US shale on track for first output dip in five years as price chaos freezes drilling

US crude oil production is expected to fall for the first time in five years, with the Energy Information Administration projecting output will average 13.5 million barrels per day in 2026—down roughly 100,000 b/d from 2025 levels. The decline, modest in absolute terms, marks a significant shift in trajectory. Output had risen 300,000 b/d in 2024 and 400,000 b/d in 2025, powered almost entirely by the Permian Basin, which hit 6.0 million b/d in December 2025 and now accounts for 44% of total US production. The EIA still expects marginal gains in the Permian, Alaska and the Gulf of Mexico next year, but they will not be enough to offset declines elsewhere. The price backdrop explains much of the hesitation. WTI is projected to average $51/b in 2026, down from $65 in 2025 and $77 in 2024. But the annual averages obscure a more disorienting ride: futures swung from $57/b at the start of 2025 to $111 during a period of geopolitical tensions before settling near $100. Henry Hub gas prices climbed above $5/MMBtu, briefly making gas appear the more attractive bet. That kind of volatility has paralyzed capital planning. A Dallas Federal Reserve survey of oil and gas executives found that 30% expected no change in 2025 output in response to recent events, and 43% anticipated only modest increases of up to 250,000 b/d. Just 1% forecast gains above 1 million b/d. The rig count told the same story. Oil-directed rigs dropped from 415 in January 2025 to 386 by late November, even with WTI above $90. Half of the executives surveyed reported no change in planned drilling for 2026; 26% expected only slight increases. "Even after nearly a month of oil above $90 per barrel, rig counts declined, signaling little confidence that prices will hold," one respondent noted. Another said predicting anything in the sector had become "very difficult." The industry has also been preoccupied with consolidation. Deals totaling $192 billion closed in 2023 and $105 billion in 2024, including Diamondback Energy's $26 billion acquisition of Endeavor Energy Resources. In February 2025, Devon Energy and Coterra Energy announced an all-stock merger valued at roughly $58 billion—the latest in a wave of tie-ups that has redirected management attention and capital toward integration rather than growth. The EIA also revised its Permian accounting in March 2026, adding the Avalon, Barnett, Dean and Woodford plays to its formation tracking while removing Delaware and Yeso-Glorieta as conventional rather than tight formations. The net effect was to raise the Permian's tight oil estimate by 200,000 b/d and shale gas by 800 million cubic feet per day for 2025—a bookkeeping adjustment, but one that illustrates how difficult it remains to get a clean read on actual productive capacity. For traders, the key question is whether WTI can hold in a range that justifies renewed drilling. The $50–65/b band the EIA has penciled in for 2026 is below most operators' breakevens for new wells outside the core Permian. Watch whether a sustained move above $90 shifts the rig count. On the gas side, the startup schedule for Golden Pass LNG—a 2.3 Bcf/d facility—could tighten domestic supply and keep Henry Hub elevated, which may push some operators toward gas-weighted acreage. If consolidation continues among mid-caps, the producer base contracting further is the structural risk to watch.