PATTERSON UTI ENERGY INC Q3 FY2026 earnings call

• U.S. Onshore Recovery: Activity is gaining momentum, led by private operators but shifting toward public operators in 2027. Demand is increasingly focused on premium technology, including advanced digital, automation, AI, and larger rig structures for deeper wells.
• Drilling Services Dynamics: Average day rates have risen from the low $30,000s to the mid $30,000s. Upgraded rigs command premiums several thousand dollars above average. The company has limited low-cost reactivations remaining (8-10 rigs); future growth will come from pricing and contract terms rather than volume additions.
• International Opportunities: Argentina presents tangible near-term opportunities; Venezuela sales included high-spec rigs. Middle East conflict creates logistical challenges but long-term demand remains strong, particularly for drill bits.
• Completion Services Transition: Industry supply is tightening as older diesel-powered equipment becomes uneconomic due to high diesel prices. Nearly 90% of Patterson’s active horsepower will be natural gas-powered by year-end. Lead times for new direct-drive systems exceed one year.
• Capital Allocation Discipline: Management prioritizes free cash flow per share and return on capital over growth for its own sake. Investments are made only where compelling returns exist. Balance sheet strength is preserved, with no senior debt maturities until 2029.
• Free Cash Flow: Strong free cash flow generation continues, supporting dividends ($0.10/share), share repurchases ($62M in Q3), and potential debt reduction or strategic acquisitions.

Drilling Services: Revenue was $417 million with adjusted gross profit of $149 million. U.S. contract drilling averaged 101 rigs (up from 88 at the trough) and 9,249 operating days. Directional drilling saw significant margin expansion. Completion Services: Revenue was $808 million with adjusted gross profit of $133 million. Pricing increased mid-single digits sequentially, though activity was impacted by sand and trucking constraints. Drilling Products: Revenue was $110 million (up 21% sequentially) with adjusted gross profit of $51 million, driven by record international revenue in Latin America and strong U.S. market share gains. Other: Revenue was $6 million with adjusted gross profit of $4 million.

• Q4 2026 Drilling Services: Expect average rig count of approximately 104 rigs, exiting above that level. Adjusted gross profit expected to be approximately $150 million. Note: Includes reactivation costs and wind-down costs in Colombia.
• Q4 2026 Completion Services: Adjusted gross profit expected to be approximately $140 million, reflecting higher pricing vs. Q3, offset by normal seasonal/weather factors.
• Q4 2026 Drilling Products: Adjusted gross profit expected to decline 5-10% sequentially, primarily due to lower anticipated drilling activity in Saudi Arabia.
• Q4 2026 General & Administrative: Expected to remain steady at approximately $70 million.
• Q4 2026 Depreciation, Depletion, Amortization, and Impairment (DD&A): Expected to be approximately $220 million.
• Full Year 2026 CapEx: Net of asset sales proceeds, expected to be less than $600 million.
• 2027 Outlook: Anticipate another step-up in demand with oil-directed activity strengthening. Public operators likely to account for a significant share of rig additions. Free cash flow expected to improve meaningfully in 2027.

• Operational Disruptions: Q3 completions were impacted by non-productive time due to sand availability constraints in South Texas and trucking/driver shortages in the Permian Basin. While temporary, these highlight supply chain vulnerabilities.
• Reactivation Costs: Beyond the initial 8-10 low-cost rig reactivations, further capacity additions require significantly higher pricing to meet return thresholds, posing a risk if pricing does not sustain.
• Geopolitical Instability: The conflict in the Middle East creates logistics, safety, and personnel challenges, potentially limiting near-term growth in key markets like Saudi Arabia, although long-term demand is viewed positively.
• Capital Intensity: The transition to natural gas-powered completion equipment requires substantial capital. If competitors cannot fund new equipment or require higher pricing/contract terms, it may delay industry-wide supply response, but also limits Patterson's ability to rapidly expand without adequate returns.
• Competitive Landscape: Constrained access to capital among competitors creates opportunities for Patterson, but reliance on specific high-spec technologies means execution risks are tied to maintaining technological leadership and managing upgrade schedules effectively.

Q: Analyst Scott Gruber asked about the impact of rigs moving to South America on U.S. competition and what pricing/term conditions would keep rigs in the U.S. vs. deploying them internationally. / A: CEO Andy Hendricks explained that the decision depends on which market offers the best return on investment for activation/shipping. They are upgrading rigs for both markets, evaluating economics carefully. For the U.S., pricing is rising (mid-$30k range) and contract terms are improving (risk shifting back to customers). They lock in longer-term contracts when rates justify de-risking upgrades, otherwise keeping terms shorter to capture upside.

Q: Analyst Saurabh Pant asked if the upcoming rig additions are net industry adds or upgrades, and how this impacts tight completion demand in 2027 given limited completion capacity expansion. / A: Hendricks confirmed some upgrades involve swap-outs while others are net adds, driving rig count increases. Regarding completions, he noted that despite increasing rig counts, they will not invest in adding new frac capacity until pricing recovers sufficiently to justify returns. Pricing had fallen ~30% previously; only ~1/3 has recovered. They expect demand to rise but supply to remain constrained as older diesel assets retire and new natural-gas equipment has >1-year lead times.

Q: Analyst Alexa Brino asked about the magnitude of pricing moves and contract duration for high-spec rigs, and whether the industry will see a meaningful supply response to stronger 2027 completion demand. / A: Hendricks highlighted leading-edge specs like the XC Plus (1.3M lb load) securing 3-year contracts at >$45,000/day. Regarding completions, management stated they will not add industry capacity until pricing recovery allows for returns above cost of capital. Competitors face capital constraints or prioritize other uses, so industry capacity is unlikely to increase significantly in the near term, favoring Patterson’s existing high-quality fleet.

Q: Analyst Eddie Kim asked how much of the 30% prior completion price decline could recover by next year and what recovery level triggers capacity expansion. / A: Hendricks believes full recovery (and potentially more) is possible due to consolidation and competitors diverting capital elsewhere. Smith added that expanding overall industry capacity requires multi-year visibility or different contract structures. Until pricing fully recovers, talking about growing total industry fleet is premature; they focus on high-grading their own fleet rather than capturing share through volume.

Q: Analyst Dan Cutts asked about appetite for sending drilling/completion assets to the Middle East unconventional plays (e.g., Jafura) and logistics trends for ancillary services. / A: Hendricks stated they do not plan to send drilling/completion fleets to mature Middle East markets like Kuwait/Saudi Arabia due to sufficient local contractor capacity and current slowdowns. Their JV with Turnwell provides an efficiency advantage if outsiders are brought in, but they lack excess U.S. capacity to deploy. On logistics, recent sand mine issues in South Texas and driver shortages in the Permian have resolved, with operations returning to full efficiency.