Permian Basin bottlenecks limit oil output despite recent high prices
Takeaway capacity to move natural gas out of the Permian Basin is also limiting the region's operators from responding to the current spike in oil prices.
The market is calling for more oil, but as analysts at East Daley Analytics note, the restrictions on moving associated natural gas are also limiting the ability to move crude oil out of the Permian. Until new pipelines such as Blackcomb and Hugh Brinson add a combined 4.7 billion cubic feet a day of capacity by the end of the year, producers will struggle to move associated gas - and therefore crude - out of the basin.
"This dynamic matters because the Permian is the largest oil-producing region in the U.S. In previous cycles, higher oil prices typically trigger increased drilling activity and supply growth from the basin. However, producers today face a structural bottleneck that limits their ability to respond to price signals," analysts pointed out.
Julian Renton of East Daley Analytics observed that this is not the first time producers have been unable to respond to market signals.
"A key historical parallel is the early 1970s, when U.S. production reached physical capacity, limiting the ability to increase supply despite rising prices. More recently, during the 2014 oil price collapse, production declined more slowly than prices would have suggested due to hedging and operational inertia," he told the Reporter-Telegram.
What is different today is multiple constraints are occurring simultaneously, he continued.
Not only are there infrastructure limitations, but capital discipline continues to limit the willingness of operators to increase activity, especially in response to what the forward curve signals current high prices may not persist, Renton added.
"Finally, inventory management is becoming more important as Tier 1 acreage is developed more deliberately," he wrote.
"In that sense, producers are not just unwilling to respond, they are, in some cases, physically constrained from doing so, which is a meaningful shift from earlier shale cycles," he wrote.
The markets may turn to other liquids-rich basins like the Bakken, Rockies, Anadarko and Eagle Ford, which have historically ramped up drilling activity when prices rise.
"Historically, these regions have responded to higher oil prices, typically with a lag," wrote Renton. "However, two factors are likely to blunt that response. First, the backwardated forward curve signals current high prices may not persist, reducing the incentive for producers to materially increase capital spending. Second, capital allocation flexibility across portfolios - particularly for operators with exposure to both the Permian and other basins - means companies may prefer to wait for improved Permian takeaway capacity rather than shift capital for a potentially short-lived opportunity."
That said, he wrote private operators are likely to be the most responsive in the near term. These companies tend to have fewer capital return constraints and greater operational flexibility, allowing them to opportunistically increase activity where infrastructure is available.
"Even so, the overall pool of producers positioned to respond remains relatively limited. Incremental supply will likely come from a combination of privates and select public operators with existing capacity, minimal hedge exposure, and the ability to act without committing to long-term capital increases," Renton wrote.
He concluded: "If the disruption is short-lived, the market may remain tight without a meaningful supply response. If it persists longer, the risk of a broader supply shortfall increases, as the traditional shale response mechanism is currently constrained."
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This story was originally published March 19, 2026 at 10:03 PM.