Patterson-UTI (PTEN) Q3 2026 earnings review
Patterson-UTI rig demand climbs, while supply delays trim frac profit
Patterson-UTI, an onshore oilfield drilling and pressure-pumping contractor, returned to profit as U.S. rig counts and equipment prices climbed. Revenue rose 14% from a year ago, while cash from operations and asset sales rebounded enough to restart share buybacks. Chief executive Andy Hendricks said customer budgets support further rig additions in 2027, and by our math the fourth-quarter plan lifts segment gross profit excluding one-offs by 22% from a year ago.
| Revenue | $1,342M +14.1% from a year ago |
|---|---|
| Ebitda, excluding one-offs | $264M +20.7% from a year ago |
| U.S. average operating rigs | 101 up from 92 last quarter (exited at 104) |
| Q4 segment gross profit outlook | ~$341M +22% from a year ago by our math |
⚖️ Verdict: 🟢 Bullish
The story got better because the third-quarter cash rebound eased the risk that full-year free cash flow would fall short of the dividend. Drilling rigs and drill bits both beat the company's plan and set up a higher fourth quarter. One caution: sand and trucking delays caused the pressure-pumping division to miss its profit target, and unpaid customer bills rose to $946 million.
The question now is whether rising rig counts and pumping prices can hold into 2027 if oil prices cool or competitors build new fleets. One view is that tight supplies of natural-gas frac equipment and upgraded rigs will keep prices climbing; the other is that oil producers will cap spending while overdue bills keep absorbing cash. First-quarter rig reactivations and the year-end receivables balance will tell.
🐂 Bull Case
Upgraded Rigs Lift Drilling Activity and Pricing
Patterson-UTI rents onshore drilling rigs and directional drilling tools through its Drilling Services division. "The commodity price environment continues to support higher customer budgets, and our discussions indicate the likelihood for additional rig reactivations and increased completion demand in 2027," chief executive Andy Hendricks said. Customers want larger rigs and automated software to "drill deeper wells and longer laterals more efficiently".
- U.S. operating rigs: averaged 101, up 9 from last quarter, and exited September at 104
- Drilling Services revenue: $417.4 million, up 9.8% from a year ago
- Division gross profit excluding one-offs: $148.9 million ($1.47 million per average rig by our math), beating the $145 million target
The division's recovery is gaining speed because oil producers in the Permian and Rockies are paying higher daily rates for structurally upgraded rigs. The fourth-quarter plan calls for 104 average rigs and $150 million in division gross profit excluding one-offs, even after paying to prepare more rigs for early 2027.
What to watch: the U.S. contract drilling backlog in the third-quarter filing. A figure above $365 million would show that newly reactivated rigs are locking in multi-quarter contracts.
Gas-Powered Fleets Drive Higher Frac Prices
Completion Services, the company's pressure-pumping division that fractures rock to release oil and gas, is raising prices by replacing older diesel engines with natural-gas equipment. Natural-gas engines save customers money on fuel, and Hendricks said such fleets remain in short supply across the industry.
Pumping prices rose by a mid-single-digit percentage from the second quarter, lifting division revenue 14.6% from a year ago to $808.3 million. The oilfield services group will have about 90% of its active fleet able to burn natural gas by year-end. It continues to "decommission diesel-powered assets and therefore do not expect active horsepower to increase through the first half of 2027".
Retiring diesel pumps as new Emerald 100%-natural-gas units arrive keeps total industry supply tight, so price hikes flow straight to profit. The fourth-quarter outlook projects $140 million in division gross profit excluding one-offs, up 26.2% from a year ago, with smaller holiday slowdowns than usual.
What to watch: fourth-quarter Completion Services gross profit excluding one-offs against the $140 million target. Meeting it would prove that third-quarter price gains held through the winter holiday period.
Third-Quarter Cash Rebound Covers Full-Year Dividends
A standing concern after the second quarter was whether Patterson-UTI could generate enough second-half cash to cover its roughly $152 million annual dividend after burning cash in the first half. "We generated strong free cash flow during the quarter, reinforcing our confidence in our outlook," finance chief Andy Smith said.
By our math from the nine-month cash flow statement, third-quarter operating cash flow jumped to $300.9 million, up from $119.9 million across the entire first half. Including $45.7 million from asset sales, third-quarter free cash flow under the company's definition reached $205.3 million by our math. That single quarter wiped out the $137.7 million first-half deficit and enabled $24 million in share buybacks.
With nine-month cash generation at $67.5 million by our math, the Houston-based company needs $84.6 million in the fourth quarter to cover the full-year dividend. Smith expects fourth-quarter free cash flow to remain strong and grow meaningfully in 2027, which eases the dividend-coverage concern.
What to watch: fourth-quarter cash flow from operations and asset sales in the full-year report. Generating at least $85 million in free cash flow under the company's formula would fulfill the full-year dividend pledge.
🐻 Bear Case
Sand and Trucking Delays Cut Frac Profit
Completion Services is Patterson-UTI's largest revenue stream, and management had projected $140 million in third-quarter gross profit excluding one-offs on near-full fleet utilization. Even with mid-single-digit price increases, total pumping activity dipped slightly from the second quarter.
Several fracturing fleets sat idle for more hours late in the quarter because of "temporary sand availability constraints in South Texas and trucking delays in the Permian Basin". Those supply bottlenecks held division gross profit excluding one-offs to $132.8 million, missing the company's $140 million target by 5.1% and snapping a four-quarter beat streak.
What to watch: Completion Services gross profit margin excluding one-offs in the fourth quarter. A rebound to the implied 17% level from 16.4% in the third quarter would confirm that sand and trucking bottlenecks were temporary.
Saudi Slowdown Will Trim Record Drill-Bit Profit
The Drilling Products division, which makes Ulterra drill bits used in the United States and the Middle East, had its best quarter since Patterson-UTI bought it in 2023. Revenue rose 20.6% from last quarter to $110.2 million, and gross profit excluding one-offs reached $51.2 million, beating the $40 million plan by 28.0%.
The company credited record U.S. sales per rig and "effective management of challenges related to the conflict in the Middle East". However, the fourth-quarter outlook projects division gross profit excluding one-offs to fall 5% to 10% from the third quarter because of "lower drilling activity in Saudi Arabia due to ongoing geopolitical unrest in the region". That cuts fourth-quarter profit to about $47.4 million at the middle of the range by our math.
What to watch: fourth-quarter Drilling Products gross profit excluding one-offs. A drop larger than 10% would indicate that Middle East conflict is hurting drill-bit shipments beyond Saudi Arabia.
Receivables and Colombia Exit Costs Still Weigh
Management previously said working capital would release cash in the second half after a billing software change delayed customer collections in the spring. In the third quarter, net accounts receivable — unpaid customer bills — rose another $26.0 million from June to $945.7 million, up $222.4 million since December.
By our math, the nine-month working-capital cash drain stayed at $241.6 million, so the third-quarter cash rebound came from higher earnings and asset sales rather than collecting overdue bills. In addition, after booking $21.0 million of Colombia exit charges in the second quarter, the company warned of further Colombia wind-down expenses in the fourth quarter.
What to watch: accounts receivable on the year-end balance sheet. A balance still above $900 million would show that the expected second-half working-capital release did not happen.
Risks this quarter didn't answer
Three standing risks from our prior analysis received no direct numbers in the third-quarter earnings release.
- Public oil producer budgets: Hendricks noted higher 2027 customer budgets in discussions, but the release gave no split showing whether large public producers are adding rigs alongside private operators.
- Industry frac supply in 2027: the company will hold its own active horsepower flat through the first half of 2027, but competitor newbuild deliveries in 2027 remain an open test for pricing.
- Ulterra patent appeal: the release had no update on the Federal Circuit patent-royalty case, which typically appears in the quarterly filing's legal footnote.
👓 Other Themes
Rig Sale Gain Provided Most of Net Income
Patterson-UTI swung to $28.4 million in net income from a $36.4 million loss a year ago, lifting operating margin by 7.1 percentage points to 4.7%. Most of the bottom-line profit came from a $22.1 million gain on sold rigs in other operating income, while the year-ago quarter carried a $20.0 million legal charge; depreciation fell 2.7 percentage points of revenue and direct operating costs fell 1.1 points.
💲 Other KPIs
Net debt — long-term debt minus cash — fell 13.2% from last quarter and 13.4% from a year ago by our math. Total debt held steady at $1.23 billion while cash climbed by $136.1 million in the third quarter to $339.3 million, aided by operating cash flow and $45.7 million in asset-sale proceeds.
Property and equipment purchases fell 9.3% from the second quarter and 2.2% from a year ago, taking 10.5% of third-quarter revenue. Nine-month capital spending reached $413.9 million, or $353.3 million after subtracting $60.6 million of asset-sale proceeds, against the company's earlier full-year net target of about $600 million.
Weighted average diluted shares rose 0.4% from a year ago and 1.1% from the second quarter. Even though the company spent $24 million to buy back stock during the third quarter, swinging from a net loss to positive net income added 3.3 million dilutive shares to the per-share calculation.
🔮 Guidance
New. The plan calls for $150 million, up 0.7% from the third quarter and 13.3% from a year ago by our math, despite extra costs to reactivate rigs and wind down Colombia. The division has beaten its quarterly forecast four times in a row by an average of 4.1%.
New. Management expects $140 million, up 5.4% from the third quarter and 26.2% from a year ago by our math. Higher pricing and steady activity should offset holiday slowdowns, which the company expects to be milder than in prior fourth quarters.
New. The outlook points to $47.4 million at the middle of the range by our math, down from the third quarter's $51.2 million record as Saudi Arabian drilling slows, but still up 38.5% from a year ago.
New. The oilfield services provider expects profit from its remaining working interests to hold near $3.8 million, more than double the $1.5 million earned a year ago.
New. The fleet is set to average 104 rigs in the fourth quarter, matching September's exit rate and up from 101 in the third quarter and 93 a year ago. Management expects to exit 2026 above 104 rigs and reactivate more in early 2027.
New. Overhead costs are planned at $70 million, matching the third quarter and up 12.8% from $62.1 million a year ago.
New. The forecast of $220 million is down slightly from $221.6 million in the third quarter and $220.9 million a year ago.
❓ Key Questions
Did the U.S. drilling contract backlog grow in Q3?
The second-quarter filing showed $365 million in U.S. term-contract drilling backlog, but the earnings release does not include this figure. The third-quarter filing will show whether recent rig reactivations locked in multi-quarter commitments.
Why did accounts receivable keep rising to $946 million?
Management previously blamed a spring billing software change for higher unpaid bills and expected working capital to release cash in the second half. Receivables still rose $26 million in the third quarter, leaving a $242 million nine-month working-capital drain.
Will full-year net capital spending stay near $600 million?
Nine-month capital spending net of asset sales is only $353 million by our math. Reaching the prior $600 million full-year forecast would require $247 million of net spending in the fourth quarter, a figure the release did not update.
What is the fleet-average daily rate on U.S. drilling rigs?
Patterson-UTI stopped publishing average daily drilling revenue and margin in early 2025. Without fleet-wide daily figures, investors cannot measure how quickly higher prices on upgraded rigs are lifting the average across all 104 working rigs.