Patterson-UTI Energy, Inc. (PTEN) Earnings
Patterson-UTI Energy, Inc. is expected to report next earnings on October 28, 2026 (in NaN days), with a consensus EPS estimate of $0.03. PTEN has beaten EPS estimates in 6 of its last 12 reported quarters (average surprise +33.9% over the last four).
| Report date | EPS est | EPS actual | Surprise | Revenue | Rev. surprise |
|---|---|---|---|---|---|
| Jul 30, 2026 | $-0.04 | $-0.05 | -26.3% | $1.2B | +6.6% |
| Apr 23, 2026 | $-0.10 | $-0.06 | +40.0% | $1.1B | +1.2% |
| Feb 4, 2026 | $-0.11 | $-0.02 | +81.8% | $1.2B | +4.9% |
| Oct 22, 2025 | $-0.10 | $-0.06 | +40.0% | $1.2B | +6.9% |
| Jul 23, 2025 | $-0.04 | $-0.06 | -50.0% | $1.2B | +3.9% |
| Apr 23, 2025 | $-0.04 | $0.00 | +106.5% | $1.3B | +8.6% |
| Feb 5, 2025 | $-0.10 | $-0.12 | -20.0% | $1.2B | -7.9% |
| Oct 23, 2024 | $-0.03 | $-2.50 | -9027.4% | $1.4B | +8.4% |
| Jul 24, 2024 | $0.09 | $0.05 | -44.4% | $1.3B | -5.5% |
| May 1, 2024 | $0.13 | $0.15 | +15.4% | $1.5B | -0.3% |
| Feb 14, 2024 | $0.19 | $0.15 | -21.1% | $1.6B | +5.2% |
| Jul 26, 2023 | $0.44 | $0.45 | +2.3% | $759M | -2.9% |
Source: company filings + earnings calendar. For informational purposes only — not investment advice.
Earnings call summary
Q2 FY2026 · July 30, 2026
AI summary of management’s prepared remarks and analyst Q&A. For informational purposes only — not investment advice.
Management highlights
### Market & Industry Dynamics - Geopolitical uncertainty has reinforced the value of secure U.S. oil and natural gas production, with a constructive long-term outlook supported by an oil strip of ~$70 per barrel through the end of 2027, above most customers' 2026 budget assumptions of $60 per barrel or lower. - The industry is increasingly differentiated: high-specification, technologically advanced equipment is in limited supply, and operators prioritize efficiency, reliability, and capability, creating upside for providers like Patterson UTI that have invested in upgraded assets. - Private E&P operators are driving current activity growth, responding faster to higher oil prices, while large public E&P operators have maintained disciplined activity so far, with discussions about increasing activity gaining momentum focused on high-spec equipment. ### Drilling Services Operational Highlights - Rig activity and pricing recovered faster than expected in Q2 2026, with new contract pricing up 10-15% sequentially from Q1, and upgraded rigs commanding day rates several thousand dollars higher than standard super spec rigs. - Outside the Permian, high-quality rigs are effectively sold out with minimal idle capacity available for reactivation; demand is growing in the Permian, with customers reluctant to lose active rigs, supporting further pricing improvement. - Industry trends are shifting toward longer laterals (over 10% of recent wells have laterals longer than 4 miles, 4x 2025 levels) and deeper shale targets (activity more than doubled year-over-year), driving demand for upgraded rigs with higher capacity and advanced automation. ### Completion Services Operational Highlights - The segment saw meaningful sequential improvement in Q2 2026, with fully booked frac calendars and more favorable pricing than expected; natural gas-powered completion capacity is effectively fully utilized industry-wide, with most available capacity being older, less efficient diesel assets that customers prefer not to use. - The company's strategy is focused on improving fleet quality rather than adding total horsepower: it is retiring older diesel equipment and adding 100% natural gas-powered Emerald Frac assets, with ~90% of active horsepower expected to be gas-powered by year-end 2026. - 50 industry rigs added since spring 2026 have not yet translated to full incremental completion demand, which will support growth in 2027 as activity flows through the chain. ### Drilling Products Operational Highlights - The segment delivered record international revenue in Q2 2026 despite Middle East conflict disruptions, with sequential growth across key geographies, confirming attractive long-term international growth opportunities. - Downhole tools, a complementary extension of the core drill bit business, have grown significantly since end-2025, and geothermal demand has doubled over the same period, creating new long-term growth avenues. ### Financial & Capital Update - Total Q2 2026 revenue was $1.228 billion, up 10% sequential from Q1. The company ended Q2 with $203 million cash and no outstanding borrowings under its $500 million revolving credit facility, after refinancing 2028 notes to extend maturity to 2036, with no senior maturities until 2029. - The company is exiting its contract drilling business in Colombia due to aging assets, unfavorable political changes that reduced investment attractiveness; $26 million in non-cash charges related to this exit were recorded in Q2. - The board approved a quarterly dividend of 10 cents per share, payable September 15, 2026. 2026 full-year adjusted free cash flow is expected to cover all dividend payments, with free cash flow expected to improve meaningfully in 2027.
Guidance
- For Q3 2026: Drilling Services adjusted gross profit is expected to be ~$145 million, with an average rig count of ~100 rigs, exiting the quarter above that level. - For Q3 2026: Completion Services adjusted gross profit is expected to be ~$140 million, supported by near-full asset utilization and additional pricing improvement from Q2 levels. - For Q3 2026: Drilling Products adjusted gross profit is expected to be ~$40 million, supported by Canadian seasonal recovery and higher U.S. activity. Other segment adjusted gross profit is expected to be ~$5 million, G&A ~$70 million, and depreciation/depletion/amortization ~$225 million. - 2026 full-year capital expenditures, net of asset sale proceeds, are maintained at ~$600 million, focused on rig upgrades and natural gas-powered completion assets. Available frac horsepower in H2 2026 is expected to stay broadly flat with H1, as new gas asset additions offset retired diesel capacity. - Management maintains its commitment to return at least 50% of 2026 adjusted free cash flow to shareholders. Free cash flow is expected to improve in H2 2026, and grow meaningfully in 2027 and beyond. - Management expects further activity and pricing improvement across segments into 2027, with growth driven by both private E&P activity and increasing demand from public E&P operators focused on high-spec assets.
Segment performance
Drilling Services: Q2 2026 revenue was $374 million, with an adjusted gross profit of $114 million (or $134 million excluding non-cash charges from the Columbia contract drilling exit). The segment recorded 8,361 operating days with a 92% average operating rate. It contributed 30.5% of total Q2 revenue. Completion Services: Q2 2026 revenue was $754 million, with an adjusted gross profit of $123 million. Results benefited from a largely full frac calendar and improved pricing across part of the fleet. It contributed 61.4% of total Q2 revenue. Drilling Products: Q2 2026 revenue was $91 million, with an adjusted gross profit of $37 million. This was the segment's highest quarterly revenue since the 2023 Altera acquisition, with a 14% sequential revenue increase even with Middle East conflict disruptions and Canadian seasonal headwinds. Downhole tools represent approximately 5% of segment revenue. The U.S. accounts for roughly 70% of segment revenue. It contributed 7.4% of total Q2 revenue. Other Revenue: Q2 2026 revenue was $9 million, with an adjusted gross profit of $7 million, driven by higher oil prices for non-operated oil-weighted E&P interests. It contributed 0.7% of total Q2 revenue.
Risks & headwinds
- Continued commodity price volatility could impact customer activity levels and investment plans, even though current strip pricing supports a constructive outlook. - Geopolitical uncertainty, including ongoing conflict in the Middle East, created supply chain and logistics disruptions for international operations in Q2 2026, and could continue to impact international activity. - Political changes in Colombia reduced the commercial attractiveness of the market, leading to the full exit of the contract drilling business there; similar political risk exists in other international markets including Argentina. - Rising tungsten prices, driven by increased demand outside the oil and gas industry, have increased input costs for drill bits, partially mitigated by a shift toward steel body drill bits that reduces tungsten use. - Working capital headwinds are more pronounced than usual in 2026 due to faster-than-expected activity growth, which temporarily reduced free cash flow in Q2.
Analyst Q&A
Q: What contract duration do new rig reactivations and upgrades have, and what is the difference in activity pacing between private and public E&P customers? /
A: Patterson UTI never reactivates rigs for only a few wells; all new reactivations and upgrades are for longer-term programs, with most new contracts running at least six months, some much longer, with contracts extending into 2027. Private E&Ps have moved much faster to increase activity than large public E&Ps, which are still finalizing 2027 plans, but discussions with public E&Ps about higher activity are gaining traction, focused on high-spec upgraded rigs.
Q: What are the cost and returns for high-spec rig upgrades, and how many rigs can be upgraded in the near term? /
A: Engineering teams have developed capital-efficient upgrades for existing rigs to increase load capacity to 1 million pounds (required for longer laterals and deeper wells) for roughly $2 million per rig, with a full payback achieved within one year. 10 to 15 rigs can be upgraded in 2026 and early 2027. Larger structural upgrades for deeper plays require higher investment but are secured by three-plus-year contracts with payback early in the contract term.
Q: How sustainable are recent pricing gains, and what is the gap between leading-edge day rates and the fleet average? /
A: For drilling, 10-15% average Q2 price increases on new contracts are locked into term contracts and fully sustainable, with upgraded rigs commanding even higher fixed day rates. For completions, pricing gains are supported by extreme market tightness: most idle completion fleets are older diesel assets that customers do not want, and demand for gas-powered assets far outstrips current supply. Industry-wide, less capital is being invested in new completion capacity than in past cycles, supporting sustained pricing improvements.
Q: Will the company add net new completion capacity after upgrading the fleet, and when? /
A: Management is currently prioritizing pricing recovery for existing capacity over adding net new fleets. The company holds reserved access to Caterpillar equipment delivery slots for 2027, but has not made a final decision to add net capacity, and will wait to evaluate market changes as pricing recovers before committing to expansion. The near-term focus is on improving fleet quality and margins by replacing lower-margin diesel assets with higher-margin gas assets.