Halliburton Misses Estimates but Flags Gradual North America Recovery
Second-quarter adjusted operating income fell short of analyst expectations, yet management pointed to incremental gains in US drilling and fracking activity through 2026.
Halliburton reported adjusted operating income of $683 million for the second quarter of 2026, missing average analyst expectations of $688.7 million and falling 6.1% from the same period a year earlier. The miss was enough to send shares lower, with third-quarter guidance for the Completion and Production segment adding to the pressure — the outlook for that unit fell short of what analysts had pencilled in.6,5
The oilfield services industry has been caught between two forces this year. North American drilling and fracking demand has been recovering, but not fast enough to offset a meaningful pullback in the Middle East, where war and uncertainty have curtailed operator spending. For a company with Halliburton's scale, the gap between what the recovery can deliver now and what its cost structure requires is real.6,5,2
Halliburton said it was "encouraged" by North American activity, describing incremental improvement in drilling and fracking through 2026. The commentary was cautious rather than bullish. Management acknowledged the recovery does not all happen at once. JPMorgan analyst Arun Jayaram described the "unifying message" across the fracking sector as one of improving service pricing driven by a shrinking supply of equipment — a margin tailwind that takes time to show up in reported numbers.5,6
The Middle East drag is harder to dismiss. SLB and Baker Hughes saw their regional revenues fall 10% and 19% year on year respectively in the first quarter of 2026, according to The Economist. Rystad Energy estimates that damage to oil-and-gas infrastructure in the region could cost $50 billion to repair — a number that implies eventual work but none of it imminent while conflict persists.2
Aberdeen-based subsea equipment firm Ashtead Technology reported that its Middle East business weighed on first-half results, with the company posting revenue of £100.2 million for the period ended mid-2026, a 1% rise from 2025, and an EBITDA margin of 25.0%, down from 27.3% a year earlier. Ashtead's board said in July (2026-07-15) it was comfortable with full-year market expectations only on the assumption that the conflict between the US and Iran eases in the second half. That conditional comfort speaks to how broadly the regional uncertainty is now being priced into services budgets.4
ICE Brent crude front-month was trading at $83.67 per barrel on Monday (2026-08-03), down 0.49% on the session, while WTI was at $80.05, off 0.14%. Those levels reflect a market that has absorbed geopolitical risk without a sharp upward move — not a set-up that typically accelerates discretionary capital spending by E&P operators.5
Saudi Aramco sits at the intersection of several of these threads. The company is considering selling a stake in its sulfur business for up to $7 billion, Reuters reported in June (2026-06-18), as part of a broader asset monetisation programme. Earlier this year it was also reported to be targeting up to $10 billion from real estate asset sales, and last year it closed an $11 billion deal with a BlackRock-led group for a lease of midstream facilities at the Jafurah gas project. The asset sales point to a company managing capital differently from its peak spending years — a signal that Aramco's own capex envelope is not expanding aggressively.3
On Monday (2026-08-03), the US and Saudi Arabia signed a civilian nuclear cooperation agreement, described by Washington as providing American companies access to the Saudi nuclear energy market. The deal sits outside Aramco's hydrocarbon business but adds another dimension to the bilateral relationship — one that has historically shaped how comfortably Saudi Arabia tolerates US pressure on oil output or pricing.7
Iran remains the unresolved variable. The 2019 missile strike on Saudi Aramco infrastructure — attributed to Iranian-backed groups — temporarily knocked out 5% of global oil production. The proxy network that enabled that strike remains in place. An escalation that impairs Aramco's production or shipping lanes would flip the current services-revenue drag into something more acute: disrupted output that forces rapid unplanned maintenance and infrastructure repair, exactly the high-margin emergency work that oilfield services firms are positioned to capture.1,2
The more immediate signal for Halliburton is whether North American activity translates into pricing power quickly enough to offset the continued softness abroad. Service pricing is improving and equipment supply is tightening, but the earnings miss in the second quarter of 2026 shows the arithmetic has not yet turned in the company's favour. The question for the third quarter is whether the incremental North American recovery Halliburton described accelerates — or stays incremental.6,5