Permian Basin Inventory Expands to 55,000 Locations as Operators Hold Drilling Steady
New research reveals a growing runway of low-cost wells even as major producers resist expanding activity amid geopolitical uncertainty.
The Permian Basin’s commercially viable drilling inventory has grown to approximately 55,000 locations with breakeven costs below $50 per barrel, according to a new analysis released April 15 by Enverus Intelligence Research. The finding represents a 10 percent year-over-year increase and underscores the basin’s enduring position as the backbone of U.S. shale production. Yet the expansion in available inventory stands in sharp contrast to the posture of many large operators, who are holding drilling programs flat despite elevated crude prices driven by ongoing Middle East tensions.
The Enverus report estimates that total undeveloped inventory in the Permian approaches 100,000 locations when geologically viable resource is included, with more than 60 percent of the incremental supply concentrated in emerging deep zones such as the Barnett-Woodford and Wolfcamp D formations. This deep-zone potential, combined with continued cost reductions across the basin, has effectively extended the runway of economically attractive drilling opportunities—countering persistent concerns about inventory exhaustion that have shadowed the Permian in recent years.
The findings align with earlier U.S. Geological Survey assessments that identified significant undiscovered resources in the Woodford and Barnett shales, estimating 28.3 trillion cubic feet of technically recoverable natural gas and 1.6 billion barrels of oil in formations extending to depths of 20,000 feet. Together, these analyses paint a picture of a basin with substantial untapped potential in its deeper geological horizons, even as legacy zones mature.
Despite the expanded inventory, industry behavior suggests a deliberate strategy of capital discipline over production growth. The Dallas Federal Reserve’s first-quarter 2026 Energy Survey, released March 25, found that the business activity index rose to 21.0 from negative 6.2 in the prior quarter, signaling a modest rebound. However, half of the executives surveyed reported no change to their 2026 well-drilling plans, and nearly 70 percent of executives at large exploration and production firms—which account for the bulk of U.S. crude output—said their programs remain unchanged.
The restraint is driven primarily by geopolitical volatility. Surveyed executives expect West Texas Intermediate crude to average $74 per barrel by year-end, though the range of estimates spans from $50 to $135, reflecting deep uncertainty around the ongoing Iran conflict and Strait of Hormuz disruptions. Large producers appear content to hold steady until the geopolitical landscape stabilizes, while smaller operators have been more responsive: roughly 60 percent of small-firm executives reported revising their drilling plans upward.
Meanwhile, the Permian continues to deliver record production with fewer rigs. U.S. oil output reached 13.6 million barrels per day in 2025, with the Permian contributing approximately 6.6 million barrels daily—nearly half the national total. Operators have achieved these gains through multi-zone completions, faster rig mobilization between well sites, and simultaneous multi-directional drilling from single pads. However, the Energy Information Administration has cautioned that sustained rig count declines could lead to a 2 percent production drop by 2027, which would mark the first decline since 2021.
The divergence between expanding inventory and cautious drilling activity creates a complex talent environment across the Permian Basin. The deep-zone potential identified by Enverus and the USGS requires specialized geological expertise and engineering capabilities that differ from conventional Permian operations. Formations at depths exceeding 15,000 feet present distinct challenges in well design, pressure management, and completion technology that may increase demand for experienced subsurface engineers and geoscientists familiar with high-pressure, high-temperature environments.
At the same time, the efficiency-driven production model—delivering record output with fewer active rigs—places a premium on operational specialists capable of optimizing multi-zone completions and pad-level logistics. The shift away from rig-count-driven growth toward technology-intensive extraction may gradually reshape the workforce profile in the basin, favoring technical depth over headcount volume. Regulatory and compliance professionals also remain in steady demand as operators navigate evolving federal methane rules and state-level permitting requirements in an increasingly complex oversight environment.
The trajectory of Permian Basin activity in the second half of 2026 will likely hinge on two factors: the resolution of Middle East supply disruptions and the commissioning of new long-haul natural gas pipelines expected to alleviate takeaway constraints by late 2026 and early 2027. If crude prices stabilize and pipeline capacity expands as projected, the newly documented inventory could unlock a wave of development activity—particularly in the deep zones that remain largely untested at scale.
Industry observers will also monitor whether large operators begin loosening their capital discipline in response to sustained price signals, or whether the current posture of restraint becomes the new baseline for Permian development. The Dallas Fed’s next energy survey, expected in June, will provide an important barometer of executive sentiment heading into the back half of the year.
