Baker Hughes US Rig Count Climbs to 580 in Week Ending July 2, Up 41 From Last Year

Baker Hughes counted 580 active US drilling rigs for the week ending July 2, 2026, up 7 from the prior week and 41 above the same week in 2025. That year-over-year gain of 7.6% reflects continued operator willingness to deploy capital in North American basins despite sub-$70 WTI crude. The count draws attention to the tension between a recovering US rig fleet and growing analyst concern about global oil supply balances in 2027.

A Year of Rig Recovery at $69 WTI

One year ago this week, Baker Hughes recorded 539 active US rigs. The 41-rig gain since then represents a 7.6% increase in the active fleet, spread across oil-directed and gas-directed plays. WTI crude traded at $68.78 per barrel on July 3, per OilPrice.com data, up from $68.08 at the July 1 session close as reported in Oil Authority's Hormuz coverage. Brent crude tracked at $72.12 per barrel on the same data source, with CME markets operating on an abbreviated Independence Day eve schedule.

Henry Hub natural gas futures moved to $3.245 per MMBtu in Friday trading, per OilPrice.com, supporting continued gas-directed activity in the Haynesville and Marcellus supply basins. Natural gas rigs typically account for 15 to 20% of the Baker Hughes US total, with oil-directed drilling making up the remaining majority. The full oil-gas breakdown for the week ending July 2 is published in the Baker Hughes downloadable North America Rig Count report released each Friday.

Parent Operators and Permian Concentration

ExxonMobil's 2024 acquisition of Pioneer Natural Resources made it the Permian Basin's largest single operator. Pioneer's former acreage and drilling program now run under the XTO Energy umbrella, ExxonMobil's unconventional exploration and production subsidiary. ExxonMobil has set multi-year Permian production growth targets requiring continued drilling on both the Midland and Delaware sub-basins, according to investor guidance published after the Pioneer transaction closed.

ConocoPhillips holds a major Permian position through its 2021 acquisition of Concho Resources. Large Permian operators have maintained fixed annual rig programs since 2021, setting budgets at the start of the year rather than adjusting week to week based on price moves. Neither company discloses a per-week Permian rig tally separately from its consolidated drilling program reports.

The Supply Math Behind 580 Active Rigs

The EIA's June 2026 Short-Term Energy Outlook projected US crude production at 13.7 million barrels per day for 2026 and 14.2 million bpd for 2027, a 500,000 bpd increase year over year. Dividing that projected growth by 580 active rigs yields an implied 862 barrels per day of incremental annual output per rig, an Oil Authority calculation from EIA STEO and Baker Hughes data. Shale efficiency gains explain the ratio: the US ran more than 1,800 rigs in 2014 to produce roughly 9 million bpd, versus 580 rigs today supporting nearly 14 million bpd.

EIA published its June STEO before the Strait of Hormuz ceasefire announcement on June 30, 2026. The STEO's $95 per barrel Brent average for 2026 has already diverged well below current spot prices of $72 per barrel. No revised EIA forecast incorporating the ceasefire has been released, though both Goldman Sachs and Morgan Stanley have published updated price targets that run below the STEO baseline.

Goldman and Morgan Stanley Flag 2027 Downside

When Oil Authority covered Goldman Sachs' 2027 surplus warning on July 2, Brent traded at $71.33 per barrel. Goldman's analysis found that OPEC+ output will rise from 34.0 million bpd in 2026 to 39.8 million bpd in 2027, a 5.8 million bpd increase against global demand growth of only 2.5 million bpd. That arithmetic implies a potential annualized supply surplus of 3.3 million bpd, before counting the 500,000 bpd of additional US production EIA projects for 2027.

Morgan Stanley cut its Q3 2026 WTI target to $75 per barrel, matching the directional reversal Goldman made when it abandoned its former $82 per barrel Q3 target following the Hormuz ceasefire. Goldman's Q4 2026 projection stands at $80 per barrel. EIA's own 2027 Brent forecast of $79 per barrel, published in June, sits above where both banks now expect the market to trade.

US drillers are adding capacity into a market Goldman and Morgan Stanley both expect to face oversupply in 2027. Production from newly drilled wells typically lags rig deployment by six to twelve months for most shale plays. That places much of the capacity added in the current count cycle directly inside the 2027 window Goldman identified as the highest-risk period for downward price pressure.

Western Canadian Select and the Widening Spread

Western Canadian Select crude traded at $56.23 per barrel on July 2, as reported in Oil Authority's July 2 Goldman surplus coverage. The WCS-WTI differential stood at $12.05 per barrel that session, widening from $10.93 per barrel on July 1 as detailed in Oil Authority's Hormuz inventory article. That $1.12 widening in one session raises the direct cost for Canadian heavy oil producers shipping into US Gulf Coast refinery systems.

The Trans Mountain Expansion pipeline connects Alberta crude to Pacific tidewater, giving producers an alternative route to Gulf Coast pricing. A wider WCS-WTI differential despite elevated TMX throughput suggests heavy oil supply volume, not takeaway capacity, is the primary driver of the current spread. Suncor Energy and Cenovus Energy will report Q2 2026 results in late July, when realized WCS prices and spread impacts will appear in earnings disclosures.