Financial Data and Key Metrics Changes - Net income for Q2 2022 was $21.9 million or $0.10 per share, compared to a net loss of $28.8 million or $0.13 per share in Q1 2022 [11] - Adjusted EBITDA forecast for 2022 is now expected to exceed $600 million, with a slight increase in CapEx forecast to $390 million due to rising activity and cost inflation [4][11] Business Line Data and Key Metrics Changes - In contract drilling, average U.S. rig count increased by six rigs to 121, with 127 active rigs currently [5] - Average adjusted rig margin per day increased by $2,220, while average rig revenue per day increased by $2,770 [11] - Pressure pumping revenues reached $238 million, a 26% increase from Q1, with adjusted gross margin improving to $46.9 million [15] - Directional drilling revenues increased by 27% to $54.8 million, with adjusted gross margin improving to $9.4 million [15] Market Data and Key Metrics Changes - Tier 1 super spec rig utilization is greater than 90%, with Patterson-UTI's utilization exceeding 95% [6] - The active rig count is at its highest level since early 2020, indicating strong demand and limited supply [6] Company Strategy and Development Direction - The company is positioned to benefit from strong market fundamentals, focusing on contract drilling, pressure pumping, and directional drilling services [19] - Plans to push day rates and contract terms while maintaining a disciplined approach to activity growth [19] - Emphasis on technology in directional drilling to improve wellbore quality and efficiency [9] Management's Comments on Operating Environment and Future Outlook - Management believes the industry is in a multi-year upcycle, with U.S. oilfield service companies showing financial discipline [18] - Anticipation of continued increases in rig activity and pricing, with constraints on rig supply positively impacting market pricing [25][27] Other Important Information - The company has approximately $440 million of future day rate drilling revenue under term contracts, up from $400 million at the end of Q1 [12] - The company expects to generate approximately $15.5 million of revenue in Colombia for Q3, with adjusted gross margin of approximately $4.8 million [14] Q&A Session Summary Question: Rig count and future activity - Management confirmed five additional rigs are committed to work in 2022, with continued increases expected despite some constraints on rig supply [25] Question: Contract coverage and day rates - Management indicated that day rates are increasing rapidly, and they expect to extend contract lengths as they negotiate for 2023 [27] Question: Pressure pumping capacity - Management stated that while they are currently focused on 12 spreads, they are open to adding more if market conditions warrant [36] Question: CapEx and supply chain - Management noted that lead times for equipment are around six months, prompting an increase in CapEx to secure necessary items for next year [43] Question: Labor issues - Management acknowledged ongoing challenges in recruiting but emphasized successful efforts to find and retain personnel [51] Question: Cash flow and working capital - Management expects working capital increases to be limited in the second half of the year, projecting positive cash flow for 2022 [56] Question: Colombia market conditions - Management reported that operations in Colombia remain stable, with no anticipated changes due to the political climate [57] Question: Utilization of less efficient rigs - Management believes there is a low probability of operators accepting less efficient rigs, as their customer base is focused on increasing activity with Tier 1 super spec rigs [60]

Form 10-Q ☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the quarterly period ended March 31, 2022 or ☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 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 i ...

Financial Data and Key Metrics Changes - The company reported a significant increase in average adjusted margin in the U.S., which rose by $1,720 per day in Q1 2022, with expectations for further growth of $1,100 per day in Q2 2022 [5][8] - Total adjusted EBITDA for 2022 is now expected to exceed $500 million, reflecting strong pricing momentum for services [8] - The rig count in the U.S. increased by nine rigs sequentially to 115 rigs in Q1 2022 [8] Business Line Data and Key Metrics Changes - In contract drilling, revenues and margins increased significantly due to higher activity and day rates, with average adjusted margin per rig day reaching $7,170 [9] - Pressure pumping revenues improved to $190 million in Q1 2022, with adjusted gross margin rising to $32.1 million, aided by a sales and use tax refund [12] - Directional drilling revenues increased by 23% to $43.3 million in Q1 2022, with expectations for revenues to reach approximately $50 million in Q2 2022 [16] Market Data and Key Metrics Changes - The leading edge day rates for Tier 1 rigs are now in the upper $20,000 range, with total day rates exceeding $30,000 including ancillary equipment [6] - In Colombia, contract drilling revenues increased to $17 million in Q1 2022, up from $15.8 million in the previous quarter [9] Company Strategy and Development Direction - The company is focused on increasing contract backlog and securing longer-term contracts due to rising demand and limited supply of rigs [6][10] - Management anticipates continued pricing increases in the market for equipment and services, indicating a strong pricing environment not seen in a decade [27] Management's Comments on Operating Environment and Future Outlook - Management noted that the increase in oil and gas demand is primarily driven by the reopening of world economies rather than geopolitical events [22] - The company expects the market for its services to remain tight, with operators needing to commit to higher prices to secure equipment and crews [26] - There is an expectation of a step-up in rig count in 2023 as larger public operators begin to increase their programs [67] Other Important Information - The company is maintaining its 2022 capital expenditure forecast at approximately $350 million, with a focus on the first half of the year to mitigate supply chain issues [19] - Increased working capital was a drag on cash flow in Q1 2022, but management expects this to moderate and cash balances to increase over the year [20] Q&A Session Summary Question: Pricing and Rig Revenue Expectations - Management indicated that there is significant upside potential for average rig revenue and margins, with expectations for continued upward movement in pricing [32][34] Question: Rig Count Projections - Management revised their year-end rig count projection to above 700 rigs, citing strong market conditions [39] Question: Contract Duration and Pricing - The majority of contracts are expected to roll to higher prices, with a shift towards longer contract durations due to market tightness [41] Question: Supply Chain and Labor Issues - Management acknowledged challenges in hiring and retaining labor but does not foresee a strong need for significant wage increases at this time [35] Question: Future Rig Demand and Upgrades - Management confirmed that there are sufficient existing rigs that can be upgraded to meet demand, with no plans for new builds [51]

Operations and Fleet - As of December 31, 2021, the company operated a fleet of 192 marketed land-based drilling rigs in the U.S. and Colombia, with 73 rigs in West Texas and 33 in Appalachia[34]. - The average active U.S. rig count increased to 106 in Q4 2021, up from 80 in Q3 2021, partly due to the acquisition of 13 active rigs from Pioneer Energy Services Corp.[23]. - The company ended Q4 2021 with 11 active pressure pumping spreads, with an expected average of 11 active spreads in Q1 2022[24]. - The company has invested approximately $409 million over the last three years to modify and upgrade its drilling fleet[37]. - Average rigs operating per day in the U.S. decreased from 149 in 2019 to 82 in 2021, with 1,662 wells drilled in 2021 compared to 2,690 in 2019[43]. - Pressure pumping equipment totaled approximately 1.1 million horsepower as of December 31, 2021, with 497 units in operation[48]. Financial Performance - The average oil price per barrel in Q4 2021 was $77.45, showing a recovery from the lows experienced in 2020[20]. - Capital expenditures for 2021 were approximately $166 million, with a forecast increase to $170 million for 2022 due to rising activity levels[25]. - The contract drilling backlog in the U.S. increased from approximately $301 million in 2020 to $325 million in 2021, with 22% expected to remain after 2022[59]. - Approximately 57% of consolidated operating revenues in 2021 came from the ten largest customers, with one customer accounting for approximately $216 million, or 16% of total revenues[58]. - The company recorded a $220 million charge in Q4 2021 related to the abandonment of 43 legacy, non-super-spec rigs due to limited commercial opportunity[43]. - A charge of $32.2 million was recorded in Q4 2021 for the abandonment of approximately 0.2 million horsepower within the pressure pumping fleet[49]. Acquisitions and Divestitures - The acquisition of Pioneer Energy Services was completed on October 1, 2021, valued at approximately $278 million, enhancing the company's contract drilling capabilities[27]. - The company sold its acquired well servicing rig business for $43 million in cash on December 31, 2021, presenting the results as a discontinued operation[30]. Technology and Innovation - The EcoCell™ lithium battery hybrid energy management system was commercialized to reduce fuel consumption and emissions on drilling rigs[64]. - The company continues to enhance technology offerings, including the Cortex® operating system for rig performance and the GenAssist™ application for fuel efficiency[45]. - The company abandoned certain directional drilling equipment totaling $2.5 million in Q4 2021 due to advances in technology rendering those assets obsolete[54]. Employee Relations and Safety - The company had approximately 5,000 full-time employees as of January 31, 2022, with employee relations considered satisfactory[66]. - The company trained over 3,500 employees on its Code of Business Conduct and Ethics in 2021[72]. - The company has implemented safety protocols in response to the COVID-19 pandemic, allowing many office-based employees to work from home[69]. - The company is committed to diversity and inclusion, requiring new supervisors and managers to attend training on these topics[71]. Regulatory and Environmental Considerations - The company is subject to numerous federal, state, and local regulations that could increase operational costs and affect business[75]. - The company faces potential legislative and regulatory changes regarding hydraulic fracturing that could impact operations and costs[83]. - The company monitors and assesses new policies related to greenhouse gas emissions and climate change, which may affect operations[89]. - The company does not anticipate significant capital expenditures for environmental control facilities in the foreseeable future[74]. Risk Management and Insurance - The company maintains liability and other forms of insurance to mitigate risks associated with its operations[91]. - The company has indemnification agreements with many customers, but these may be limited or unenforceable under certain circumstances[91]. - The company maintains various types of insurance coverage, including a $1.5 million deductible for workers' compensation and a $10 million deductible for general liability[92]. - The company self-insures several risks, including loss of earnings and most cybersecurity risks[92]. - The company retains the risk for any loss in excess of insurance policy limits or exclusions[93]. Financial Position and Borrowings - As of December 31, 2021, the applicable margin on LIBOR rate loans was 1.75% and on base rate loans was 0.75%[291]. - The company had no borrowings outstanding under its revolving credit facility as of December 31, 2021[291]. - Under the Reimbursement Agreement, the company is obligated to pay Scotiabank interest at LIBOR plus 2.25% per annum for any amounts not paid on demand[292]. - The company has exposure to interest rate market risk associated with borrowings under the Credit Agreement[290]. Seasonality and Market Conditions - Seasonality has not significantly affected the company's overall operations, although there is slower activity toward the end of the calendar year[95]. - The carrying values of cash and cash equivalents, trade receivables, and accounts payable approximate fair value due to their short-term maturity[293]. - The company utilizes numerous independent subcontractors and multiple suppliers for raw materials and services[96].

Financial Data and Key Metrics Changes - For Q4 2021, the company reported a net loss of $362 million or $1.68 per share, which included pre-tax charges totaling $286 million [17] - The adjusted EBITDA for 2022 is expected to exceed $450 million, which is more than $100 million above the CapEx forecast of approximately $350 million [7][18] - The average rig margin per day during Q4 decreased to $5,450 due to increased labor and rig reactivation costs [19] Business Line Data and Key Metrics Changes - In contract drilling, total revenue increased by 46% and adjusted gross margin increased by 26% [19] - Pressure pumping profitability improved significantly, with adjusted gross margin rising to $20.9 million on $183 million of revenues in Q4 [23] - Directional drilling adjusted gross margin for Q4 was $1 million, which included a $4 million non-cash write-off of inventory [25] Market Data and Key Metrics Changes - The U.S. rig count is projected to be between 650 to 700 for the industry in 2022 [39] - The company expects to generate approximately $16 million of revenue in Colombia for Q1 2022 [20] Company Strategy and Development Direction - The company plans to focus on high return, quick payback opportunities for CapEx, with a majority directed towards maintenance and reactivation [8][32] - The company is increasing its quarterly dividend to $0.04 per share, reflecting improved cash flow [8] - The company aims to upgrade approximately 20 rigs to Tier 1 status in 2022, with expected paybacks ranging from 1 to 3 years [22] Management's Comments on Operating Environment and Future Outlook - Management expressed optimism about a multiyear up cycle in the oilfield services sector due to tight premium equipment availability and improving pricing [30][31] - The company anticipates strong EBITDA growth year-on-year, driven by higher activity and improved pricing [32] - Management noted that labor remains tight but compensation increases have been implemented to address potential challenges [81] Other Important Information - The company repaid a $50 million balance on its term loan, resulting in approximately $741 million of net debt outstanding as of December 31, 2021 [27] - The company has a total of 107 Tier 1 super-spec rigs in the U.S., with 95% utilization [11] Q&A Session Summary Question: Guidance for 2022 and rig count expectations - Management expects the rig count in 2022 to be between 650 to 700, with improving pricing and profitability across businesses [39][40] Question: Daily gross margins expectations - Management indicated that daily gross margins are expected to improve, with some rigs earning over $30,000 per day [42][44] Question: Term contracts and pricing - Management confirmed that term contracts are rolling up and will not be dilutive to expected realized day rates [55][58] Question: Pressure pumping margins - Management expects continued progression in pressure pumping gross margins throughout the year, potentially reaching high teens [71][73] Question: Rig upgrades and costs - Management noted that upgrading Tier 2 rigs to Tier 1 super-spec could be costly, with their own upgrades costing about $2 million each [46][47] Question: Directional drilling growth - Management highlighted the impressive growth in directional drilling and plans to roll out new technology to improve profitability [82]

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, 2021 or ☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from to Commission file number 1-39270 Patterson-UTI Energy, Inc. (Exact name of registrant as specified in its charter) Delaware 75-2504748 (State or other jurisdiction ...

Patterson-UTI Energy, Inc. (NASDAQ:PTEN) Q3 2021 Earnings Conference Call October 28, 2021 10:00 AM ET Company Participants James Drickamer - VP, IR Andy Hendricks - President, CEO & Director Andrew Smith - EVP & CFO Conference Call Participants Ian Macpherson - Piper Sandler Connor Lynagh - Morgan Stanley Keith Mackey - RBC Capital Markets Waqar Syed - ATB Capital Markets Vaibhav Vaishnav - Coker & Palmer Operator Good morning. My name is Julianne and I will be your conference operator today. At this time, ...

PART I — FINANCIAL INFORMATION This part provides the unaudited condensed consolidated financial statements and management's discussion and analysis of financial condition and results of operations [ITEM 1. Financial Statements](index=3&type=section&id=ITEM%201.%20Financial%20Statements) This section presents unaudited condensed consolidated financial statements and notes, reporting reduced net loss and decreased assets and equity [Unaudited Condensed Consolidated Balance Sheets](index=3&type=section&id=Unaudited%20condensed%20consolidated%20balance%20sheets) This section presents the company's financial position, detailing assets, liabilities, and equity at specific dates Condensed Consolidated Balance Sheet Highlights (in thousands): | Metric | June 30, 2021 | December 31, 2020 | | :-------------------------- | :------------ | :------------------ | | Total Assets | $3,073,306 | $3,299,069 | | Total Liabilities | $1,265,589 | $1,283,010 | | Total Stockholders' Equity | $1,807,717 | $2,016,059 | [Unaudited Condensed Consolidated Statements of Operations](index=4&type=section&id=Unaudited%20condensed%20consolidated%20statements%20of%20operations) This section outlines the company's revenues, expenses, and net loss for the reported periods Net Loss and EPS (in thousands, except per share data): | Metric | Three Months Ended June 30, 2021 | Three Months Ended June 30, 2020 | Six Months Ended June 30, 2021 | Six Months Ended June 30, 2020 | | :-------------------------- | :------------------------------- | :------------------------------- | :----------------------------- | :----------------------------- | | Net Loss | $(103,309) | $(150,332) | $(209,722) | $(585,054) | | Basic Net Loss Per Share | $(0.55) | $(0.81) | $(1.12) | $(3.10) | | Diluted Net Loss Per Share | $(0.55) | $(0.81) | $(1.12) | $(3.10) | Total Operating Revenues (in thousands): | Period | 2021 | 2020 | Change | | :----- | :--- | :--- | :----- | | Three Months Ended June 30 | $291,774 | $250,380 | +16.5% | | Six Months Ended June 30 | $532,703 | $696,307 | -23.5% | [Unaudited Condensed Consolidated Statements of Comprehensive Loss](index=5&type=section&id=Unaudited%20condensed%20consolidated%20statements%20of%20comprehensive%20loss) This section details the company's comprehensive loss, including net loss and other comprehensive income/loss items Total Comprehensive Loss (in thousands): | Period | 2021 | 2020 | | :----- | :--- | :--- | | Three Months Ended June 30 | $(103,054) | $(149,637) | | Six Months Ended June 30 | $(209,049) | $(585,745) | [Unaudited Condensed Consolidated Statements of Changes in Stockholders' Equity](index=6&type=section&id=Unaudited%20condensed%20consolidated%20statements%20of%20changes%20in%20stockholders'%20equity) This section reports changes in stockholders' equity, including net loss, stock-based compensation, and treasury stock transactions - Total stockholders' equity decreased from **$2,016,059 thousand** at December 31, 2020, to **$1,807,717 thousand** at June 30, 2021, primarily due to net loss and treasury stock purchases[16](index=16&type=chunk) Key Changes in Stockholders' Equity (Six Months Ended June 30, 2021, in thousands): | Item | Amount | | :-------------------------- | :------- | | Net Loss | $(209,722) | | Stock-based compensation | $11,825 | | Payment of cash dividends | $(7,523) | | Purchase of treasury stock | $(3,522) | [Unaudited Condensed Consolidated Statements of Cash Flows](index=7&type=section&id=Unaudited%20condensed%20consolidated%20statements%20of%20cash%20flows) This section summarizes cash flows from operating, investing, and financing activities for the reported periods Cash Flow Summary (Six Months Ended June 30, in thousands): | Activity | 2021 | 2020 | Change | | :-------------------------- | :------- | :------- | :------- | | Net cash provided by operating activities | $44,197 | $219,333 | -79.8% | | Net cash used in investing activities | $(41,651) | $(114,336) | -63.5% | | Net cash used in financing activities | $(11,045) | $(32,444) | -65.9% | | Cash and cash equivalents at end of period | $216,682 | $246,781 | -12.2% | [Notes to Unaudited Condensed Consolidated Financial Statements](index=8&type=section&id=Notes%20to%20unaudited%20condensed%20consolidated%20financial%20statements) This section provides detailed explanations and disclosures for the unaudited condensed consolidated financial statements [Note 1. Basis of Presentation](index=8&type=section&id=Note%201.%20Basis%20of%20Presentation) This note outlines the basis of preparation for the interim financial statements and significant accounting policies - The unaudited interim condensed consolidated financial statements are prepared in accordance with SEC rules and should be read in conjunction with the annual Form 10-K[20](index=20&type=chunk) - The U.S. dollar is the functional currency for all operations, except for Canadian operations which use the Canadian dollar[21](index=21&type=chunk) - Recently adopted accounting standards (ASU 2016-13 on credit losses, ASU 2018-15 on capitalizing implementation costs, ASU 2018-13 on fair value measurements, ASU 2019-12 on income taxes) had no material impact on the consolidated financial statements[22](index=22&type=chunk)[23](index=23&type=chunk)[24](index=24&type=chunk)[25](index=25&type=chunk) [Note 2. Credit Losses](index=9&type=section&id=Note%202.%20Credit%20Losses) This note discusses the company's accounting policy for expected credit losses and related impacts - The company adopted ASU 2016-13 (CECL) on January 1, 2020, for measuring expected credit losses, which did not have a material impact on financial statements[27](index=27&type=chunk)[28](index=28&type=chunk) - No credit loss expense was recorded during the three and six months ended June 30, 2021[29](index=29&type=chunk) [Note 3. Revenues](index=9&type=section&id=Note%203.%20Revenues) This note details revenue recognition policies and disaggregates revenue by primary segments - Primary revenue-generating segments include contract drilling, pressure pumping, and directional drilling, with revenue recognized over time as services are performed[30](index=30&type=chunk)[32](index=32&type=chunk) - Revenue from oil and natural gas working interests is excluded from ASC Topic 606[35](index=35&type=chunk) Accounts Receivable and Contract Liabilities (in millions): | Metric | June 30, 2021 | December 31, 2020 | | :------------------- | :------------ | :------------------ | | Accounts receivable | $194 | $158 | | Contract liabilities | $0.5 | $0.6 | - Recorded **$2.3 million** in early termination revenue during the six months ended June 30, 2021, for performance obligations satisfied in 2020, due to collectability becoming probable[42](index=42&type=chunk) [Note 4. Inventory](index=11&type=section&id=Note%204.%20Inventory) This note provides a breakdown of the company's inventory composition Inventory Composition (in thousands): | Category | June 30, 2021 | December 31, 2020 | | :-------------------- | :------------ | :------------------ | | Finished goods | $315 | $600 | | Work-in-process | $424 | $802 | | Raw materials and supplies | $33,024 | $31,683 | | **Total Inventory** | **$33,763** | **$33,085** | [Note 5. Property and Equipment](index=11&type=section&id=Note%205.%20Property%20and%20Equipment) This note presents the net carrying amount of property and equipment and discusses impairment considerations Property and Equipment, Net (in thousands): | Metric | June 30, 2021 | December 31, 2020 | | :-------------------------- | :------------ | :------------------ | | Property and equipment, net | $2,511,977 | $2,761,041 | - No impairment related to the marketability or condition of drilling rigs was recorded during the three and six months ended June 30, 2021[44](index=44&type=chunk) [Note 6. Goodwill and Intangible Assets](index=11&type=section&id=Note%206.%20Goodwill%20and%20Intangible%20Assets) This note details the balances and amortization of goodwill and other intangible assets - Goodwill was fully impaired in the first quarter of 2020, resulting in no goodwill balance as of June 30, 2021, following a **$395 million** impairment charge[46](index=46&type=chunk)[48](index=48&type=chunk) Intangible Assets, Net Carrying Amount (in thousands): | Category | June 30, 2021 | December 31, 2020 | | :-------------------- | :------------ | :------------------ | | Customer relationships | $1,114 | $1,243 | | Developed technology | $22,192 | $28,257 | | Internal use software | $751 | $587 | | **Total** | **$24,057** | **$30,087** | - Amortization expense on intangible assets was approximately **$6.3 million** for the six months ended June 30, 2021, down from **$10.6 million** in the prior year[48](index=48&type=chunk) [Note 7. Accrued Liabilities](index=12&type=section&id=Note%207.%20Accrued%20Liabilities) This note provides a detailed breakdown of the company's accrued liabilities Accrued Liabilities (in thousands): | Category | June 30, 2021 | December 31, 2020 | | :---------------------------------- | :------------ | :------------------ | | Salaries, wages, payroll taxes and benefits | $35,316 | $37,627 | | Workers' compensation liability | $62,179 | $70,847 | | Property, sales, use and other taxes | $18,559 | $10,666 | | Insurance, other than workers' compensation | $7,427 | $8,462 | | Accrued interest payable | $10,636 | $11,325 | | Accrued restructuring expenses | $8,314 | $14,310 | | Other | $23,864 | $21,767 | | **Total Accrued Liabilities** | **$166,295** | **$175,004** | [Note 8. Long-Term Debt](index=13&type=section&id=Note%208.%20Long-Term%20Debt) This note outlines the company's long-term debt obligations, including terms, covenants, and repayment schedules Long-Term Debt (in thousands): | Category | June 30, 2021 | December 31, 2020 | | :------------------------------------------ | :------------ | :------------------ | | Term Loan Agreement (Maturing June 2022) | $50,000 | $50,000 | | 3.95% Senior Notes | $509,505 | $509,505 | | 5.15% Senior Notes | $349,250 | $349,250 | | Less deferred financing costs and discounts | $(6,859) | $(7,271) | | **Total** | **$901,896** | **$901,484** | - The company had **$50 million** outstanding under the Term Loan Agreement at a LIBOR-based interest rate of **1.48%** as of June 30, 2021, maturing in June 2022[52](index=52&type=chunk) - The Credit Agreement provides a **$600 million** revolving credit facility, with no borrowings outstanding and approximately **$600 million** available capacity at June 30, 2021[57](index=57&type=chunk)[61](index=61&type=chunk) - The company was in compliance with all debt covenants at June 30, 2021[55](index=55&type=chunk)[60](index=60&type=chunk) Principal Repayment Requirements of Long-Term Debt (as of June 30, 2021, in thousands): | Year ending December 31, | Amount | | :----------------------- | :----- | | 2021 | $0 | | 2022 | $50,000 | | 2023 | $0 | | 2024 | $0 | | 2025 | $0 | | Thereafter | $858,755 | | **Total** | **$908,755** | [Note 9. Commitments and Contingencies](index=16&type=section&id=Note%209.%20Commitments%20and%20Contingencies) This note discloses the company's various commitments, including letters of credit, equipment purchases, and legal proceedings - Outstanding letters of credit totaled **$63.7 million** at June 30, 2021, primarily for insurance collateral[77](index=77&type=chunk) - Commitments to purchase major equipment amounted to approximately **$53.0 million**[78](index=78&type=chunk) - Remaining minimum obligation under proppant and chemical purchase agreements was approximately **$8.4 million**, expiring in 2021 and 2022[79](index=79&type=chunk) - Legal proceedings are not expected to have a material adverse effect on financial condition, cash flows, or results of operations[80](index=80&type=chunk) [Note 10. Stockholders' Equity](index=16&type=section&id=Note%2010.%20Stockholders'%20Equity) This note details changes in stockholders' equity, including dividends, stock buybacks, and equity plans - The Stockholder Rights Agreement expired on **April 21, 2021**[81](index=81&type=chunk) - A cash dividend of **$0.02 per share** was approved on July 28, 2021, to be paid on September 16, 2021[82](index=82&type=chunk) - As of June 30, 2021, approximately **$130 million** remained authorized under the stock buyback program[83](index=83&type=chunk) Treasury Stock Acquisitions (Six Months Ended June 30, 2021, in thousands): | Metric | Shares | Cost | | :------------------------------------------ | :------- | :----- | | Treasury shares at beginning of period | 83,402,322 | $1,366,313 | | Acquisitions pursuant to long-term incentive plan | 428,665 | $3,522 | | Treasury shares at end of period | 83,830,987 | $1,369,835 | [Note 11. Stock-based Compensation](index=17&type=section&id=Note%2011.%20Stock-based%20Compensation) This note describes the company's stock-based compensation plans and related expenses - The Patterson-UTI Energy, Inc. 2021 Long-Term Incentive Plan was approved on June 3, 2021, authorizing approximately **13.5 million shares**[86](index=86&type=chunk) - No stock options were granted during the six months ended June 30, 2021 or 2020[87](index=87&type=chunk) Non-Vested Restricted Stock Units Outstanding (as of June 30, 2021): | Type | Number of Shares | | :-------------------------- | :--------------- | | Time Based | 3,268,802 | | Performance Based | 359,315 | - **621,400 shares** were issued in April 2021 to settle the 2018 Performance Units[92](index=92&type=chunk) Phantom Units Compensation Expense (in thousands): | Period | 2021 | 2020 | | :-------------------------- | :--- | :--- | | Three Months Ended June 30 | $1,000 | $200 | | Six Months Ended June 30 | $1,500 | $200 | [Note 12. Income Taxes](index=19&type=section&id=Note%2012.%20Income%20Taxes) This note explains the company's effective income tax rates and significant factors influencing them Effective Income Tax Rate: | Period | 2021 | 2020 | | :-------------------------- | :--- | :--- | | Three Months Ended June 30 | 13.4% | 11.4% | | Six Months Ended June 30 | 15.0% | 13.3% | - The **higher effective tax rate** in 2021 was primarily due to the non-deductible portion of goodwill impairment in 2020 and state rate changes in 2021, partially offset by a valuation allowance in 2021[96](index=96&type=chunk)[97](index=97&type=chunk) [Note 13. Earnings Per Share](index=20&type=section&id=Note%2013.%20Earnings%20Per%20Share) This note presents basic and diluted earnings per share calculations and potentially dilutive securities Net Loss Per Common Share: | Metric | Three Months Ended June 30, 2021 | Three Months Ended June 30, 2020 | Six Months Ended June 30, 2021 | Six Months Ended June 30, 2020 | | :-------------------------- | :------------------------------- | :------------------------------- | :----------------------------- | :----------------------------- | | Basic | $(0.55) | $(0.81) | $(1.12) | $(3.10) | | Diluted | $(0.55) | $(0.81) | $(1.12) | $(3.10) | - Potentially dilutive securities totaling **10,361 thousand shares** (2021) and **9,101 thousand shares** (2020) were excluded from diluted EPS calculations as their inclusion would have been anti-dilutive[103](index=103&type=chunk) [Note 14. Business Segments](index=20&type=section&id=Note%2014.%20Business%20Segments) This note provides financial information disaggregated by the company's reportable business segments - The company operates three reportable business segments: contract drilling, pressure pumping, and directional drilling, along with other operations including oilfield rentals, equipment servicing, electrical controls and automation, and oil and natural gas working interests[104](index=104&type=chunk)[106](index=106&type=chunk) Total Revenues by Segment (Three Months Ended June 30, in thousands): | Segment | 2021 | 2020 | | :---------------- | :------- | :------- | | Contract drilling | $142,264 | $171,476 | | Pressure pumping | $111,991 | $59,533 | | Directional drilling | $24,869 | $11,742 | | Other operations | $18,251 | $11,460 | | **Total Revenues** | **$291,774** | **$250,380** | Loss Before Income Taxes by Segment (Six Months Ended June 30, in thousands): | Segment | 2021 | 2020 | | :---------------- | :--------- | :--------- | | Contract drilling | $(106,850) | $(434,760) | | Pressure pumping | $(63,660) | $(104,040) | | Directional drilling | $(10,033) | $(24,980) | | Other operations | $(7,843) | $(29,126) | | Corporate | $(38,551) | $(54,982) | | **Total Loss Before Income Taxes** | **$(246,665)** | **$(674,541)** | [Note 15. Fair Values of Financial Instruments](index=22&type=section&id=Note%2015.%20Fair%20Values%20of%20Financial%20Instruments) This note discloses the fair values of the company's financial instruments, particularly outstanding debt - The carrying values of cash and cash equivalents, trade receivables, and accounts payable approximate fair value due to their short-term maturity[108](index=108&type=chunk) Fair Values of Outstanding Debt (in thousands): | Debt Type | Carrying Value (June 30, 2021) | Fair Value (June 30, 2021) | Carrying Value (Dec 31, 2020) | Fair Value (Dec 31, 2020) | | :---------------- | :----------------------------- | :------------------------- | :----------------------------- | :------------------------- | | Term Loan Agreement | $50,000 | $50,000 | $50,000 | $50,000 | | 3.95% Senior Notes | $509,505 | $516,397 | $509,505 | $471,019 | | 5.15% Senior Notes | $349,250 | $366,655 | $349,250 | $319,560 | | **Total Debt** | **$908,755** | **$933,052** | **$908,755** | **$840,579** | [Note 16. Restructuring Expenses](index=22&type=section&id=Note%2016.%20Restructuring%20Expenses) This note details the restructuring plan implemented and associated expenses by segment - A restructuring plan was implemented in Q2 2020, resulting in **$38.3 million** in charges, and was completed in Q3 2020 with no additional expenses in 2021[109](index=109&type=chunk)[200](index=200&type=chunk) Restructuring Expenses by Segment (Six Months Ended June 30, 2020, in thousands): | Category | Contract Drilling | Pressure Pumping | Directional Drilling | Other Operations | Corporate | Total | | :----------------------- | :---------------- | :--------------- | :------------------- | :--------------- | :-------- | :---- | | Severance costs | $1,821 | $3,460 | $503 | $501 | $215 | $6,500 | | Contract termination costs | — | $20,373 | — | — | — | $20,373 | | Other exit costs | $523 | $194 | $827 | — | — | $1,544 | | ROU asset abandonments | $86 | $7,304 | $1,845 | — | $686 | $9,921 | | **Total** | **$2,430** | **$31,331** | **$3,175** | **$501** | **$901** | **$38,338** | [Note 17. Subsequent Event](index=23&type=section&id=Note%2017.%20Subsequent%20Event) This note describes significant events occurring after the balance sheet date, specifically a merger agreement - On July 5, 2021, the company entered into a merger agreement to acquire Pioneer Energy Services Corp. for up to **26,275,000 shares** of common stock and **$30 million cash**[112](index=112&type=chunk) - All Pioneer debt will be retired in connection with the transaction, which is expected to close in the fourth quarter of 2021, subject to regulatory and stockholder approvals[112](index=112&type=chunk)[113](index=113&type=chunk) [ITEM 2. Management's Discussion and Analysis of Financial Condition and Results of Operations](index=27&type=section&id=ITEM%202.%20Management's%20Discussion%20and%20Analysis%20of%20Financial%20Condition%20and%20Results%20of%20Operations) This section analyzes operations, segment performance, oil price impact, the Pioneer acquisition, and the company's strong liquidity [Management Overview and Recent Developments](index=27&type=section&id=Management%20Overview%20and%20Recent%20Developments) This section provides an overview of the company's operations, market conditions, and strategic initiatives - The company is a Houston-based oilfield services company, primarily operating land-based drilling rigs and pressure pumping equipment[122](index=122&type=chunk) - Oil prices (WTI-Cushing) experienced significant volatility, recovering from **negative $36.98/barrel** in April 2020 to **$74.21/barrel** in June 2021, averaging **$66.19/barrel** in Q2 2021[125](index=125&type=chunk) Operational Activity Highlights: | Metric | Q2 2021 | Q1 2021 | Q3 2021 (Expected) | | :-------------------------- | :------ | :------ | :----------------- | | Average Active Rig Count | 73 | 69 | ~81 | | Average Active Pressure Pumping Spreads | ~8 | 7 | ~9 | - The 2021 capital expenditure forecast was increased to approximately **$165 million** due to improving activity levels and increasing oilfield cost inflation[128](index=128&type=chunk) - On July 5, 2021, the company agreed to acquire Pioneer Energy Services Corp. for up to **26,275,000 shares** of common stock and **$30 million cash**, with closing expected in Q4 2021[130](index=130&type=chunk)[132](index=132&type=chunk) Operating Revenues by Segment (Three Months Ended June 30, in thousands): | Segment | 2021 | % of Total | 2020 | % of Total | | :---------------- | :------- | :--------- | :------- | :--------- | | Contract drilling | $141,732 | 48.6% | $171,134 | 68.3% | | Pressure pumping | $111,991 | 38.4% | $59,533 | 23.8% | | Directional drilling | $24,869 | 8.5% | $11,742 | 4.7% | | Other operations | $13,182 | 4.5% | $7,971 | 3.2% | | **Total** | **$291,774** | **100.0%** | **$250,380** | **100.0%** | [Results of Operations](index=30&type=section&id=Results%20of%20Operations) This section analyzes the company's financial performance across its various business segments [Contract Drilling](index=30&type=section&id=Contract%20Drilling) This section details the financial and operational performance of the contract drilling segment Contract Drilling Performance (Three Months Ended June 30, in thousands, except per day data): | Metric | 2021 | 2020 | % Change | | :-------------------------------- | :------- | :------- | :------- | | Revenues | $141,732 | $171,134 | (17.2)% | | Operating loss | $(58,229) | $(30,742) | 89.4% | | Operating days | 6,652 | 7,450 | (10.7)% | | Average revenue per operating day | $21.31 | $22.97 | (7.2)% | | Average direct operating costs per operating day | $15.05 | $11.69 | 28.7% | | Capital expenditures | $24,042 | $42,501 | (43.4)% | Contract Drilling Performance (Six Months Ended June 30, in thousands, except per day data): | Metric | 2021 | 2020 | % Change | | :-------------------------------- | :------- | :------- | :------- | | Revenues | $275,233 | $438,498 | (37.2)% | | Operating loss | $(106,850) | $(434,760) | (75.4)% | | Operating days | 12,835 | 18,685 | (31.3)% | | Average revenue per operating day | $21.44 | $23.47 | (8.6)% | | Average direct operating costs per operating day | $13.99 | $13.41 | 4.3% | | Capital expenditures | $35,469 | $91,946 | (61.4)% | - As of June 30, 2021, the rig fleet included **198 APEX® rigs**, with **150 classified as super-spec rigs**[138](index=138&type=chunk) - Contract drilling backlog was approximately **$210 million** as of June 30, 2021, with about **20%** expected to remain at June 30, 2022[140](index=140&type=chunk) [Pressure Pumping](index=31&type=section&id=Pressure%20Pumping) This section details the financial and operational performance of the pressure pumping segment Pressure Pumping Performance (Three Months Ended June 30, in thousands, except job data): | Metric | 2021 | 2020 | % Change | | :-------------------------- | :------- | :------- | :------- | | Revenues | $111,991 | $59,533 | 88.1% | | Operating loss | $(23,921) | $(68,554) | (65.1)% | | Average active spreads | 8 | 4 | 100.0% | | Fracturing jobs | 105 | 35 | 200.0% | | Average revenue per fracturing job | $1,006.36 | $1,549.71 | (35.1)% | | Capital expenditures | $8,921 | $1,947 | 358.2% | Pressure Pumping Performance (Six Months Ended June 30, in thousands, except job data): | Metric | 2021 | 2020 | % Change | | :-------------------------- | :------- | :------- | :------- | | Revenues | $187,830 | $184,640 | 1.7% | | Operating loss | $(63,660) | $(104,040) | (38.8)% | | Average active spreads | 7 | 7 | (—)% | | Fracturing jobs | 176 | 124 | 41.9% | | Average revenue per fracturing job | $994.88 | $1,413.11 | (29.6)% | | Capital expenditures | $12,989 | $16,227 | (20.0)% | - The pressure pumping market remains oversupplied, with the company having approximately **1.4 million horsepower** in its fleet as of June 30, 2021[141](index=141&type=chunk) [Directional Drilling](index=32&type=section&id=Directional%20Drilling) This section details the financial and operational performance of the directional drilling segment Directional Drilling Performance (Three Months Ended June 30, in thousands): | Metric | 2021 | 2020 | % Change | | :-------------------------- | :------- | :------- | :------- | | Revenues | $24,869 | $11,742 | 111.8% | | Operating loss | $(5,110) | $(14,385) | (64.5)% | | Average jobs per day | 28 | 12 | 133.3% | | Capital expenditures | $1,219 | $2,044 | (40.4)% | Directional Drilling Performance (Six Months Ended June 30, in thousands): | Metric | 2021 | 2020 | % Change | | :-------------------------- | :------- | :------- | :------- | | Revenues | $44,539 | $46,227 | (3.7)% | | Operating loss | $(10,033) | $(24,980) | (59.8)% | | Average jobs per day | 25 | 23 | 8.7% | | Capital expenditures | $1,323 | $4,052 | (67.3)% | [Other Operations](index=32&type=section&id=Other%20Operations) This section details the financial and operational performance of the company's other business activities Other Operations Performance (Three Months Ended June 30, in thousands): | Metric | 2021 | 2020 | % Change | | :-------------------------- | :------- | :------- | :------- | | Revenues | $13,182 | $7,971 | 65.4% | | Operating loss | $(3,287) | $(10,355) | (68.3)% | | Capital expenditures | $3,429 | $2,808 | 22.1% | Other Operations Performance (Six Months Ended June 30, in thousands): | Metric | 2021 | 2020 | % Change | | :-------------------------- | :------- | :------- | :------- | | Revenues | $25,101 | $26,942 | (6.8)% | | Operating loss | $(7,843) | $(29,126) | (73.1)% | | Capital expenditures | $6,173 | $8,072 | (23.5)% | - Oil and natural gas revenues increased by **$3.2 million** in Q2 2021 (YoY) due to favorable crude oil market prices (**$66.19/barrel** in Q2 2021 vs. **$27.81/barrel** in Q2 2020)[160](index=160&type=chunk) - Oilfield rentals business experienced a **$3.1 million decrease** in service volume for the six months ended June 30, 2021 (YoY)[184](index=184&type=chunk) [Corporate](index=33&type=section&id=Corporate) This section presents corporate-level financial items not allocated to specific business segments Corporate Financials (Three Months Ended June 30, in thousands): | Metric | 2021 | 2020 | % Change | | :-------------------------------- | :------- | :------- | :------- | | Selling, general and administrative | $19,045 | $19,197 | (0.8)% | | Merger and integration expenses | $1,148 | $0 | NA | | Net gain on asset disposals | $(3,211) | $(1,222) | 162.8% | | Credit loss expense | $0 | $4,551 | (100.0)% | | Interest income | $20 | $334 | (94.0)% | | Interest expense | $10,704 | $10,984 | (2.5)% | | Capital expenditures | $439 | $373 | 17.7% | Corporate Financials (Six Months Ended June 30, in thousands): | Metric | 2021 | 2020 | % Change | | :-------------------------------- | :------- | :------- | :------- | | Selling, general and administrative | $36,978 | $41,223 | (10.3)% | | Merger and integration expenses | $1,148 | $0 | NA | | Net gain on asset disposals | $(4,052) | $(2,461) | 64.6% | | Credit loss expense | $0 | $5,606 | (100.0)% | | Interest income | $159 | $991 | (84.0)% | | Interest expense | $20,713 | $22,208 | (6.7)% | | Capital expenditures | $619 | $1,304 | (52.5)% | - Merger and integration expenses of **$1.148 million** were recognized in Q2 2021 related to the Pioneer Energy Services Corp. acquisition[164](index=164&type=chunk)[191](index=191&type=chunk) - Other operating expenses (income), net, in 2020 included a **$9.2 million charge** related to a capacity reservation agreement for sand[165](index=165&type=chunk)[192](index=192&type=chunk) - Lower interest expense in 2021 was due to the early repayment of long-term debt in Q4 2020[194](index=194&type=chunk) [Income Taxes](index=38&type=section&id=Income%20Taxes_MD%26A) This section discusses the company's income tax expense and effective tax rate Effective Income Tax Rate: | Period | 2021 | 2020 | | :-------------------------- | :--- | :--- | | Three Months Ended June 30 | 13.4% | 11.4% | | Six Months Ended June 30 | 15.0% | 13.3% | - The **higher effective tax rate** in 2021 was primarily due to the non-deductible portion of goodwill impairment in 2020 and state rate changes in 2021, partially offset by a valuation allowance in 2021[196](index=196&type=chunk)[197](index=197&type=chunk) [Liquidity and Capital Resources](index=38&type=section&id=Liquidity%20and%20Capital%20Resources) This section assesses the company's ability to meet its financial obligations and fund operations - As of June 30, 2021, the company had approximately **$215 million** in working capital, including **$217 million** in cash and cash equivalents[202](index=202&type=chunk) - The company had approximately **$600 million** available under its revolving credit facility at June 30, 2021, with no outstanding borrowings[203](index=203&type=chunk) - Outstanding debt totaled **$909 million** at June 30, 2021, and the company was in compliance with all debt covenants[207](index=207&type=chunk) - Cash flows from operating activities were **$44.2 million** for the six months ended June 30, 2021, with **$56.6 million** used for capital expenditures and **$7.5 million** for dividends[213](index=213&type=chunk) - The 2021 capital expenditure forecast was increased to approximately **$165 million**[214](index=214&type=chunk) - As of June 30, 2021, approximately **$130 million** remained authorized under the stock buyback program[217](index=217&type=chunk) [Adjusted EBITDA](index=41&type=section&id=Adjusted%20EBITDA) This section presents Adjusted EBITDA as a non-GAAP measure for evaluating business performance - Adjusted EBITDA is a non-GAAP financial measure used to assess business performance[220](index=220&type=chunk) Adjusted EBITDA (in thousands): | Period | 2021 | 2020 | | :-------------------------- | :------- | :------- | | Three Months Ended June 30 | $35,439 | $14,086 | | Six Months Ended June 30 | $70,808 | $101,618 | [Critical Accounting Policies and Estimates](index=41&type=section&id=Critical%20Accounting%20Policies%20and%20Estimates) This section highlights key accounting policies and estimates that require significant management judgment - There have been no material changes in critical accounting policies and estimates since the 2020 Annual Report on Form 10-K[222](index=222&type=chunk) [Recently Issued Accounting Standards](index=41&type=section&id=Recently%20Issued%20Accounting%20Standards_MD%26A) This section refers to disclosures on recently issued accounting standards - Refer to Note 1 of the unaudited condensed consolidated financial statements for a discussion of recently issued accounting standards[223](index=223&type=chunk) [Volatility of Oil and Natural Gas Prices and its Impact on Operations and Financial Condition](index=41&type=section&id=Volatility%20of%20Oil%20and%20Natural%20Gas%20Prices%20and%20its%20Impact%20on%20Operations%20and%20Financial%20Condition) This section discusses the impact of fluctuating oil and natural gas prices on the company's financial results - The company's financial performance is highly dependent on volatile oil and natural gas prices, which averaged **$66.19 per barrel** (WTI-Cushing) in Q2 2021[224](index=224&type=chunk) - A decline in demand, prolonged low prices, or reduced customer access to capital could materially adversely affect operating results, financial condition, and cash flows[226](index=226&type=chunk) [ITEM 3. Quantitative and Qualitative Disclosures About Market Risk](index=42&type=section&id=ITEM%203.%20Quantitative%20and%20Qualitative%20Disclosures%20About%20Market%20Risk) The company faces interest rate market risk from its variable-rate Term Loan Agreement and revolving credit facility - The company has interest rate market risk exposure from its Term Loan Agreement (**$50 million** outstanding at LIBOR-based **1.48%** as of June 30, 2021)[227](index=227&type=chunk)[228](index=228&type=chunk) - A **one percent increase** in the interest rate on the Term Loan Agreement would increase annual cash interest expense by **$0.5 million**[228](index=228&type=chunk) - The revolving credit facility and reimbursement agreement also expose the company to variable interest rate risk, though no amounts were outstanding or disbursed under these at June 30, 2021[229](index=229&type=chunk)[230](index=230&type=chunk) [ITEM 4. Controls and Procedures](index=42&type=section&id=ITEM%204.%20Controls%20and%20Procedures) The company's management, including the CEO and CFO, concluded that disclosure controls and procedures were effective as of June 30, 2021, and reported no material changes in internal control over financial reporting during the quarter - The CEO and CFO concluded that disclosure controls and procedures were effective as of June 30, 2021[233](index=233&type=chunk) - There were no material changes in internal control over financial reporting during the most recently completed fiscal quarter[234](index=234&type=chunk) PART II — OTHER INFORMATION This part covers legal proceedings, risk factors, equity security sales, and exhibits [ITEM 1. Legal Proceedings](index=43&type=section&id=ITEM%201.%20Legal%20Proceedings) This section describes ongoing legal matters and their potential impact on the company - The company is party to various legal proceedings arising in the normal course of business[236](index=236&type=chunk) - The outcome of these proceedings is not expected to have a material adverse effect on the company's financial condition, cash flows, or results of operations[236](index=236&type=chunk) [ITEM 1A. Risk Factors](index=43&type=section&id=ITEM%201A.%20Risk%20Factors) This section outlines significant risks, particularly for the Pioneer acquisition, covering closing conditions, business disruptions, costs, litigation, and integration - Completion of the Pioneer acquisition is subject to various conditions, including stockholder and regulatory approvals, which may delay or prevent the transaction[237](index=237&type=chunk)[239](index=239&type=chunk) - Uncertainty surrounding the Pioneer acquisition and the planned divestiture of Pioneer's well service rig business could disrupt existing business relationships[240](index=240&type=chunk) - The company expects to incur **significant transaction costs** for the Pioneer acquisition, which may exceed anticipations and will be borne even if the acquisition is not completed[241](index=241&type=chunk)[242](index=242&type=chunk) - Litigation related to the Pioneer acquisition could result in injunctions, delaying or preventing the closing, and incur **substantial costs**[243](index=243&type=chunk)[244](index=244&type=chunk) - There is a risk of inability to successfully integrate Pioneer's business or realize the anticipated benefits and synergies from the acquisition[247](index=247&type=chunk)[248](index=248&type=chunk)[250](index=250&type=chunk) - The expanded size, complexity, and international footprint of the business post-acquisition will pose **substantial management challenges**[251](index=251&type=chunk) [ITEM 2. Unregistered Sales of Equity Securities and Use of Proceeds](index=46&type=section&id=ITEM%202.%20Unregistered%20Sales%20of%20Equity%20Securities%20and%20Use%20of%20Proceeds) This section reports on Q2 2021 common stock purchases, primarily for employee tax withholding, not under the stock buyback program Common Stock Purchases (Quarter Ended June 30, 2021): | Period Covered | Total Number of Shares Purchased | Average Price Paid per Share | | :------------- | :------------------------------- | :--------------------------- | | April 2021 | 255,650 | $6.52 | | May 2021 | — | $— | | June 2021 | 173,015 | $10.72 | | **Total** | **428,665** | | - These purchases were **primarily for employees' tax withholding obligations** upon the settlement of performance unit awards and vesting of restricted stock units, not under the stock buyback program[254](index=254&type=chunk) - As of June 30, 2021, approximately **$130 million** remained authorized under the stock buyback program[253](index=253&type=chunk)[254](index=254&type=chunk) [ITEM 6. Exhibits](index=47&type=section&id=ITEM%206.%20Exhibits) This section lists all exhibits filed with the Quarterly Report on Form 10-Q, including corporate governance, incentive plans, and certifications - Exhibits include the Restated Certificate of Incorporation, Bylaws, 2021 Long-Term Incentive Plan, Executive Officer Restricted Stock Unit Award Agreement, Employment Agreements, and certifications by the CEO and CFO[255](index=255&type=chunk) [Signature](index=48&type=section&id=Signature) This section confirms the official signing and submission of the report - The report was signed by C. Andrew Smith, Executive Vice President and Chief Financial Officer, on August 3, 2021[257](index=257&type=chunk)

Financial Data and Key Metrics Changes - For Q2 2021, the company reported a net loss of $103 million or $0.55 per share, while consolidated adjusted EBITDA was $35.4 million [15] - Average rig count improved to 73 rigs in Q2 from 69 rigs in Q1, with average rig margin per day at $6,250 [16] - Pressure Pumping revenues increased almost 50% sequentially to $112 million, with gross margin improving to $9.7 million [18] Business Line Data and Key Metrics Changes - In Contract Drilling, the average rig count increased to 73 rigs, with expectations to improve to an average of 81 rigs in Q3 [16][17] - Pressure Pumping saw an increase in active spreads from 8 to 9, with revenues expected to improve by more than 30% to approximately $150 million in Q3 [19] - Directional Drilling revenues increased 26% to $24.9 million, with expectations for further growth to $34 million in Q3 [20] Market Data and Key Metrics Changes - The company noted general oilfield cost inflation across segments due to improving activity levels and labor market tightness [15] - The company has term contracts for drilling rigs providing approximately $210 million of future day rate drilling revenue [17] Company Strategy and Development Direction - The company is focusing on increasing activity and pricing in response to rising demand for drilling and completion services [24] - Investments in high-demand items, including specialty drill pipe and ESG-related technologies, are part of the increased CapEx forecast of $165 million for 2021 [22] - The company is also pursuing an acquisition of Pioneer Energy Services, expected to close in Q4, which will enhance its operational capabilities [25] Management's Comments on Operating Environment and Future Outlook - Management expressed optimism about increasing E&P demand for services, driven by commodity price stability and the company's performance [24] - The company anticipates a "fear of missing out" scenario in 2022, leading to increased pricing and margins as operators scramble for high-spec rigs [36][39] Other Important Information - The company plans to pay a quarterly cash dividend of $0.02 per share on September 16, 2021 [22] - The company is upgrading engines on existing pump trailers to Tier 4 dual fuel, which is expected to improve operational efficiency and margins [11][30] Q&A Session Summary Question: Can you provide insights on frac fleet upgrades and CapEx? - The company is changing engines to Tier 4 dual fuel, with some CapEx allocated for this upgrade, which is seen as a cost-effective solution [30] Question: What is the outlook for rig demand from public E&Ps? - Management noted a broad-based increase in rig demand from private, midsized public, and large international E&Ps [32] Question: Can you discuss pricing for ESG-friendly fleets? - The company believes that offering Tier 4 dual fuel will allow for better pricing and margins compared to conventional fleets [34] Question: What are the expectations for land drilling margins? - Management anticipates a potential return to higher margins as operators may face challenges in securing desired rigs [39] Question: Will there be a decline in rig demand in Q4? - Management indicated that the typical decline in Q4 may not occur this year due to favorable commodity prices [40] Question: Can you elaborate on the incremental rigs from a major E&P? - The company expects to grow share within existing drilling programs rather than a significant ramp-up in overall drilling activity [43]

UNITED STATES SECURITIES AND EXCHANGE COMMISSION Washington, D.C. 20549 Form 10-Q ☑ QUARTERLY REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the quarterly period ended March 31, 2021 or ☐ TRANSITION REPORT PURSUANT TO SECTION 13 OR 15(d) OF THE SECURITIES EXCHANGE ACT OF 1934 For the transition period from to Commission file number 1-39270 Patterson-UTI Energy, Inc. (Exact name of registrant as specified in its charter) Delaware 75-2504748 (State or other jurisdiction of i ...