Baker Hughes US Rig Count Climbs 10 to 573 While WTI Settles at $68.86, Permian Margins Thin to $1.86 Per Barrel

Baker Hughes released its weekly North America rig count on Friday, June 27, recording 573 total US active rigs for the week ending June 26. The count gained 10 rigs from 563 the prior week, comprising 440 oil rigs, 125 gas rigs, and 8 miscellaneous units. WTI crude oil settled at $68.86 per barrel on Friday's CME close, the lowest CME settlement since February 2026. That combination frames a widening gap between drilling activity and the commodity prices supporting it.

Basin Breakdown: Permian Reaches 258, Canada Climbs to 197

The Permian Basin added 2 rigs to reach 258 active units for the week. That count sits 12 rigs below year-ago levels, reflecting the year-over-year reduction in Permian drilling that has unfolded since early 2025. Canada staged a stronger weekly recovery, adding 11 rigs to 197 active units. Other major basins held steady: Eagle Ford remained at 44 rigs, Haynesville at 55, Marcellus at 24, and Williston at 28. Granite Wash added 1 rig to 19; the Cana Woodford shed 1 rig to settle at 19.

Iran Agreement Reprices Global Crude 22% Over Four Weeks

WTI crude settled 22.2% below its level of four weeks prior, reaching $68.86 per barrel on Friday's CME close. The US-Iran peace framework agreed on June 14 reopened the Strait of Hormuz to Persian Gulf crude traffic, restoring shipping lanes that markets had priced as largely closed since hostilities began. In April 2026, the EIA's Short-Term Energy Outlook projected Brent averaging $96 per barrel for 2026 and a Q2 Brent peak of $115 per barrel, when Hormuz disruptions cut 9.1 million barrels per day from global supply. Friday's settlement reflects the market's revision of that geopolitical supply-risk premium.

The Breakeven Math: $1.86 Per Barrel Above the Average Permian Floor

The Dallas Federal Reserve's Q1 2026 energy survey found the average breakeven price for a new Permian well at $67 per barrel. At $68.86 WTI, the average operator holds $1.86 per barrel of gross margin before royalties, severance taxes, and gathering costs. Small firms in the Dallas Fed survey cited $68 per barrel as their average breakeven, placing them $0.86 per barrel underwater on unhedged production at current spot prices. Large firms reported a $59 per barrel breakeven, implying $9.86 per barrel of gross margin at Friday's settlement.

The week's 10-rig US gain likely reflects large operators continuing to honor rig contracts agreed before the Iran agreement repriced crude. Small operators face a harder choice: absorb losses on contracted rigs, or pay early-termination fees to idle equipment. The Permian's two-rig gain to 258, still 12 rigs below year-ago levels, indicates the basin is not expanding at current prices. Gas-weighted basins like Haynesville and Marcellus operate on different economics and face less direct exposure to the WTI decline.

Devon Energy Post-Coterra: Large-Operator Economics Across Multiple Basins

Devon Energy (NYSE: DVN) completed its all-stock merger with Coterra Energy on May 7, 2026. Under the terms, each Coterra share converted to 0.70 Devon shares, leaving Devon shareholders with 54% of the combined company and former Coterra shareholders with 46%. CEO Clay Gaspar stated at closing that the merger creates "a premier shale operator with the scale, inventory depth and financial strength to deliver differentiated returns for shareholders through any commodity cycle." The combined company projects 2026 production above 1.6 million barrels of oil equivalent per day, anchored by 750,000 net acres in the core of the Delaware Basin.

Coterra itself resulted from the 2021 merger of Cabot Oil and Gas and Cimarex Energy. That Cabot Oil and Gas lineage brought substantial Marcellus Shale natural gas exposure into Devon's portfolio. At $68.86 WTI, Devon's Marcellus gas production operates on separate economics from its Permian oil exposure. Devon's scale places it in the large-operator category per the Dallas Fed breakeven survey, implying a $9.86 per barrel gross margin on oil production at current spot prices.

Goldman and JPMorgan Converge on $80 Brent for Q4 2026

Goldman Sachs reset its 2026 oil price forecasts on June 16, following the Iran agreement. The bank carried a Q4 2026 Brent target of $80 per barrel and a Q3 2026 Brent target of $82 per barrel, with corresponding WTI targets of $75 and $77 per barrel. JPMorgan published a parallel reset on June 24, projecting Q4 2026 Brent at $80 per barrel and Q3 at $86 per barrel. The two banks agree on a Q4 2026 Brent floor of $80, implying WTI recovers from $68.86 toward $75 to $76 per barrel by year-end.

Goldman's Q4 WTI target of $75 per barrel represents an 8.9% recovery from Friday's $68.86 settlement. The Dallas Federal Reserve's Q1 2026 energy survey separately showed respondents expected year-end WTI at $74 per barrel, within one dollar of Goldman's base case. Goldman noted its risks remain tilted to the upside, citing residual uncertainty around Strait of Hormuz implementation. JPMorgan's 2027 Brent forecast of $64 per barrel stands $11 per barrel below Goldman's $75 per barrel for the same year, a divergence that reflects different assumptions about medium-term OPEC supply normalization.

Western Canadian Select and Canadian Dollar Revenue Impact

Canadian oil sands producers face compounding price pressure at $68.86 WTI. The Alberta Energy Regulator's 2026 crude oil price forecast projects the Western Canadian Select discount to WTI at US$12 per barrel on average for the year. Applying that differential to Friday's WTI settlement places WCS at US$56.86 per barrel. At the Bank of Canada's June 26 USD/CAD exchange rate of 1.4184, Canadian producers receive C$80.67 per barrel on WCS-priced production. That figure contrasts with the elevated CAD revenues implied by April's EIA Brent projections of $96 to $115 per barrel, before the Iran agreement reset global crude markets.