Western Energy Services Corp. posts 15% revenue gain and net income return in Q3 2026 as drilling activity rises in Canada and the US
Western Energy Services Corp. wrapped up Q3 2026 in positive territory — something that wasn’t a sure thing just a year ago. The Calgary-based oilfield services company posted revenue of $42.5 million USD (CAD 57.5 million) for the three months ended September 30, 2026… swung to a net income of $2.0 million USD (CAD 2.7 million) from a net loss of $1.6 million USD (CAD 2.2 million).
The turnaround came down to a pickup in drilling activity on both sides of the border. Higher oil prices pushed customers to put more rigs to work across Canada and the US.
Q3 2026 financial results at a glance
The headline numbers tell a pretty clear story. Revenue of $42.5 million USD came in $5.5 million USD — or 15% — above Q3 2025.
Drilling rig utilization surged to 73% from just 24% in Q3 2025 — a 204% increase — with Operating Days rising 37% to 200, driven directly by improved oil prices.
Adjusted EBITDA edged up to $9.8 million USD (CAD 13.3 million) from $9.7 million USD (CAD 13.1 million) — a modest improvement. Higher revenue got partially offset by increased salaries and repair and maintenance costs, a reminder that putting more rigs to work comes with real operational expenses.
Capital spending picked up too. Western added $7.2 million USD (CAD 9.7 million) in property and equipment during Q3 2026, up from $4.1 million USD (CAD 5.5 million) a year earlier, with $4.0 million USD (CAD 5.4 million) of that going toward ELR rig upgrades. It’s a deliberate bet on higher-spec equipment built for complex horizontal drilling programs.
Rising oil prices drove higher drilling demand in both countries
Commodity prices made the difference. West Texas Intermediate crude averaged US$85.89 per barrel in Q3 2026, a 32% increase over Q3 2025. Western Canadian Select rose 35% year-over-year to US$74.93 per barrel (CDN$101.26 per barrel). Both moves tied back to escalating conflict in the Middle East and disruptions to global supply routes.
When producers see prices like that, they drill more. That’s exactly what happened.
Industry data backs it up. The Canadian Association of Energy Contractors reported that total Operating Days in Canada were 16% higher in Q3 2026 than in Q3 2025. In the US, the Baker Hughes rig count averaged 589 active rigs during the quarter, compared to 540 in the prior-year period. Both markets moved in the same direction at the same time — a tailwind Western was well-positioned to catch.
Operational improvements across drilling and well servicing segments
Western’s Canadian drilling operations saw utilization climb to 45% in Q3 2026, up from 33% a year earlier, while Operating Days increased 13% to 1,153. Part of that utilization gain reflects Western’s decision to deregister six Canadian rigs at the end of 2025, which shrunk the denominator in the utilization calculation even as active work held steady.
The US story was sharper. Drilling rig utilization surged to 73% from just 24% in Q3 2025 — a 204% increase — with Operating Days rising 37% to 200, driven directly by improved oil prices. Three US rigs were also deregistered at year-end 2025, focusing the American footprint on active, productive assets.
Day rates held up well on both sides of the border. Canadian revenue per Operating Day came in essentially flat at US$22,500 (CAD 30,405), consistent with Q3 2025. US day rates ticked up 3% to US$34,717, pointing to modest pricing power in a tighter market.
The well servicing segment improved too. Canadian service rig utilization rose to 38% from 24%, and Service Hours grew 12% to 10,986, driven by additional program work from higher industry activity. Revenue per Service Hour came in at US$682 (CAD 921), down 3% from the prior year — a small price concession more than offset by meaningfully higher volume.
Nine-month results lag prior year despite Q3 recovery
The Q3 recovery is real, but it doesn’t erase a softer first half. Revenue for the nine months ended September 30, 2026 totaled $112.0 million USD (CAD 151.3 million), down 5% from $117.7 million USD (CAD 159.1 million) in the same period of 2025, with lower production services revenue as the main drag.
Adjusted EBITDA for the nine-month period was $23.2 million USD (CAD 31.4 million), a 5% decline from $24.4 million USD (CAD 33.0 million). Worth noting: the prior-year figure included $2.7 million USD (CAD 3.6 million) in one-time reorganization costs, so the underlying comparison is a bit closer than the headline suggests.
Despite lower EBITDA, net income for the first nine months was $0.37 million USD (CAD 0.5 million), compared to a net loss of $3.25 million USD (CAD 4.4 million) in the same period of 2025. Lower depreciation and reduced finance costs helped Western stay in positive territory even as revenue trailed last year’s pace.
Western Energy Services Corp. also strengthened its balance sheet by extending debt maturities. The Second Lien Facility now runs to July 2028, and the Credit Facilities extend to January 2028 — or June 2029 under certain conditions. That’s meaningful runway to operate without near-term refinancing pressure.
What the Q3 results mean heading into the rest of 2026
Western heads into Q4 with cautious optimism. Oil-weighted basins show improving momentum, and the company currently has 19 drilling rigs and 17 well servicing rigs operating. Gas-weighted activity remains constrained, though — mixed natural gas fundamentals keep limiting upside in that part of the market.
Geopolitical risk hasn’t gone away. Instability in Eastern Europe and the Middle East, along with US tariff tensions, continue to introduce volatility into commodity prices and broader economic conditions. Western acknowledges that the extent and duration of those pressures remain uncertain.
The company’s 2026 capital budget was set at $18.5 million USD (CAD 25 million), a balanced approach that covers maintenance while allowing selective fleet upgrades. Over the medium term, Western is counting on demand support from growing Canadian LNG export capacity, expanded pipeline access, and domestic energy security initiatives. Whether Q3’s momentum carried into Q4 and beyond depended largely on how those macro factors played out.
Kelly is an experienced writer with 15 years of experience exploring the big stories that shape our world, from tech breakthroughs and space exploration to climate, energy, and the fascinating quirks of science. She has a talent for turning complex ideas into sharp, memorable insights that stay with readers long after they’ve finished reading.
