The Permian Basin, the United States’ most productive oil-producing region, is grappling with a significant natural gas surplus that has led to sharply negative prices and strained pipeline infrastructure. This situation has emerged amid rising oil prices fueled by geopolitical tensions, particularly the ongoing conflict between Iran and the U.S., which has driven increased drilling activity in West Texas.
During the first half of 2026, natural gas prices at the Waha trading hub in the Permian Basin fell as low as negative $7.95 per million British thermal units (MMBtu) in late April, a record low compared to the national benchmark at Henry Hub in Louisiana, where prices stood at $2.72 per MMBtu on the same day. The glut of natural gas is a byproduct of ramped-up oil production, which providers are incentivized to pursue even when it produces excess gas. In some cases, producers were paying users to take gas off their hands due to insufficient pipeline capacity to transport the volumes to market.
Although new pipeline infrastructure has come online during the summer months, alleviating some of the pressure and lifting prices out of the negative territory, the value of Permian natural gas remains about 40% below the national average. Experts warn that this brief reprieve may not last as production is expected to accelerate significantly before new pipeline expansions are completed toward the end of the decade.
Industry analysts highlight that natural gas volumes often grow faster than crude output in the Permian, creating a mismatch between supply and takeaway capacity. “The big question is how quickly gas production grows into the new capacity,” said Rob Wilson, president of East Daley Analytics, an energy data firm. If high oil prices persist, especially if the Strait of Hormuz remains disrupted, producers may face renewed challenges moving gas from the field.
The Permian’s gas production currently represents around 20% of U.S. output and has been a key driver of stable domestic prices and supply growth in recent years. However, pipeline bottlenecks and regional congestion risk undercutting these gains and could have broader implications for the national energy landscape, especially given the country’s expanding export markets and reliance on natural gas to generate electricity and power emerging sectors like artificial intelligence.
Pipeline operators have acknowledged these pressures. Jennifer Kneale, president of Targa Resources, said in the spring that the situation might deteriorate further before improving due to ongoing volume growth outpacing capacity upgrades.
Producers in the Permian generally prioritize oil prices when funding drilling ventures, treating gas as a secondary product. This dynamic has created tolerance for extremely low or even negative gas prices. For example, Diamondback Energy, one of the region’s leading producers, reported an average oil price of nearly $97 per barrel in the first quarter but experienced negative $2.15 per MMBtu for its gas sales, a factor that contributed to an 8.2% drop in the company’s stock price.
In response to the gas surplus, some operators have curtailed drilling in gas-prone areas or reduced production altogether. Environmental and regulatory restrictions limit the amount of gas that can be flared or vented, further complicating operational decisions. Some firms are adopting innovative approaches to reduce reliance on external fuels, including using gas produced onsite to power equipment. Chevron announced plans to build a natural gas–fueled power plant in Reeves County, Texas, to supply electricity to a large Microsoft data center planned nearby.
According to Bank of America analysts, natural gas production growth in the Permian slowed to less than half the rate seen in previous years during the first half of 2026, reflecting producer caution amid the ongoing pipeline and pricing challenges.