The Permian Basin, the nation’s leading oil-producing region, experienced significant natural gas pricing pressures during the first half of the year as associated gas from oil-directed drilling operations accumulated without adequate pipeline infrastructure to transport it. Operators were forced to either flare excess gas within regulatory limits or incur costs to dispose of what many considered an unwanted byproduct of their primary crude oil extraction activities. This supply-demand imbalance resulted in the Waha hub, the regional pricing benchmark for Midland-area gas, averaging negative $2.19 per million British thermal units, reaching a record low of negative $7.95 per MMBtu at the end of April—more than $10 below the national Henry Hub benchmark.
Relief arrived in June with the commencement of operations for the Gulf Coast Express Pipeline expansion and Energy Transfer’s Hugh Brinson Pipeline, which began transporting gas toward demand centers in East Texas, the Katy Hub, and Gulf Coast markets including liquefied natural gas facilities and industrial customers. These new infrastructure additions shifted the Waha hub price into positive territory, where it remained for more than a month. However, industry observers noted that reaching full operational capacity will require additional time, with the Hugh Brinson Pipeline not expected to reach full capacity until March 2027.
Producers who had reduced volumes through shutdowns or flaring started resuming operations as new pipeline capacity became available. According to the U.S. Energy Information Administration, pipeline developers plan to introduce 44.9 billion cubic feet per day of new natural gas capacity nationwide during 2026 and 2027, with more than 66% originating in Texas. The Hugh Brinson Pipeline, Rio Bravo Pipeline Project, and Blackcomb Pipeline represent the three largest projects expected to commence operations by year-end.
Industry executives anticipate that pipeline constraints will remain the primary limitation on Permian Basin drilling activity for the next 12 months, though most expect full resolution of takeaway capacity issues in 2027, with the first quarter of that year cited most frequently. However, some survey respondents expressed skepticism, with more than 10% projecting resolution no earlier than 2028 and approximately 7% suggesting the constraints may never fully ease. The timeline for relief could accelerate if current geopolitical conditions maintain elevated oil prices, spurring additional drilling that would generate larger volumes of associated natural gas.
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