, we may redeem the Senior Notes in whole or in part, at any time or from time to time at a redemption price equal to 100% of the principal amount of such Senior Notes to be redeemed, plus accrued and unpaid interest, if any, on those Senior Notes to the redemption date, plus a “make-whole” premium. Additionally, commencing on November 1, 2027, in the case of the 2028 Notes, on August 15, 2029, in the case of the 2029 Notes, and on July 1, 2033, in the case of the 2033 Notes, at our option, we may redeem the respective Senior Notes in whole or in part, at a redemption price equal to 100% of the principal amount of the Senior Notes to be redeemed, plus accrued and unpaid interest, if any, on those Senior Notes to the applicable redemption date.

The indentures pursuant to which the Senior Notes were issued include 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 indentures.

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

The indentures also provide 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 Senior Notes to become or to be declared due and payable.

Equipment Loans — As part of the NexTier merger, we assumed the obligations of NexTier Completions Solutions Inc. (“NCS”) under a Master Loan and Security Agreement (as amended, the “Master Agreement”) with Caterpillar Financial Services Corporation. The Master Agreement allows NCS to enter into secured equipment financing term loans from time to time (the “Equipment Loans”). The Equipment Loans may be drawn in multiple tranches, with each loan evidenced by a separate promissory note. The Master Agreement and the Equipment Loans contain customary affirmative and negative covenants, including limitations on further encumbrance of the collateral other than the applicable loans under the Master Agreement. The Equipment Loans bear interest at a rate of 5.25% per annum, and we pay interest on the 1st of each month. The Equipment Loans will mature on June 1, 2025. We were in compliance with these covenants at September 30, 2023.

Drilling Products Letters of Credit — As part of the Ulterra merger, we assumed letters of credit of $2.5 million outstanding with financial institutions providing for short-term borrowing capacity, overdraft protection and bonding requirements. We maintain these letters of credit primarily for the benefit of various insurance companies as collateral for retrospective premiums and retained losses that could become payable under terms of the underlying insurance contracts. These letters of credit expire annually at various times during the year and are typically renewed. As of September 30, 2023, no amounts had been drawn under the letters of credit.

Presented below is a schedule of the principal repayment requirements of long-term debt as of September 30, 2023 (in thousands):


Year ending December 31,
2023	$	2,973
2024		12,290
2025		6,396
2026		—
2027		—
2028		482,505
Thereafter		744,895
Total	$	1,249,059

10. Commitments and Contingencies

As of September 30, 2023, we maintained letters of credit in the aggregate amount of $92.7 million primarily for the benefit of various insurance companies as collateral for retrospective premiums and retained losses that 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 September 30, 2023, no amounts had been drawn under the letters of credit.

As of September 30, 2023, we had commitments to purchase major equipment totaling approximately $197 million.

Our completion services segment has entered into agreements to purchase minimum quantities of proppants and chemicals from certain vendors. As of September 30, 2023, the remaining minimum obligation under these agreements was approximately $34.5 million, of which approximately $14.2 million, $16.3 million, and $4.0 million relate to the remainder of 2023, 2024 and 2025, respectively.

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 or results of operations.

11. Stockholders’ Equity

Cash Dividend — On November 7, 2023, our Board of Directors approved a cash dividend on our common stock in the amount of $0.08 per share to be paid on December 15, 2023 to holders of record as of December 1, 2023. 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. Our Board of Directors may, without advance notice, reduce or suspend our dividend to improve our financial flexibility and position our company for long-term success. There can be no assurance that we will pay a dividend in the future.

Share Repurchases and Acquisitions — In September 2013, our Board of Directors approved a stock buyback program. In April 2023, our Board of Directors approved an increase of the authorization under the stock buyback program to allow for an aggregate of $300 million of future share repurchases. All purchases executed to date have been through open market transactions. Purchases under the buyback 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 September 30, 2023, we had remaining authorization to purchase approximately $281 million of our outstanding common stock under the stock buyback program. Shares of stock purchased under the buyback program are held as treasury shares.

Treasury stock acquisitions during the nine months ended September 30, 2023 were as follows (dollars in thousands):


	Shares		Cost

Treasury shares at January 1, 2023		88,758,722	$	1,453,079
Purchases pursuant to stock buyback program		7,426,044		93,276
Acquisitions pursuant to long-term incentive plans		2,356,845		31,722
Treasury shares at September 30, 2023		98,541,611	$	1,578,077

12. Stock-based Compensation

We use share-based payments to compensate employees and non-employee directors. We recognize the cost of share-based payments under the fair-value-based method. Share-based awards include equity instruments in the form of stock options or restricted stock units that have included service conditions and, in certain cases, performance conditions. Our share-based awards also include share-settled performance unit awards. Share-settled performance unit awards are accounted for as equity awards. In 2020, we granted performance-based cash-settled phantom units, which are accounted for as a liability classified award. We issue shares of common stock when vested stock options are exercised and after restricted stock units and share-settled performance unit awards vest.

The Patterson-UTI Energy, Inc. 2021 Long-Term Incentive Plan (the “2021 Plan”) was originally approved by our stockholders on June 3, 2021. Subject to stockholder approval, our Board of Directors approved an amendment to the 2021 Plan to increase the number of shares available for issuance under the 2021 Plan by 5.445 million shares (the “First Amendment”). On June 8, 2023, our stockholders approved the First Amendment. On September 1, 2023, in connection with the NexTier merger, our Board of Directors approved a second amendment to the 2021 Plan (the “Second Amendment,” and together with the First Amendment, the “Plan Amendments” and the 2021 Plan, as amended by the Plan Amendments, the “Plan”) to assume approximately 10 million shares previously reserved for issuance under the NexTier Oilfield Solutions Inc. Equity and Incentive Award Plan (the “NexTier Plan”). Following the Plan Amendments, the aggregate number of shares of Common Stock authorized for grant under the Plan is approximately 28.9 million.

On September 1, 2023, the Board of Directors also approved amendments to the NexTier Plan and the NexTier Oilfield Solutions Inc. (Former C&J Energy) Management Incentive Plan (the “Former C&J Energy Plan” and, together with the NexTier Plan, the “Assumed Plans”) to assume awards that were previously granted under the Assumed Plans (consisting of stock options, time- and performance-based restricted stock units and cash-settled performance unit awards), which, in connection with the NexTier merger, were converted into equity awards in respect of shares of Patterson-UTI common stock.

Stock Options — We estimate the grant date fair values of stock options using the Black-Scholes-Merton valuation model. Volatility assumptions are based on the historic volatility of our 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 our 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 nine months ended September 30, 2023.

Stock option activity from January 1, 2023 to September 30, 2023 follows:


				Weighted
				Average
	Underlying			Exercise Price
	Shares			Per Share
Outstanding at January 1, 2023		2,905,150		$	22.19
Granted		—		$	—
Assumed (1)		652,573		$	27.97
Exercised		—		$	—
Expired		(662,500	)	$	22.70
Outstanding at September 30, 2023		2,895,223		$	23.38
Exercisable at September 30, 2023		2,895,223		$	23.38

(1)

Awards assumed in connection with the NexTier merger.

Restricted Stock Units (Equity Based) — 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. We use the straight-line method to recognize periodic compensation cost over the vesting period.

Restricted stock unit activity from January 1, 2023 to September 30, 2023 follows:


						Weighted
						Average Grant
	Time			Performance		Date Fair Value
	Based			Based		Per Share
Non-vested restricted stock units outstanding at January 1, 2023		3,090,846			359,315	$	12.71
Granted		1,675,657			—	$	11.32
Assumed (1)		7,438,031			—	$	5.62
Vested		(5,396,107	)		—	$	6.48
Forfeited		(84,739	)		—	$	13.82
Non-vested restricted stock units outstanding at September 30, 2023		6,723,688			359,315	$	9.47

(1)

Awards assumed in connection with the NexTier merger.

As of September 30, 2023, we had unrecognized compensation cost related to our unvested restricted stock units totaling $58.1 million. The weighted-average remaining vesting period for these unvested restricted stock units was 1.58 years as of September 30, 2023.

Restricted Stock Units (Liability Based) — We converted NexTier’s cash-settled performance based units into our cash-settled restricted stock units in connection with the NexTier merger. These awards are accounted for as liability classified awards and remeasured at fair value at each reporting period. Compensation expense is recorded over the vesting period and is initially based on the fair value at the award conversion date. Compensation expense is subsequently remeasured at each reporting date during the vesting period based on the change in our stock price. Dividend cash equivalents are not paid on cash-settled units. As of September 30, 2023, $8.4 million is included in “Other Liabilities” in our unaudited condensed consolidated balance sheets. We recognized $3.4 million of compensation expense for these awards during the three and nine months ended September 30, 2023.

Performance Unit Awards — We have 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 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 generally the three-year period commencing on April 1 of the year of grant.

The performance goals for the Performance Units are tied to our total shareholder return for the performance period as compared to total shareholder return for a peer group determined by the Compensation Committee. For the performance units granted in April 2022 and April 2021, the peer group includes one market index and three market indices, respectively. The performance 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. The recipients will receive the target number of shares if our total shareholder return during the performance period, when compared to the peer group, is at the 55th percentile. If our total shareholder return during the performance period, when compared to the peer group, is at the 75th percentile or higher, then the recipients will receive two times the target number of shares. If our total shareholder return during the performance period, when compared to the peer group, is at the 25th percentile, then the recipients will only receive one-half of the target number of shares. If our total shareholder return during the performance period, when compared to the peer group, is between the 25th and 55th percentile, or the 55th and 75th percentile, then the shares to be received by the recipients will be determined using linear interpolation for levels of achievement between these points.

The payout under the Performance Units shall not exceed the target number of shares if our absolute total shareholder return is negative or zero.

The total target number of shares with respect to the Performance Units for the awards granted in 2019-2023 is set forth below:


	2023		2022		2021		2020		2019
	Performance		Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards		Unit Awards
Target number of shares		631,700		414,000		843,000		500,500		489,800

In April 2022, 979,600 shares were issued to settle the 2019 Performance Units. In May 2023, 1,001,000 shares were issued to settle the 2020 Performance Units. The Performance Units granted in 2021, 2022 and 2023 have not reached the end of their respective performance periods.

Because the Performance Units are share-settled awards, they are accounted for as equity awards and measured at fair value on the date of grant using a Monte Carlo simulation model. The fair value of the Performance Units is set forth below (in thousands):


	2023		2022		2021		2020		2019
	Performance		Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards		Unit Awards
Aggregate fair value at date of grant	$	8,440	$	10,743	$	7,225	$	826	$	9,958

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):


	2023		2022		2021		2020		2019
	Performance		Performance		Performance		Performance		Performance
	Unit Awards		Unit Awards		Unit Awards		Unit Awards		Unit Awards
Three months ended September 30, 2023	$	903	$	990	$	617	N/A		N/A
Three months ended September 30, 2022	N/A		$	895	$	602	$	69	N/A
Nine months ended September 30, 2023	$	1,372	$	2,781	$	1,821	$	69	N/A
Nine months ended September 30, 2022	N/A		$	1,791	$	1,806	$	206	$	830

As of September 30, 2023, we had unrecognized compensation cost related to our unvested Performance Units totaling $13.5 million. The weighted-average remaining vesting period for these unvested Performance Units was 1.39 years as of September 30, 2023.

Phantom Units — In May 2020, the Compensation Committee approved a grant of long-term performance-based phantom units to our Chief Executive Officer and President, William A. Hendricks, Jr. (the “Phantom Units”). The Phantom Units settled in May 2023, with a cash payment of $7.4 million, which was determined by multiplying 597,000 earned phantom units by our average trading price per share over the twenty consecutive trading days preceding March 31, 2023.

13. Leases

ASC Topic 842 Leases

We acquired $7.5 million and $19.1 million of operating leases for operating locations, corporate offices, certain operating equipment and light duty vehicles primarily related to the Ulterra acquisition and NexTier merger, respectively.

We acquired $5.2 million and $50.7 million of finance leases for light duty vehicles and certain operating equipment related to the Ulterra acquisition and NexTier merger, respectively.

Lease expense consisted of the following for the three and nine months ended September 30, 2023 and 2022 (in thousands):


	Three Months Ended				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
Operating lease cost	$	2,419	$	1,410	$	5,302	$	4,288
Finance lease cost:
Amortization of right-of-use assets		1,613		—		1,613		—
Interest on lease liabilities		341		—		341		—
Total finance lease cost		1,954		—		1,954		—
Short-term lease expense (1)		1,734		—		1,734		—
Total lease expense (2)	$	6,107	$	1,410	$	8,990	$	4,288

(1)

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

(2)

Total lease expense is recorded in operating costs for the respective segments and within “selling, general and administrative” in our unaudited condensed consolidated statements of operations.

Supplemental cash flow information related to leases for the nine months ended September 30, 2023 and 2022 is as follows (in thousands):


	Nine Months Ended
	September 30,
	2023		2022
Cash paid for amounts included in the measurement of lease liabilities:
Operating cash flows from operating leases	$	4,902	$	5,485
Operating cash flows from finance leases		326		—
Financing cash flows from finance leases		2,986		—

Right of use assets obtained in exchange for lease obligations:
Operating leases (1)	$	31,654	$	6,470
Finance leases (1)		58,774		—

(1)

Includes right of use assets acquired in business combinations.

Supplemental balance sheet information related to leases as of September 30, 2023 and December 31, 2022 is as follows:



	September 30, 2023	December 31, 2022
Weighted Average Remaining Lease Term:
Operating leases	5.2 years	6.1 years
Finance leases	0.8 years	N/A

Weighted Average Discount Rate:
Operating leases	6.1%	4.1%
Finance leases	7.3%	N/A

Maturities of operating and finance lease liabilities as of September 30, 2023 are as follows (in thousands):


Year ending December 31,	Operating			Finance
2023 (excluding the nine months ended September 30, 2023)	$	3,432		$	14,969
2024		15,173			36,564
2025		12,112			3,249
2026		8,585			3,365
2027		6,652			—
2028		4,911
Thereafter		9,322			—
Total lease payments		60,187			58,147
Less imputed interest		(8,666	)		(2,387	)
Total	$	51,521		$	55,760

14. 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, the impact of U.S. state and local taxes, the realizability of deferred tax assets and other differences related to the recognition of income and expense between GAAP and tax accounting.

Our effective income tax rate for the three months ended September 30, 2023 was 93.7%, compared with 3.5% for the three months ended September 30, 2022. The difference in effective income tax rates was primarily attributable to the impact of valuation allowances on deferred tax assets between periods.

Our effective income tax rate for the nine months ended September 30, 2023 was 13.9%, compared with 8.3% for the nine months ended September 30, 2022. The difference in effective income tax rates was primarily attributable to the impact of valuation allowances on deferred tax assets between periods.

In assessing the realizability of deferred tax assets, management considers whether it is more likely than not that some portion or all of the deferred tax assets will not be realized, and when necessary, valuation allowances are provided. The ultimate realization

of deferred tax assets is dependent upon the generation of future taxable income during the periods in which those temporary differences become deductible. We assess the realizability of our deferred tax assets quarterly and consider carryback availability, the scheduled reversal of deferred tax liabilities, projected future taxable income and tax planning strategies in making this assessment.

We continue to monitor income tax developments in the United States and other countries where we have legal entities. We will incorporate into our future financial statements the impacts, if any, of future regulations and additional authoritative guidance when finalized.

15. Earnings Per Share

We provide a dual presentation of our net income (loss) per common share in our unaudited condensed consolidated statements of operations: basic net income (loss) per common share (“Basic EPS”) and diluted net income (loss) per common share (“Diluted EPS”).

Basic EPS excludes dilution and is determined by dividing the earnings attributable to common stockholders by the weighted average number of common shares outstanding during the period.

Diluted EPS is based on the weighted average number of common shares outstanding plus the dilutive effect of potential common shares, including stock options and non-vested performance units and non-vested restricted stock units. The dilutive effect of stock options, non-vested performance units and non-vested restricted stock units is determined using the treasury stock method.

The following table presents information necessary to calculate net income (loss) per share for the three and nine months ended September 30, 2023 and 2022 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				Nine Months Ended
	September 30,				September 30,
	2023		2022		2023		2022
BASIC EPS:
Net income attributable to common stockholders	$	50	$	61,452	$	184,342	$	54,561
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock		280,218		216,822		233,631		216,090
Basic net income per common share	$	0.00	$	0.28	$	0.79	$	0.25

DILUTED EPS:
Net income attributable to common stockholders	$	50	$	61,452	$	184,342	$	54,561
Weighted average number of common shares outstanding, excluding non-vested shares of restricted stock		281,984		220,454		234,488		219,381
Diluted net income per common share	$	0.00	$	0.28	$	0.79	$	0.25
Potentially dilutive securities excluded as anti-dilutive		3,268		3,359		10,351		3,359

16. Business Segments

Effective as of the third quarter of 2023, we revised our reportable segments to align with certain changes in how our Chief Operating Decision Maker (“CODM”) manages and allocates resources to our business as a result of the Ulterra acquisition and NexTier merger. Accordingly, we now have the following reportable business segments: (i) drilling services, (ii) completions services, and (iii) drilling products.

Drilling Services — represents our contract drilling, directional drilling, oilfield technology and electrical controls and automation businesses.

Completion Services — represents the combination of our well completion business, which includes hydraulic fracturing, wireline and pumping, completion support, cementing and our legacy pressure pumping business.

Drilling Products — represents our manufacturing and distribution of drill bits business, which was acquired with our acquisition of Ulterra on August 14, 2023.

This segment structure reflects the financial information and reports used by management, specifically including our CODM, to make decisions regarding the businesses, including performance evaluation and resource allocation decisions. As a result of the revised reportable segment structure, we have restated the corresponding items of segment information for all periods presented.

The following tables summarize selected financial information relating to our business segments (in thousands):


	Three Months Ended						Nine Months Ended
	September 30,						September 30,
	2023			2022			2023			2022
Revenues:
Drilling Services	$	503,767		$	428,242		$	1,496,520		$	1,109,234
Completion Services		459,574			287,664			1,003,083			715,630
Drilling Products		46,570			—			46,570			—
Other(1)		17,501			22,079			59,393			60,836
Elimination of intercompany revenues - Drilling Services (2)		(14,992	)		(10,217	)		(40,359	)		(25,905	)
Elimination of intercompany revenues - Other (2)		(968	)		(265	)		(3,068	)		(679	)
Total revenues	$	1,011,452		$	727,503		$	2,562,139		$	1,859,116

Income (loss) before income taxes:
Drilling Services	$	114,737		$	46,530		$	329,322		$	68,629
Completion Services		162			48,949			69,898			75,461
Drilling Products		(6,240	)		—			(6,240	)		—
Other		435			3,983			1,811			10,297
Corporate		(99,390	)		(23,117	)		(154,542	)		(60,161	)
Interest income		2,131			58			4,583			87
Interest expense		(15,625	)		(10,975	)		(34,189	)		(32,198	)
Other		(618	)		(1,774	)		3,191			(2,644	)
Income (loss) before income taxes	$	(4,408	)	$	63,654		$	213,834		$	59,471

Depreciation, depletion, amortization and impairment:
Drilling Services	$	90,668		$	88,199		$	272,361		$	262,955
Completion Services		83,338			24,746			135,339			73,244
Drilling Products		17,075			—			17,075			—
Other		5,319			7,920			21,946			20,495
Corporate		1,235			1,285			5,908			3,947
Total depreciation, depletion, amortization and impairment	$	197,635		$	122,150		$	452,629		$	360,641

Capital expenditures:
Drilling Services	$	89,242		$	72,683		$	261,155		$	181,754
Completion Services		56,464			46,653			107,529			114,669
Drilling Products		7,940			—			7,940			—
Other		5,972			6,457			18,387			19,654
Corporate		804			562			15,406			1,476
Total capital expenditures	$	160,422		$	126,355		$	410,417		$	317,553


	September 30, 2023		December 31, 2022
Identifiable assets:
Drilling Services	$	2,345,942	$	2,348,177
Completion Services		3,940,742		541,975
Drilling Products		1,038,772		—
Other		57,782		64,018
Corporate (3)		37,336		189,653
Total assets	$	7,420,574	$	3,143,823

(1)

Other includes our oilfield rentals business and oil and natural gas working interests.

(2)

Intercompany revenues consist of revenues from drilling services provided to our other operations, and revenues from other operations for services provided to drilling services, completion services and within other operations. These revenues are generally based on estimated external selling prices and are eliminated during consolidation.

(3)

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

17. Fair Values of Financial Instruments

The carrying values of cash, cash equivalents and restricted cash, 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 our outstanding debt balances as of September 30, 2023 and December 31, 2022 is set forth below (in thousands):


	September 30, 2023				December 31, 2022
	Carrying		Fair		Carrying		Fair
	Value		Value		Value		Value
3.95% Senior Notes Due 2028	$	482,505	$	433,313	$	488,505	$	431,556
5.15% Senior Notes Due 2029		344,895		314,329		347,900		313,164
7.15% Senior Notes Due 2033		400,000		414,880		—		—
Equipment Loans Due 2025		21,659		21,595		—		—
Total debt	$	1,249,059	$	1,184,117	$	836,405	$	744,720

The fair values of the 2028 Notes, the 2029 Notes and the 2033 Notes at September 30, 2023 and December 31, 2022 are based on quoted market prices, which are considered Level 1 fair value estimates in the fair value hierarchy of fair value accounting. The fair value of the Equipment Loans is based on 5.25%, which is considered Level 2 fair value estimates in the fair value hierarchy of fair value accounting. The fair values of the 2028 Notes implied a 6.70% market rate of interest at September 30, 2023 and a 6.69% market rate of interest at December 31, 2022, based on their quoted market prices. The fair values of the 2029 Notes implied a 6.94% market rate of interest at September 30, 2023 and a 7.01% market rate of interest at December 31, 2022, based on their quoted market prices. The fair values of the 2033 Notes implied a 7.08% market rate of interest at September 30, 2023, based on their quoted market price. The fair value of the Equipment Loans implied a 6.21% market rate of interest at September 30, 2023, based on their benchmark yield.

SPECIAL NOTE REGARDING FORWARD-LOOKING STATEMENTS

This Quarterly Report on Form 10-Q (this “Report”) and other public filings, press releases and presentations 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, “we,” “us,” “our,” “ours” 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, cost and margin expectations and backlog; financing of operations; oil and natural gas prices; rig counts and frac spreads; source and sufficiency of funds required for building new equipment, upgrading existing equipment and acquisitions (if opportunities arise); demand and pricing for our services; competition; equipment availability; government regulation; legal proceedings; debt service obligations; impact of inflation and economic downturns; 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 relate to:

•

the expected benefits of the recently completed merger (the “NexTier merger”) with NexTier Oilfield Solutions Inc. (“NexTier”) and the acquisition (the “Ulterra acquisition”) of Ulterra Drilling Technologies, L.P. (“Ulterra”) on our financial condition, results of operations, strategy and plans and our ability to realize those benefits;

•

synergies, costs and other anticipated financial impacts of the NexTier merger and the Ulterra acquisition;

•

the successful integration of NexTier and Ulterra operations and the future financial and operating results of the combined company;

•

the combined company’s plans, objectives, expectations and intentions with respect to future operations and services;

•

adverse oil and natural gas industry conditions;

•

global economic conditions, including inflationary pressures and risks of economic downturns or recessions in the United States and elsewhere;

•

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, completions services and drilling equipment, including as a result of reactivation, improvement or construction;

•

competition and demand for our services;

•

the impact of the ongoing war in Ukraine and instability in other international regions;

•

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, including the ability to develop and obtain satisfactory returns from new technology;

•

the ability to retain management and field personnel;

•

loss of key customers;

•

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

•

cybersecurity events;

•

synergies, costs and financial and operating impacts of acquisitions;

•

difficulty in building and deploying new equipment;

•

governmental regulation;

•

climate legislation, regulation and other related risks;

•

environmental, social and governance practices, including the perception thereof;

•

environmental risks and ability to satisfy future environmental costs;

•

technology-related disputes;

•

legal proceedings and actions by governmental or other regulatory agencies;

•

the ability to effectively identify and enter new markets;

•

public health crises, pandemics and epidemics;

•

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;

•

adverse credit and equity market conditions;

•

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

•

our return of capital to stockholders;

•

stock price volatility;

•

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 SEC.

We caution that the foregoing list of factors is not exhaustive. Additional information concerning these and other risk factors is contained elsewhere in this Report and in our Annual Report on Form 10-K for the year ended December 31, 2022 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.

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

Management Overview — We are a Houston, Texas-based leading provider of drilling and completion services to oil and natural gas exploration and production companies in the United States and other select countries, including contract drilling services, integrated well completions services and directional drilling services in the United States, and specialized drill bit solutions in the United States, Middle East and many other regions around the world. We operate under three reportable business segments: (i) drilling services, (ii) completion services, and (iii) drilling products.

Drilling Services

Our contract drilling business operates in the continental United States and internationally in Colombia and, from time to time, we pursue contract drilling opportunities in other select markets. 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 wellbore placement for directional and horizontal wells. We also service equipment for drilling contractors, and we provide electrical controls and automation to the energy, marine and mining industries, in North America and other select markets.

We have addressed our customers’ needs for drilling horizontal wells in shale and other unconventional resource plays by improving the capabilities of our drilling fleet. The U.S. land rig industry has in recent years referred to certain high specification rigs as “super-spec” rigs, which we consider to be at least a 1,500 horsepower, AC-powered rig that has at least a 750,000-pound hookload, a 7,500-psi circulating system, and is pad-capable. Due to evolving customer preferences, we refer to certain premium rigs as “Tier-1, super spec” rigs, which we consider as being a super-spec rig that also has a third mud pump and raised drawworks that allow for more clearance underneath the rig floor. As of September 30, 2023, our rig fleet included 173 super-spec rigs, of which 131 were Tier-1, super-spec rigs.

Completion Services

Our well completion services business consists of services for hydraulic fracturing, wireline and pumping, completion support, and cementing. It also includes our power solutions natural gas fueling business, our proppant last mile logistics and storage business and our research and technology department. Our completion services business operates in several of the most active basins in the continental United States including the Permian, the Marcellus Shale/Utica, the Eagle Ford, Mid-Continental, Haynesville, and the Bakken/Rockies. The high density of our operations in the basins in which we are most active provides us the opportunity to leverage our fixed costs and to quickly respond with what we believe are highly efficient, integrated solutions that are best suited to address customer requirements.

Drilling Products

We serve the energy and mining markets by manufacturing and distributing drill bits through North America and internationally in over 30 countries. Our drilling equipment is used in oil and gas exploration and production and in mining operations. We have manufacturing facilities located in Fort Worth, Texas, Leduc, Alberta and Saudi Arabia and repair facilities located in Argentina, Colombia, Oman and Saudi Arabia.

Other

Other consists of our oilfield rentals business, with a fleet of premium oilfield rental tools, along with the results of our ownership, as a non-operating working interest owner, in oil and gas assets located in Texas and New Mexico.

Recent Developments in Market Conditions and Outlook — Crude oil prices and demand for drilling and completions equipment and services increased in 2022, and industry supply of Tier-1, super-spec rigs became constrained. Commodity price volatility in the second quarter of 2023 resulted in a decline in industry activity; however, commodity prices increased during the third quarter. The current demand for equipment and services remains dependent on macro conditions, including commodity prices, geopolitical environment, inflationary pressures, economic conditions in the United States and elsewhere and continued customer consolidation and focus by exploration and production companies and service companies on capital discipline. Oil prices reached a low of $69.71 per barrel and averaged $82.25 per barrel in the third quarter of 2023, as compared to $73.54 per barrel in the second quarter of 2023. Natural gas prices (based on the Henry Hub Spot Market Price) averaged $2.59 per MMBtu in the third quarter of 2023 as compared to an average of $2.16 per MMBtu in the second quarter of 2023.

Our average active rig count in the United States for the third quarter of 2023 was 120 rigs. This was a decrease from our average active rig count for the second quarter of 2023 of 128. We expect our rig count in the United States will average approximately 118 rigs during the fourth quarter. Based on contracts in place in the United States as of November 7, 2023, we expect an average of 74 rigs operating under term contracts during the fourth quarter of 2023 and an average of 52 rigs operating under term contracts during the four quarters ending September 30, 2024.

Our completion services business was impacted by calendar inefficiencies during the third quarter of 2023, with customer activity slowing more towards the end of the quarter. Completion services activity has stabilized in the fourth quarter, relative to levels late in the third quarter. Outside the typical holiday and seasonal slowdowns, we believe activity will remain relatively steady with current levels through the rest of this year, with activity likely to modestly recover starting in the first quarter of 2024.

Drilling products demand has begun to increase from levels late in the third quarter as the North American rig count has moderately increased in the fourth quarter.

For the fourth quarter, we expect total capital expenditures of approximately $190 million.

Recent Developments in Business Combinations and Financial Matters — On September 1, 2023 we completed our merger (the “NexTier merger”) with NexTier Oilfield Solutions Inc. (“NexTier”). Each share of common stock of NexTier issued and outstanding immediately prior to the effective time (including outstanding restricted shares) was converted into the right to receive 0.752 shares of our common stock, which based on the closing price of our common stock of $14.91 on September 1, 2023, valued the transaction at approximately $2.8 billion, including the assumption of debt. NexTier is a predominately U.S. land-focused oilfield service company, with a diverse set of well completion and production services across a variety of active basins.

On August 14, 2023, we completed our acquisition (the “Ulterra acquisition”) of Ulterra Drilling Technologies, L.P. (“Ulterra”). Total consideration for the acquisition included the issuance of 34.9 million shares of our common stock and payment of approximately $376 million cash, which based on the closing price of our common stock of $14.94 on August 14, 2023, valued the transaction at closing at approximately $897 million. Ulterra is a global provider of specialized drill bit solutions.

On September 13, 2023, we completed the offering of $400 million in aggregate principal amount of our 7.15% Senior Notes due 2033 (the “2033 Notes”). The net proceeds before offering expenses were approximately $396 million, which we used to repay amounts outstanding under our revolving credit facility.

On August 29, 2023, we entered into Amendment No. 4 to Amended and Restated Credit Agreement (the “Credit Agreement Amendment”), which amends our Amended and Restated Credit Agreement, dated as of March 27, 2018 (as amended, the “Credit Agreement”), by and among us, as borrower, Wells Fargo Bank, National Association, as administrative agent, letter of credit issuer, swing line lender and a lender and each of the other letter of credit issuers and lenders party thereto.

The Credit Agreement Amendment, among other things, (i) deemed certain outstanding letters of credit issued for the account of BEP Diamond Holdings Corp. (the entity we acquired in the Ulterra acquisition) with a face amount of $2.5 million to have been issued under the Credit Agreement, and (ii) extended the maturity date for $85 million of revolving credit commitments of certain lenders under the Credit Agreement from March 27, 2025 to March 27, 2026. As a result, of the $600 million of revolving credit commitments under the Credit Agreement, the maturity date for $501.7 million of such commitments is March 27, 2026; the maturity date for $48.3 million of such commitments is March 27, 2025; and the maturity date for the remaining $50 million of such commitments is March 27, 2024.

During the first quarter of 2023, we elected to repurchase portions of our 3.95% Senior Notes due 2028 (the “2028 Notes”) and our 5.15% Senior Notes due 2029 (the “2029 Notes”) in the open market. The principal amounts retired through these transactions totaled $6.0 million of our 2028 Notes and $3.0 million of our 2029 Notes, plus accrued interest. We recorded corresponding gains on

the extinguishment of these amounts totaling $0.8 million and $0.3 million, respectively, net of the proportional write-off of associated deferred financing costs and original issuance discounts. These gains are included in “Interest expense, net of amount capitalized” in our unaudited condensed consolidated statements of operations.

Impact on our Business from Oil and Natural Gas Prices and Other Factors — Our revenues, profitability and cash flows are highly dependent upon prevailing prices for oil and natural gas and upon our customers’ ability to access, and willingness to deploy, capital to fund their operating and capital expenditures. 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 are relatively low or when our customers have a reduced ability to access capital, the demand for our services generally weakens, and we experience downward pressure on pricing for our services. Even during periods of historically moderate or 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. We may also be impacted by delayed customer payments and payment defaults associated with customer liquidity issues and bankruptcies.

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. 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.

In addition to the dependence on oil and natural gas prices and demand for our services, we are highly impacted by operational risks, competition, labor issues, weather, the availability, from time to time, of products used in our businesses, supplier delays and various other factors that could materially adversely affect our business, financial condition, cash flows and results of operations. Please see Item 1A of this Report and our Annual Report on Form 10-K for the fiscal year ended December 31, 2022.

For the three months ended September 30, 2023 and June 30, 2023 and nine months ended September 30, 2023 and 2022, our operating revenues consisted of the following (dollars in thousands):


	Three Months Ended								Nine Months Ended
	September 30,				June 30,				September 30				September 30
	2023				2023				2023				2022
Drilling Services	$	488,775	48.3	%	$	489,659	64.5	%	$	1,456,161	56.8	%	$	1,083,329	58.3	%
Completion Services		459,574	45.4	%		250,241	33.0	%		1,003,083	39.2	%		715,630	38.5	%
Drilling Products		46,570	4.6	%		—	0.0	%		46,570	1.8	%		—	0.0	%
Other		16,533	1.7	%		18,985	2.5	%		56,325	2.2	%		60,157	3.2	%
	$	1,011,452	100.0	%	$	758,885	100.0	%	$	2,562,139	100.0	%	$	1,859,116	100.0	%

Results of Operations

The following tables summarize results of operations by business segment for the three months ended September 30, 2023 and June 30, 2023:


	Three Months Ended
	September 30,			June 30,
Drilling Services (1)	2023			2023		% Change
	(dollars in thousands)
Revenues	$	488,775		$	489,659		(0.2	)%
Direct operating costs		279,927			281,573		(0.6	)%
Adjusted gross margin (2)		208,848			208,086		0.4	%
Selling, general and administrative		3,570			4,395		(18.8	)%
Depreciation, amortization and impairment		90,668			90,400		0.3	%
Other operating (income) expenses, net		(127	)		12	NA
Operating income	$	114,737		$	113,279		1.3	%
Capital expenditures	$	89,242		$	82,634		8.0	%

Operating days - U.S. (3)		11,009			11,669		(5.7	)%
Average revenue per operating day - U.S. (3)	$	38.11		$	35.94		6.0	%
Average direct operating costs per operating day - U.S. (3)	$	19.87		$	19.04		4.4	%
Average adjusted gross margin per operating day - U.S. (3)	$	18.24		$	16.91		7.9	%

(1)

Drilling services segment represents our contract drilling, directional drilling, oilfield technology and electrical controls and automation businesses.

(2)

Adjusted gross margin is defined as revenues less direct operating costs (excluding depreciation, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross margin to adjusted gross margin by segment.

(3)

Operational data relates to our contract drilling business. A rig is considered to be operating if it is earning revenue pursuant to a contract on a given day.

Revenues were flat between sequential quarters. However, our contract drilling business recorded approximately $29 million of previously deferred revenue from a customer prepayment during the three months ended September 30, 2023, which became recognizable after the customer changed its drilling schedule. Without this incremental revenue, our drilling services revenues would have decreased 6% over the comparable periods, which reflects the reduction in average contract drilling rig count in the United States from 128 rigs to 120 rigs.

Direct operating costs decreased approximately 1% between sequential quarters primarily due to the reduction in average rig count in our contract drilling business. The decrease in average rig count was partially offset by inflationary pressure on labor and supplies.

The increase in capital expenditures was primarily due to the timing of order placement and spending on committed deliveries that more heavily impacted the third quarter of 2023.


	Three Months Ended
	September 30,		June 30,
Completion Services (1)	2023		2023		% Change
	(dollars in thousands)
Revenues	$	459,574	$	250,241		83.7	%
Direct operating costs		368,869		196,473		87.7	%
Adjusted gross margin (2)		90,705		53,768		68.7	%
Selling, general and administrative		7,205		2,488		189.6	%
Depreciation, amortization and impairment		83,338		25,976		220.8	%
Operating income	$	162	$	25,304		(99.4	)%
Capital expenditures	$	56,464	$	29,640		90.5	%

(1)

Completion services represents the combination of well completion business from the NexTier merger and our legacy pressure pumping business.

(2)

The changes for the three months ended September 30, 2023 as compared to June 30, 2023 can be primarily attributed to the NexTier merger, which closed on September 1, 2023. The NexTier merger had a material impact on our reported results of operations. In order to provide a more meaningful basis for comparison, the discussion below is focused on changes between comparable periods excluding the effects of the NexTier merger.

Completion services revenues, excluding the effects of the NexTier merger, decreased $62.8 million, or 25%. The decrease was due to lower pricing, which accounted for approximately 40% of the change in revenue, with the remainder being driven by lower utilization.

Direct operating costs, excluding the effects of the NexTier merger, decreased $35.6 million, or 18%. The decrease was primarily due to lower utilization.

Selling, general and administrative expense, excluding the effects of the NexTier merger, was flat over the comparable periods.

Depreciation, amortization and impairment, excluding the effects of the NexTier merger, increased $26.5 million, or 102%. The increase was primarily attributable to the change in the estimated useful lives of certain components to reflect recent trends in increased intensity and pumping hours per day in servicing larger jobs. We expect the impact of this change to result in approximately $5 million of incremental depreciation expense in excess of our historic run rate in each subsequent three-month period. See Note 1 of Notes to unaudited condensed consolidated financial statements for additional information on this change in accounting estimate.

Capital expenditures, excluding the effects of the NexTier merger, increased $8.5 million, or 29%. The increase was primarily due to spending related to maintenance capital and the timing of order placement that more heavily impacted the third quarter of 2023.


	Three Months Ended
	September 30,			June 30,
Drilling Products	2023			2023		% Change
	(dollars in thousands)
Revenues	$	46,570		$	—	NA
Direct operating costs		32,071			—	NA
Adjusted gross margin (1)		14,499			—	NA
Selling, general and administrative		3,664			—	NA
Depreciation, amortization and impairment		17,075			—	NA
Operating loss	$	(6,240	)	$	—	NA
Capital expenditures	$	7,940		$	—	NA

(1)

The results of our drilling products segment reflect the operations of our Ulterra acquisition, from the closing date of August 14, 2023 until September 30, 2023. As such, there were no comparable results for the three months ended June 30, 2023.

Direct operating costs and depreciation, amortization and impairment were approximately $6.4 million and $7.4 million higher than they would have otherwise been, respectively, as a result of the step up to fair value of our drill bits in accordance with purchase accounting.


	Three Months Ended
	September 30,		June 30,
Other	2023		2023			% Change
	(dollars in thousands)
Revenues	$	16,533	$	18,985			(12.9	)%
Direct operating costs		10,591		10,039			5.5	%
Adjusted gross margin (1)		5,942		8,946			(33.6	)%
Selling, general and administrative		188		233			(19.3	)%
Depreciation, depletion, amortization and impairment		5,319		9,304			(42.8	)%
Operating income (loss)	$	435	$	(591	)	NA
Capital expenditures	$	5,972	$	7,192			(17.0	)%

(1)

Adjusted gross margin is defined as revenues less direct operating costs (excluding depreciation, depletion, amortization and impairment expense). See Non-GAAP Financial Measures below for a reconciliation of GAAP gross margin to adjusted gross margin by segment.

Revenue decreased due to a lower volume of services provided by our oilfield rentals business.

Depreciation, depletion, amortization and impairment decreased primarily due to a $3.8 million impairment recorded in our oil and natural gas properties business in the second quarter of 2023.


	Three Months Ended
	September 30,			June 30,
Corporate	2023			2023			% Change
	(dollars in thousands)
Selling, general and administrative	$	30,475		$	26,141			16.6	%
Merger and integration expense	$	70,188		$	7,940			784.0	%
Depreciation	$	1,235		$	1,134			8.9	%
Other operating income, net	$	(2,508	)	$	(1,805	)		38.9	%
Interest income	$	2,131		$	1,212			75.8	%
Interest expense	$	15,625		$	9,738			60.5	%
Other (expense) income	$	(618	)	$	2,323		NA
Capital expenditures	$	804		$	12,928			(93.8	)%

Selling, general and administrative expense increased due to incremental headcount for corporate functions as a result of the NexTier merger, which closed on September 1, 2023. Selling, general and administrative expense, excluding the effects of the NexTier merger, was relatively flat over the comparable periods.

Merger and integration expense increased due to the NexTier merger and the Ulterra acquisition during the three months ended September 30, 2023. The increase was primarily attributable to $39.1 million of accelerated stock-based compensation expense and additional cash compensation associated with severance payments as well as certain legal, financial advisory, and other professional fees in order to consummate the transactions.

Interest expense increased primarily due to borrowings on our revolving credit facility throughout the quarter and the offering of 2033 Notes. See Note 9 of Notes to unaudited condensed consolidated financial statements for additional information on our long-term debt.

The decrease in capital expenditures was primarily due to the purchase of an aircraft in the second quarter of 2023.

The following tables summarize results of operations by business segment for the nine months ended September 30, 2023, and September 30, 2022:


	Nine Months Ended
	September 30,			September 30,
Drilling Services (1)	2023			2022			% Change
	(dollars in thousands)
Revenues	$	1,456,161		$	1,083,329			34.4	%
Direct operating costs		842,761			741,317			13.7	%
Adjusted gross margin (2)		613,400			342,012			79.4	%
Selling, general and administrative		11,810			10,432			13.2	%
Depreciation, amortization and impairment		272,361			262,955			3.6	%
Other operating income, net		(93	)		(4	)		2,225.0	%
Operating income	$	329,322		$	68,629			379.9	%
Capital expenditures	$	261,155		$	181,754			43.7	%

Operating days - U.S. (3)		34,429			33,144			3.9	%
Average revenue per operating day - U.S. (3)	$	36.23		$	26.02			39.3	%
Average direct operating costs per operating day - U.S. (3)	$	19.25		$	16.93			13.7	%
Average adjusted gross margin per operating day - U.S. (3)	$	16.98		$	9.08			86.9	%

(1)

Drilling services segment represents our contract drilling, directional drilling, oilfield technology and electrical controls and automation businesses.

(2)

(3)

Operational data relates to our contract drilling business. A rig is considered to be operating if it is earning revenue pursuant to a contract on a given day.

Revenues increased primarily due to improved pricing and an increase in operating days in our contract drilling business within the United States.

Direct operating costs increased primarily due to an increase in operating days in our contract drilling business within the United States in addition to inflationary pressure on labor and supplies.

The increase in capital expenditures was primarily due to higher maintenance capital expenditures related to increased rig activity and upgrading of certain rig components.


	Nine Months Ended
	September 30,		September 30,
Completion Services (1)	2023		2022		% Change
	(dollars in thousands)
Revenues	$	1,003,083	$	715,630		40.2	%
Direct operating costs		785,458		560,627		40.1	%
Adjusted gross margin (2)		217,625		155,003		40.4	%
Selling, general and administrative		12,388		6,298		96.7	%
Depreciation, amortization and impairment		135,339		73,244		84.8	%
Operating income	$	69,898	$	75,461		(7.4	)%
Capital expenditures	$	107,529	$	114,669		(6.2	)%

(1)

Completion services represents the combination of well completion business from the NexTier merger and our legacy pressure pumping business.

(2)

The changes for the nine months ended September 30, 2023 as compared to September 30, 2022 can be primarily attributed to the NexTier merger, which closed on September 1, 2023. The NexTier merger had a material impact on our reported results of operations. In order to provide a more meaningful basis for comparison, the discussion on changes below is focused on changes between comparable periods, excluding the effects of the NexTier merger.

Completion services revenues and direct operating costs, excluding the effects of the NexTier merger, increased $15.3 million and $16.8 million, or 2% and 3%, respectively. The modest increases reflect volatility over both comparable periods as we experienced pricing and activity increases during the nine months ended September 30, 2022 that reversed with recent market trends in the third

quarter of 2023. Direct operating costs also increased during the nine months ended September 30, 2023, primarily due to inflationary pressure on labor and supplies.

Selling, general and administrative expense, excluding the effects of the NexTier merger, was relatively flat consistent over the comparable periods.

Depreciation, amortization and impairment, excluding the effects of the NexTier merger, increased $31.2 million, or 43%. The increase was primarily attributable to the change in estimated useful lives of certain components to reflect recent trends in increased intensity and pumping hours per day in servicing larger jobs. We expect the impact of this change to result in approximately $20 million of incremental depreciation expense in excess of our historic run rate over the next twelve months. See Note 1 of Notes to unaudited condensed consolidated financial statements for additional information on this change in accounting estimate.

The decrease in capital expenditures was primarily due to the activation of our twelfth spread in 2022, which was partially offset by incremental capital expenditures related to NexTier equipment during September 2023.


	Nine Months Ended
	September 30,			September 30,
Drilling Products	2023			2022		% Change
	(dollars in thousands)
Revenues	$	46,570		$	—	NA
Direct operating costs		32,071			—	NA
Adjusted gross margin (1)		14,499			—	NA
Selling, general and administrative		3,664			—	NA
Depreciation, amortization and impairment		17,075			—	NA
Operating loss	$	(6,240	)	$	—	NA
Capital expenditures	$	7,940		$	—	NA

(1)


	Nine Months Ended
	September 30,		September 30,
Other	2023		2022		% Change
	(dollars in thousands)
Revenues	$	56,325	$	60,157		(6.4	)%
Direct operating costs		31,912		28,789		10.8	%
Adjusted gross margin (1)		24,413		31,368		(22.2	)%
Selling, general and administrative		656		576		13.9	%
Depreciation, depletion, amortization and impairment		21,946		20,495		7.1	%
Operating income (loss)	$	1,811	$	10,297		(82.4	)%
Capital expenditures	$	18,387	$	19,654		(6.4	)%

(1)

Revenue decreased moderately between comparable periods. Our oil and natural gas revenues decreased by $10.0 million as a result of lower average crude oil and natural gas market prices. Average WTI-Cushing prices for the nine months ended September 30, 2023 were $77.27 per barrel as compared to $98.96 per barrel for the nine months ended September 30, 2022. Natural gas prices (based on the Henry Hub spot market) averaged $2.46 per MMBtu for the nine months ended September 30, 2023 as compared to $6.74 per MMBtu for the nine months ended September 30, 2022. This decrease was partially offset by a $6.2 million increase in revenues from our oilfield rentals business.


	Nine Months Ended
	September 30,			September 30,
Corporate	2023			2022			% Change
	(dollars in thousands)
Selling, general and administrative	$	80,407		$	64,706			24.3	%
Merger and integration expense	$	78,128		$	2,069			3,676.1	%
Depreciation	$	5,908		$	3,947			49.7	%
Other operating income, net	$	(9,901	)	$	(10,561	)		(6.2	)%
Interest income	$	4,583		$	87			5,167.8	%
Interest expense	$	34,189		$	32,198			6.2	%
Other income (expense)	$	3,191		$	(2,644	)	NA
Capital expenditures	$	15,406		$	1,476			943.8	%

Selling, general and administrative expense increased primarily due to increased personnel costs as a result of higher headcount, wage growth and changes in stock-based compensation. A portion of the increased personnel costs resulted from incremental headcount for corporate functions as part of the NexTier merger.

Merger and integration expense increased due to closing the Ulterra acquisition and NexTier merger during the nine months ended September 30, 2023. Merger and integration expense increased due to the NexTier merger and the Ulterra acquisition during the three months ended September 30, 2023. The increase was primarily attributable to $39.1 million of accelerated stock-based compensation expense and additional cash compensation associated with severance payments as well as certain legal, financial advisory, and other professional fees in order to consummate the transactions.

Interest income increased due to us maintaining a higher average cash balance during the nine months ended September 30, 2023.

The $5.8 million change in other income (expense) was primarily due to foreign currency adjustments related to our Colombian operations.

The increase in capital expenditures was primarily due to the purchase of an aircraft in 2023.

Income Taxes

Our effective income tax rate for the three months ended September 30, 2023 was 93.7%, compared with 14.0% for the three months ended June 30, 2023. The difference in effective income tax rates was primarily attributable to the impact of valuation allowances on deferred tax assets between periods.

Liquidity and Capital Resources

Our primary sources of liquidity are cash and cash equivalents, availability under our revolving credit facility and cash provided by operating activities. As of September 30, 2023, we had approximately $387 million in working capital, including $67.0 million of cash and cash equivalents, and $597.5 million available under our revolving credit facility.

As part of the NexTier merger, we assumed the obligations of NexTier Completions Solutions Inc. (“NCS”) under a Master Loan and Security Agreement (as amended, the “Master Agreement”) with Caterpillar Financial Services Corporation. The Master

Agreement allows NCS to enter into secured equipment financing term loans from time to time (the “Equipment Loans”). The Equipment Loans may be drawn in multiple tranches, with each loan evidenced by a separate promissory note. The Master Agreement and the Equipment Loans contain customary affirmative and negative covenants, including limitations on further encumbrance of the collateral other than the applicable loans under the Master Agreement. The Equipment Loans bear interest at a rate of 5.25% per annum, and we pay interest on the 1st of each month. The Equipment Loans will mature on June 1, 2025. We were in compliance with these covenants at September 30, 2023.

On August 29, 2023, we entered into Amendment No. 4 to the Amended and Restated Credit Agreement (the “Credit Agreement Amendment”), which amended our Amended and Restated Credit Agreement, dated as of March 27, 2018 (as amended, the “Credit Agreement”), by and among us, as borrower, Wells Fargo Bank, National Association, as administrative agent, letter of credit issuer, swing line lender and a lender and each of the other letter of credit issuers and lenders party thereto. The Credit Agreement Amendment, among other things, (i) deemed certain outstanding letters of credit issued for the account of BEP Diamond Holdings Corp. (the entity we acquired in the Ulterra acquisition) with a face amount of $2.5 million to have been issued under the Credit Agreement and (ii) extended the maturity date for $85 million of revolving credit commitments of certain lenders under the Credit Agreement from March 27, 2025 to March 27, 2026. As a result, of the $600 million of revolving credit commitments under the Credit Agreement, the maturity date for $501.7 million of such commitments is March 27, 2026; the maturity date for $48.3 million of such commitments is March 27, 2025; and the maturity date for the remaining $50 million of such commitments is March 27, 2024.

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 September 30, 2023, we had $87.7 million in letters of credit outstanding under the Reimbursement Agreement.

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. A letter of credit fee is payable by us equal to 1.50% times the amount of outstanding letters of credit.

We have also agreed that if obligations under the Credit Agreement are secured by liens on any of our or 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.

We had $92.7 million of outstanding letters of credit at September 30, 2023, which was comprised of $87.7 million outstanding under the Reimbursement Agreement, $2.5 million outstanding under the Credit Agreement, and $2.5 million outstanding with financial institutions providing for short-term borrowing capacity, overdraft protection and bonding requirements. We maintain these letters of credit primarily for the benefit of various insurance companies as collateral for retrospective premiums and retained losses which could become payable under terms of the underlying insurance contracts. These letters of credit expire annually at various times during the year and are typically renewed. As of September 30, 2023, no amounts had been drawn under the letters of credit.

Our outstanding long-term debt at September 30, 2023 was $1.2 billion and consisted of $483 million of our 2028 Notes, $345 million of our 2029 Notes, $400 million of our 2033 Notes and $21.7 million of our Equipment Loans. We were in compliance with all covenants under the associated agreements and indentures at September 30, 2023.

For a full description of the Credit Agreement, the Reimbursement Agreement, the 2028 Notes, the 2029 Notes, the 2033 Notes and the Equipment Loans, see Note 9 of Notes to unaudited condensed consolidated financial statements.

On August 29, 2023, we entered into a Term Loan Agreement with Wells Fargo Bank, National Association, as administrative agent and a lender, and the other lenders party thereto (the “Term Loan Agreement”). The Term Loan Agreement was a committed senior unsecured term loan facility (the “Term Loan Facility”) that permitted a single borrowing of up to $300 million, which could be drawn by us on or before November 27, 2023. We terminated the Term Loan Facility on September 13, 2023 and, as a result, the commitments under the Term Loan Agreement also terminated in full. We did not borrow under the Term Loan Facility.

Cash Requirements

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, pay cash dividends and repurchase our common stock and senior notes for at least the next 12 months.

If we pursue other opportunities 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.

A portion of our capital expenditures can be adjusted and managed by us to match market demand and activity levels. For the fourth quarter, we expect total capital expenditures of approximately $190 million.

The majority of these expenditures are expected to be used for normal, recurring items necessary to support our business.

During the nine months ended September 30, 2023, our sources of cash flow included:

•

$553 million from operating activities, and

•

$19.6 million in proceeds from the disposal of property and equipment, and

•

$396 million in net proceeds before offering expenses from the issuance of our 2033 Notes.

During the nine months ended September 30, 2023, our uses of cash flow and borrowings under our revolving credit facility included:

•

$410 million to make capital expenditures for the betterment and refurbishment of drilling services and completion services equipment and, to a much lesser extent, equipment for our other businesses, to acquire and procure equipment to support our drilling services, completion services, drilling products, oilfield rentals and manufacturing operations, to acquire an aircraft and to fund investments in oil and natural gas properties on a non-operating working interest basis,

•

$357 million, net of acquired cash, for the Ulterra acquisition,

•

$65.2 million, net of acquired cash, for the NexTier merger,

•

$124.3 million for repurchases of our common stock,

•

$66.7 million to pay dividends on our common stock,

•

$5.2 million for repurchases of our 2028 Notes, and

•

$2.6 million for repurchases of our 2029 Notes.

We paid cash dividends during the nine months ended September 30, 2023 as follows:


	Per Share		Total
			(in thousands)
Paid on March 16, 2023	$	0.08	$	16,916
Paid on June 15, 2023	$	0.08	$	16,591
Paid on September 21, 2023	$	0.08	$	33,217
	$	0.24	$	66,724

On November 7, 2023, our Board of Directors approved a cash dividend on our common stock in the amount of $0.08 per share to be paid on December 15, 2023 to holders of record as of December 1, 2023. 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. Our Board of Directors may, without advance notice, reduce or suspend our dividend in order to improve our financial flexibility and position our company for long-term success. There can be no assurance that we will pay a dividend in the future.

We may, at any time and from time to time, seek to retire or purchase our outstanding debt for cash through open-market purchases, privately negotiated transactions, redemptions or otherwise. Such repurchases, if any, will be upon such terms and at such prices as we may determine, and will depend on prevailing market conditions, our liquidity requirements, contractual restrictions and other factors. The amounts involved may be material.

In September 2013, our Board of Directors approved a stock buyback program. In April 2023, our Board of Directors approved an increase of the authorization under the stock buyback program to allow for an aggregate of $300 million of future share repurchases. All purchases executed to date have been through open market transactions. Purchases under the buyback 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 September 30, 2023, we had remaining authorization to purchase approximately $281 million of our outstanding common stock under the stock buyback program. Shares of stock purchased under the buyback program are held as treasury shares.

Treasury stock acquisitions during the nine months ended September 30, 2023 were as follows (dollars in thousands):


	Shares		Cost
Treasury shares at beginning of period		88,758,722	$	1,453,079
Purchases pursuant to stock buyback program		7,426,044		93,276
Acquisitions pursuant to long-term incentive plans (1)		2,356,845		31,722
Treasury shares at end of period		98,541,611	$	1,578,077

(1)

We withheld 2,356,845 shares during the first three quarters of 2023 with respect to employees’ tax withholding obligations upon the settlement of performance unit awards and the vesting of 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, as amended, the Patterson-UTI Energy, Inc. 2021 Long-Term Incentive Plan, as amended, the NexTier Oilfield

Solutions Inc. Equity and Incentive Award Plan and the NexTier Oilfield Solutions Inc. (Former C&J Energy) Management Incentive Plan and not pursuant to the stock buyback program.

Commitments — As of September 30, 2023, we had commitments to purchase major equipment totaling approximately $197 million. Our completion services segment has entered into agreements to purchase minimum quantities of proppants and chemicals from certain vendors. As of September 30, 2023, the remaining minimum obligation under these agreements was approximately $34.5 million, of which approximately $14.2 million, $16.3 million, and $4.0 million relate to the remainder of 2023, 2024 and 2025, respectively.

See Note 10 of Notes to unaudited condensed consolidated financial statements for additional information on our current commitments and contingencies as of September 30, 2023.

As part of the Ulterra acquisition and NexTier merger, we acquired additional operating and finance leases. Operating lease liabilities totaled $51.5 million and finance lease liabilities totaled $55.8 million as of September 30, 2023.

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.

Non-GAAP Financial Measures

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 (“GAAP”). We define Adjusted EBITDA as net income (loss) plus income tax expense (benefit), net interest expense, depreciation, depletion, amortization and impairment expense and merger and integration expense. We present Adjusted EBITDA as a supplemental disclosure 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 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 GAAP measure of net income. Our computations of Adjusted EBITDA may not be the same as similarly titled measures of other companies. Set forth below is a reconciliation of the non-GAAP financial measure of Adjusted EBITDA to the GAAP financial measure of net income.


	Three Months Ended					Nine Months Ended
	September 30,			June 30,		September 30,
	2023			2023		2023		2022
	(in thousands)
Net income (loss)	$	(278	)	$	84,614	$	184,014	$	54,561
Income tax expense (benefit)		(4,130	)		13,765		29,820		4,910
Net interest expense		13,494			8,526		29,606		32,111
Depreciation, depletion, amortization and impairment		197,635			126,814		452,629		360,641
Merger and integration expense		70,188			7,940		78,128		2,069
Adjusted EBITDA	$	276,909		$	241,659	$	774,197	$	454,292

Adjusted Gross Margin

We define “Adjusted gross margin” as revenues less direct operating costs (excluding depreciation, depletion, amortization and impairment expense). Adjusted gross margin is included as a supplemental disclosure because it is a useful indicator of our operating performance.


	Drilling Services			Completion Services			Drilling Products			Other
	(in thousands)
For the three months ended September 30, 2023
Revenues	$	488,775		$	459,574		$	46,570		$	16,533
Less direct operating costs		(279,927	)		(368,869	)		(32,071	)		(10,591	)
Less depreciation, depletion, amortization and impairment		(90,668	)		(83,338	)		(17,075	)		(5,319	)
GAAP gross margin		118,180			7,367			(2,576	)		623
Depreciation, depletion, amortization and impairment		90,668			83,338			17,075			5,319
Adjusted gross margin	$	208,848		$	90,705		$	14,499		$	5,942

For the three months ended June 30, 2023
Revenues	$	489,659		$	250,241		$	—		$	18,985
Less direct operating costs		(281,573	)		(196,473	)		—			(10,039	)
Less depreciation, depletion, amortization and impairment		(90,400	)		(25,976	)		—			(9,304	)
GAAP gross margin		117,686			27,792			—			(358	)
Depreciation, depletion, amortization and impairment		90,400			25,976			—			9,304
Adjusted gross margin	$	208,086		$	53,768		$	—		$	8,946

For the nine months ended September 30, 2023
Revenues	$	1,456,161		$	1,003,083		$	46,570		$	56,325
Less direct operating costs		(842,761	)		(785,458	)		(32,071	)		(31,912	)
Less depreciation, depletion, amortization and impairment		(272,361	)		(135,339	)		(17,075	)		(21,946	)
GAAP gross margin		341,039			82,286			(2,576	)		2,467
Depreciation, depletion, amortization and impairment		272,361			135,339			17,075			21,946
Adjusted gross margin	$	613,400		$	217,625		$	14,499		$	24,413

For the nine months ended September 30, 2022
Revenues	$	1,083,329		$	715,630		$	—		$	60,157
Less direct operating costs		(741,317	)		(560,627	)		—			(28,789	)
Less depreciation, depletion, amortization and impairment		(262,955	)		(73,244	)		—			(20,495	)
GAAP gross margin		79,057			81,759			—			10,873
Depreciation, depletion, amortization and impairment		262,955			73,244			—			20,495
Adjusted gross margin	$	342,012		$	155,003		$	—		$	31,368

Critical Accounting Estimates

The preparation of financial statements in conformity with accounting principles generally accepted in the United States of America (“GAAP”) requires management to make certain estimates and assumptions that affect the reported amounts of assets and liabilities and disclosures of contingent assets and liabilities at the date of the financial statements and the reported amounts of revenues and expenses during the reporting period. Actual results could differ from such estimates. Accounting estimates and assumptions discussed in this section are those considered to be the most critical to an understanding of our financial statements because they involve significant judgments and uncertainties. There have been no material changes to our critical accounting estimates previously disclosed in Item 7 of our Annual Report on Form 10-K for the fiscal year ended December 31, 2022, except as follows:

Fair values of assets acquired and liabilities assumed in acquisitions — Assets acquired and liabilities assumed in a business combination are recorded at their estimated fair values on the date of acquisition. The difference between the purchase price amount and the net fair value of assets acquired and liabilities assumed is recognized as goodwill on the balance sheet if the purchase price exceeds the estimated net fair value or as a bargain purchase gain on the income statement if the purchase price is less than the estimated net fair value. We apply significant judgment in estimating the fair value of assets acquired and liabilities assumed, which involves the use of significant estimates and assumptions with respect to rig counts, estimated economic useful lives, operating and capital cost estimates, and weighted average discount rates reflecting the cost of capital for market participants. Changes in these judgments or estimates can have a material impact on the valuation of the respective assets and liabilities acquired and our results of operations in periods after acquisition, such as through depreciation and amortization expense. The allocation of the purchase price may be modified up to one year after the acquisition date as more information is obtained about the fair value of assets acquired and liabilities assumed. See Note 2 of Notes to unaudited condensed consolidated financial statements for additional information on the fair values of assets acquired and liabilities assumed in recent business combinations.

Recently Issued Accounting Standards

See Note 1 of Notes to unaudited condensed consolidated financial statements for a discussion of the impact 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. Crude oil prices and demand for drilling and completions equipment and services increased in 2022, and industry supply of Tier-1, super-spec rigs became constrained. Commodity price volatility in the second quarter of 2023 resulted in a decline in industry activity; however, commodity prices increased during the third quarter. The current demand for equipment and services remains dependent on macro conditions, including commodity prices, geopolitical environment, inflationary pressures, economic conditions in the United States and elsewhere and continued customer consolidation and focus by exploration and production companies and service companies on capital discipline. Oil prices reached a low of $69.71 per barrel and averaged $82.25 per barrel in the third quarter of 2023, as compared to $73.54 per barrel in the second quarter of 2023. Natural gas prices (based on the Henry Hub Spot Market Price) averaged $2.59 per MMBtu in the third quarter of 2023 as compared to an average of $2.16 per MMBtu in the second quarter of 2023.

In light of these and other factors, 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, as well as our customers’ ability to access sources of capital to fund their operating and capital expenditures. A decline in demand for oil and natural gas, prolonged low oil or natural gas prices, expectations of decreases in oil and natural gas prices or a reduction in the ability of our customers to access capital 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 historically moderate or 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

We may be exposed to certain market risks arising from the use of financial instruments in the ordinary course of business. For quantitative and qualitative disclosures about market risk, see Part II, Item 7A, “Quantitative and Qualitative Disclosures About Market Risk,” in our Annual Report on Form 10-K for the year ended December 31, 2022. There have been no material changes in our exposure to market risk.

As of September 30, 2023, we would have had exposure to interest rate market risk associated with any outstanding borrowings that we had under the Credit Agreement and amounts owed under the Reimbursement Agreement.

Loans under the Credit Agreement bear interest by reference, at our election, to the SOFR rate or base rate. The applicable margin on SOFR 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 September 30, 2023, the applicable margin on SOFR rate loans was 1.75% and the applicable margin on base rate loans was 0.75%. A letter of credit fee is payable by us equal to the applicable margin for SOFR 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. As of September 30, 2023, we had $2.5 million in letters of credit outstanding and, as a result, had available borrowing capacity of $597.5 million at that date.

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. 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 September 30, 2023, no amounts had been disbursed under any letters of credit.

Some of our revenues in foreign countries are denominated in U.S. dollars, and therefore, changes in foreign currency exchange rates impact our earnings to the extent that costs associated with those U.S. dollar revenues are denominated in the local currency. Similarly, some of our revenues are denominated in foreign currencies, but have associated U.S. dollar costs, which also give rise to foreign currency exchange rate exposure.

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 September 30, 2023.

As disclosed in Note 2 Business Combinations in the Notes to Consolidated Financial Statements, we completed the Ulterra acquisition on August 14, 2023 and the NexTier merger on September 1, 2023. We excluded Ulterra’s and NexTier’s disclosure controls and procedures that are subsumed by their internal control over financial reporting from the scope of management’s assessment of the effectiveness of our disclosure controls and procedures. This exclusion is in accordance with the guidance issued by the Staff of the Securities and Exchange Commission that an assessment of recent business combinations may be omitted from management's assessment of internal control over financial reporting for one year following the acquisition. As a result of our integration of the Ulterra and NexTier disclosure controls and procedures, certain controls will be evaluated and may be changed. Ulterra and NexTier’s total revenues constituted approximately 5% and 27% of our consolidated revenues, respectively, for the three months ended September 30, 2023. Ulterra’s and NexTier’s total assets constituted approximately 14% and 47% of our consolidated total assets, respectively, as of September 30, 2023.

Changes in Internal Control Over Financial Reporting — Except as noted above, 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.

PART II — OTHER INFORMATION

ITEM 1. Legal Proceedings

ITEM 1A. Risk Factors

There have been no material changes to the risk factors previously disclosed in Item 1A., “Risk Factors” of our Annual Report on Form 10-K for the year ended December 31, 2022 other than those listed in Part II, Item 1A., “Risk Factors” of our Quarterly Report on Form 10-Q for the quarter ended June 30, 2023 and this section.

Our business relationships may be subject to disruption due to uncertainty associated with the NexTier merger or the Ulterra acquisition, which could have a material adverse effect on our results of operations, cash flows and financial position pending and following the NexTier merger and the Ulterra acquisition.

Parties with which we do business may experience uncertainty associated with the NexTier merger and the Ulterra acquisition, including with respect to current or future business relationships with us. Our business relationships may be subject to disruption as customers, distributors, suppliers, vendors, landlords, joint venture partners and other business partners may attempt to delay or defer entering into new business relationships, negotiate changes in existing business relationships or consider entering into business relationships with parties other than us, NexTier or Ulterra. These disruptions could have a material adverse effect on our results of operations, cash flows and financial position, as well as a material adverse effect on our ability to realize the expected cost savings and other benefits of the applicable transaction.

Our ability to utilize our historic U.S. net operating loss carryforwards is expected to be limited as a result of the completion of the NexTier merger.

As of December 31, 2022, we had approximately $1.4 billion of gross U.S. federal NOLs, approximately $48.3 million of gross Canadian NOLs, approximately $18.8 million of gross Colombian NOLs and approximately $1.0 billion of post-apportionment U.S. state NOLs, before valuation allowances. The majority of our U.S. federal NOLs will expire in varying amounts, if unused, between 2030 and 2037. U.S. federal NOLs generated after 2017 can be carried forward indefinitely. Our Canadian NOLs will expire in varying amounts, if unused, between 2037 and 2042. Our Colombian NOLs will expire in varying amounts, if unused, between 2028 and 2032. Our U.S. state NOLs will expire in varying amounts, if unused, between 2023 and 2042.

Section 382 of the Code (“Section 382”) generally imposes an annual limitation on the amount of NOLs that may be used to offset taxable income when a corporation has undergone an “ownership change” (as determined under Section 382). An ownership change generally occurs if one or more stockholders (or groups of stockholders) who are each deemed to own at least 5% of such corporation’s stock has increased their ownership by more than 50 percentage points over their lowest ownership percentage within a rolling three-year period. In the event that an ownership change occurs, utilization of the relevant corporation’s NOLs would be subject to an annual limitation under Section 382, generally determined, subject to certain adjustments, by multiplying (i) the fair market value of such corporation’s stock at the time of the ownership change by (ii) a percentage approximately equivalent to the yield on long-term tax-exempt bonds during the month in which the ownership change occurs. Any unused annual limitation may be carried over to later years.

We experienced an ownership change (under Section 382) as a result of the closing of the NexTier merger. Our ability to utilize our available NOLs and other tax attributes to reduce future taxable income following this “ownership change” depends on many factors, including our future income, which cannot be assured. Based on information currently available, we expect this ownership change could cause some of our NOLs incurred prior to January 1, 2018 to expire before we would be able to utilize them to reduce taxable income in future periods, and may also require NOLs to be utilized later than they otherwise would be able to be utilized, increasing cash taxes payable in earlier years.

Uncertainties associated with the NexTier merger and the Ulterra acquisition may cause a loss of management personnel and other key employees, which could adversely affect our future business and operations.

We are dependent on the experience and industry knowledge of our officers and other key employees to execute our business plans. Our success after the transactions will depend in part upon our ability to retain key management personnel and other key

employees. Current and prospective employees may experience uncertainty about their roles within the combined company or other concerns regarding the operations of the combined company following the transactions, any of which may have an adverse effect on our ability to retain or attract key management and other key personnel. In addition, the loss of key personnel could diminish the anticipated benefits of the transactions and the integration of the companies may be more difficult. Furthermore, we may have to incur significant costs in identifying, hiring and retaining replacements for departing employees and may lose significant expertise and talent relating to the business of each of the companies. No assurance can be given that we will be able to retain or attract key management personnel and other key employees of NexTier or Ulterra to the same extent that we have previously been able to retain or attract our own employees.

We have incurred and are expected to continue incurring significant transaction costs in connection with the NexTier merger and the Ulterra acquisition, which may be in excess of those we anticipated.

We have incurred and are expected to continue to incur significant non-recurring costs associated with completing the NexTier merger and the Ulterra acquisition, combining the operations of the three companies and achieving desired synergies. These costs have been, and will continue to be, substantial. A substantial majority of non-recurring expenses consist of transaction costs and include, among others, fees paid to financial, legal, accounting and other advisors, employee retention, severance and benefit costs and filing fees. We have incurred and will continue to incur costs related to formulating and implementing integration plans, including facilities and systems consolidation costs and other employment-related costs. We will continue to assess the magnitude of these costs, and additional unanticipated costs may be incurred in connection with the integration of the companies’ businesses. While we have assumed that a certain level of expenses would be incurred, there are many factors beyond our control that could affect the total amount or the timing of the expenses. The elimination of duplicative costs, as well as the realization of other efficiencies related to the integration of the businesses, may not offset integration-related costs and achieve a net benefit in the near term, or at all. The costs described above and any unanticipated costs and expenses could have an adverse effect on our financial condition and operating results.

We may be unable to integrate the businesses of NexTier and Ulterra successfully or realize the anticipated benefits of the NexTier merger and the Ulterra acquisition.

The NexTier merger and the Ulterra acquisition involve the combination of companies that operated as independent companies. The combination of independent businesses is complex, costly and time consuming, and we have devoted, and will continue to devote, significant management attention and resources to integrating the respective business practices and operations of the companies. Potential difficulties that the companies may encounter as part of the integration process include the following:

•

our inability to successfully combine our business with the businesses of NexTier and Ulterra in a manner that permits us to achieve, on a timely basis or at all, the enhanced revenue opportunities and cost savings and other benefits anticipated to result from the NexTier merger and the Ulterra acquisition;

•

complexities associated with managing the combined businesses, including difficulty addressing possible differences in operational philosophies and the challenge of integrating complex systems, technology, networks and other assets of each of the companies in a seamless manner that minimizes any adverse impact on customers, suppliers, employees and other constituencies;

•

the assumption of contractual obligations with less favorable or more restrictive terms; and

•

potential unknown liabilities and unforeseen increased expenses or delays associated with the transactions.

In addition, because we, NexTier and Ulterra previously operated independently, it is possible that the integration process could result in:

•

diversion of the attention of our management; and

•

the disruption of, or the loss of momentum in, our ongoing businesses or inconsistencies in standards, controls, procedures and policies.

Any of these issues could adversely affect the combined company’s ability to maintain relationships with customers, suppliers, employees and other constituencies or achieve the anticipated benefits of the transactions, or could reduce the combined company’s earnings or otherwise adversely affect our business and financial results.

The benefits and synergies attributable to the NexTier merger and the Ulterra acquisition may vary from expectations.

We may fail to realize the anticipated benefits and synergies expected from the NexTier merger and the Ulterra acquisition, which could adversely affect our business, financial condition and operating results. The success of the transactions will depend, in

significant part, on our ability to successfully integrate the acquired businesses and realize the anticipated strategic benefits and synergies from the transactions. The anticipated benefits of the transactions may not be realized fully or at all, or may take longer to realize than expected. Actual operating, technological, strategic and revenue opportunities, if achieved at all, may be less significant than expected or may take longer to achieve than anticipated. If we are not able to achieve these objectives and realize the anticipated benefits and synergies expected from the NexTier merger and the Ulterra acquisition within the anticipated timing or at all, our business, financial condition and operating results may be adversely affected.

Our future results following the NexTier merger and the Ulterra acquisition will suffer if we do not effectively manage our expanded operations.

Following the NexTier merger and the Ulterra acquisition, the size and geographic footprint of our business has increased. Our future success will depend, in part, upon our ability to manage this expanded business, which may pose substantial challenges for management, including challenges related to the management and monitoring of new operations and geographies and associated increased costs and complexity. We may also face increased scrutiny from governmental authorities as a result of the increase in the size of our business. There can be no assurances that we will be successful or that we will realize the expected operating efficiencies, cost savings, revenue enhancements or other benefits currently anticipated from the NexTier merger and the Ulterra acquisition.

The NexTier merger and the Ulterra acquisition may result in a loss of customers, distributors, suppliers, vendors, landlords, joint venture partners and other business partners and may result in the modification or termination of existing contracts.

Following the NexTier merger and the Ulterra acquisition, some of our, NexTier’s or Ulterra’s customers, distributors, suppliers, vendors, landlords, joint venture partners and other business partners may modify, terminate or scale back their current or prospective business relationships with us. Some customers may not wish to source a larger percentage of their needs from a single company or may feel that we are too closely allied with one of their competitors. If relationships with customers, distributors, suppliers, vendors, landlords, joint venture partners and other business partners are adversely affected by the NexTier merger or the Ulterra acquisition, or if we lose the benefits of our contracts or those of NexTier or Ulterra, our business and financial performance following the transactions could suffer.

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 September 30, 2023.


							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)
July 2023		—	$	—		—	$	281,031
August 2023		—	$	—		—	$	281,031
September 2023		1,607,561	$	14.54		—	$	281,031
Total		1,607,561				—

(1)

We withheld 1,607,561 shares during the third quarter of 2023 with respect to employees’ tax withholding obligations upon the settlement of performance unit awards and the vesting of 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, as amended , the Patterson-UTI Energy, Inc. 2021 Long-Term Incentive Plan, as amended, the NexTier Oilfield Solutions Inc. Equity and Incentive Award Plan and the NexTier Oilfield Solutions Inc. (Former C&J Energy) Management Incentive Plan, and not pursuant to the stock buyback program.

(2)

ITEM 5. Other Information

(c) During the three months ended September 30, 2023, certain of our officers and directors listed below adopted or terminated trading arrangements for the sale of shares of our common stock in amounts and prices determined in accordance with a formula set forth in each such plan:

Plans

Number of

Rule

Non-Rule

Shares to

Name and Title

Action

Date

10b5-1

be Sold

Expiration

Andy Smith, Chief Financial Officer

Termination

August 6, 2023 (1)

Plan terminated August 6, 2023

James C. Stewart, Director

Adoption

September 22, 2023

198,000

December 31, 2024

(1)

10b5-1 Plan adopted on November 3, 2022.

ITEM 6. Exhibits

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


2.1		Agreement and Plan of Merger, dated as of June 14, 2023, by and among Patterson-UTI Energy, Inc., Pecos Merger Sub Inc., Pecos Second Merger Sub LLC and NexTier Oilfield Solutions Inc. (filed June 15, 2023 as Exhibit 2.1 to our Current Report on Form 8-K and incorporated herein by reference).

2.2		First Amendment to Agreement and Plan of Merger, dated July 27, 2023, by and between Patterson-UTI Energy, Inc. and NexTier Oilfield Solutions Inc. (filed July 28, 2023 as Exhibit 2.1 to our Current Report on Form 8-K and incorporated herein by reference).

2.3		Agreement and Plan of Merger, dated as of July 3, 2023, by and among Patterson-UTI Energy, Inc., PJ Merger Sub Inc., PJ Second Merger Sub LLC, BEP Diamond Holdings Corp. and BEP Diamond Topco L.P. (filed July 5, 2023 as Exhibit 2.1 to our Current Report on Form 8-K and incorporated herein by reference).

3.1		Restated Certificate of Incorporation (filed September 1, 2023 as Exhibit 3.3 to our Current Report on Form 8-K and incorporated herein by reference).

3.2		Amended and Restated Bylaws of Patterson-UTI Energy, Inc., effective June 14, 2023 (filed June 15, 2023 as Exhibit 3.1 to our Current Report on Form 8-K and incorporated herein by reference).

4.1		Second Supplemental Indenture, dated September 13, 2023, between Patterson-UTI Energy, Inc. and U.S. Bank Trust Company, National Association, as trustee (filed September 13, 2023 as Exhibit 4.1 to our Current Report on Form 8-K and incorporated herein by reference).

4.2		Form of 7.15% Senior Notes due 2033 (included in Exhibit 4.1 above).

10.1+		Amendment to the Patterson-UTI Energy, Inc. 2021 Long-Term Incentive Plan, as amended (filed September 1, 2023 as Exhibit 10.5 to our Current Report on Form 8-K and incorporated herein by reference).

10.2+		NexTier Oilfield Solutions Inc. Equity and Incentive Award Plan, as amended September 1, 2023 (filed September 1, 2023 as Exhibit 10.3 to our Current Report on Form 8-K and incorporated herein by reference).

10.3+		NexTier Oilfield Solutions Inc. (Former C&J Energy) Management Incentive Plan, as amended September 1, 2023 (filed September 1, 2023 as Exhibit 10.4 to our Current Report on Form 8-K and incorporated herein by reference).

10.4+		Separation Agreement and General Release of Claims, dated September 1, 2023, by and between NexTier Oilfield Solutions Inc. and Robert W. Drummond (filed September 1, 2023 as Exhibit 10.6 to our Current Report on Form 8-K and incorporated herein by reference).

10.5+		Letter Agreement, dated August 30, 2023, by and between Patterson-UTI Energy, Inc. and James M. Holcomb (filed September 1, 2023 as Exhibit 10.7 to our Current Report on Form 8-K and incorporated herein by reference).

10.6		Fourth Amendment to Credit Agreement, dated August 29, 2023, by and among Patterson-UTI Energy, Inc., Wells Fargo Bank, National Association, as administrative agent, letter of credit issuer, swing line lender and a lender and each of the other letter of credit issuers and lenders party thereto (filed September 1, 2023 as Exhibit 10.2 to our Current Report on Form 8-K and incorporated herein by reference).

10.7		Term Loan Agreement, dated August 29, 2023, by and among Patterson-UTI Energy, Inc., as borrower, Wells Fargo Bank, National Association, as administrative agent and lender and the other lenders party thereto (filed September 1, 2023 as Exhibit 10.1 to our 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.INS*		Inline XBRL Instance Document – the instance document does not appear in the Interactive Data File because its XBRL tags are embedded within the Inline XBRL document.

101.SCH*		Inline XBRL Taxonomy Extension Schema Document


101.CAL*		Inline XBRL Taxonomy Extension Calculation Linkbase Document

101.DEF*		Inline XBRL Taxonomy Extension Definition Linkbase Document

101.LAB*		Inline XBRL Taxonomy Extension Label Linkbase Document

101.PRE*		Inline XBRL Taxonomy Extension Presentation Linkbase Document

104		The cover page from our Quarterly Report on Form 10-Q for the quarter ended September 30, 2023, has been formatted in Inline XBRL.

* filed herewith.

+ Management contract or compensatory plan.

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: November 9, 2023

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Patterson-UTI Energy (PTEN) 10-Q2023 Q3 Quarterly report

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