Buried under 87 days of negative prices at the Waha Hub in West Texas, Permian gas became a liability drillers paid buyers to haul away, and the oil kept flowing regardless
On a Tuesday morning in April, a West Texas driller was doing something that sounds impossible: paying someone else to take its natural gas.
Not discounting it. Not giving it away. Paying, in cash, per unit delivered.
At the Waha Hub, the price had slipped to a record low that turned the industry’s second most valuable product into a bill.
The strangest chapter of 2026 in the Permian may be this: the basin set oil output records in the same months it set records for paying people to remove its own gas.
And yet, across the same basin, the oil rigs kept turning, the pump jacks kept nodding, and production climbed toward its highest levels ever recorded.
How does a commodity go below zero while the people producing it refuse to stop?
Why the price went negative and stayed there
Every barrel of Permian crude brings gas with it. The two travel up the same wellbore together, and there is no valve that separates oil from its traveling companion. Drillers call this associated gas, and in a well served basin, that gas flows into a pipeline, gets processed, and earns a check.
But the Permian, in early 2026, had run out of pipelines willing to take it. When every pipe out of West Texas is full, the gas has nowhere to go. Limited takeaway capacity trapped associated gas in the region, forcing producers to discount or effectively pay to move volumes out.
Spring maintenance made a bad situation catastrophic. Pipeline operators routinely take sections offline for inspection each spring, shrinking available capacity just as production was hitting new records. Flaring surged across the Permian during the worst stretch, as operators burned off volumes they could not otherwise place. Even burning it for free was more attractive than paying a trader to take it.
The well that ran on oil economics alone
Stand at a Permian wellsite and the math is visible in the hardware. A pump jack pulling crude from two miles underground cannot deliver oil without gas. The two come up together or not at all.
Stopping the gas means stopping the oil, and Permian crude, trading above $70 a barrel through most of the year, was too profitable to abandon over a gas penalty. A producer paying negative $5 per MMBtu on its gas output while selling oil at $70 a barrel is still, on balance, making a strong return. The gas loss is the cost of keeping the oil flowing, treated on the books the same way a factory treats its waste disposal fee.
That logic also explains why no producer blinked. Shutting in a Permian well to avoid a gas bill is like closing a bakery because the leftover bread costs money to throw out. This phenomenon first appeared in 2019 and has grown increasingly frequent as basin output outpaced takeaway capacity.
The record nobody wanted to set
The numbers that accumulated through the first half of 2026 were unlike anything the Permian’s trading desks had logged before. Next-day prices at the Waha Hub remained below zero for a record 78 consecutive days as pipeline constraints from spring maintenance trapped gas in the nation’s biggest oil producing basin.
Waha prices went negative a record 87 times across the year, averaging negative $2.38 per MMBtu, compared with positive $1.15 in 2025 and a five year average well above $2.50 per MMBtu. At the April low, prices plummeted to negative $5.658 per MMBtu as restricted takeaway capacity trapped a glut of associated gas in West Texas.
The shift was not gradual. Waha had gone negative just once in all of 2023, then 49 times in 2024, then 39 times in 2025, which means the infrastructure gap was widening faster than the pipe could catch up. Gas worth a fortune in Louisiana was worth less than nothing in Midland, and the irony deepened with every passing week.
Relief arrived, but it shifted the problem west
By July, new pipeline capacity pushed into service and Waha’s price climbed back into positive territory for the first time in months. The relief was real but immediately complicated.
“Waha’s gain is a detraction for Henry Hub,” analyst Leo Mariani told Natural Gas Intelligence. “Those two are going to sort of move inversely in the next handful of months as these bigger pipelines start up and start putting more gas in the market.” More gas reaching the national benchmark simply lowered prices there too, spreading the surplus across the grid rather than erasing it.
The longer fix is still under construction. The Hugh Brinson pipeline, a 400-mile greenfield line, will add 2.2 Bcf/d of takeaway capacity, carrying gas to a point about 40 miles south of Dallas and Fort Worth. Intrastate flows heading east from the Permian already increased by about 1.4 Bcf/d from July 2025 to July 2026 as new capacity came online.
What the numbers mean going forward
The Waha anomaly is resolved for now, but the underlying tension is not. Permian natural gas production is expected to reach 32.7 Bcf/d by 2035, and every additional bcf of gas needs a pipe. Spring maintenance windows will return each year, and when they overlap with production peaks, the same trap closes again.
For landowners and communities across the Delaware and Midland sub basins, the flaring surge was the most visible consequence. One major pipeline operator had warned that associated gas constraints could limit crude oil production growth, then revised its expectation upward to an increase of 100,000 to 200,000 barrels per day by year end.
Those who want to understand what concentrated gas infrastructure deals look like from the producer’s side will find context in a Barnett Shale deal that bundled 65 MMcfd of production with a working carbon capture project. The midstream power shaping these markets is also visible in the story of a 230 MW deal built around Permian gas processing operations.
The strangest chapter of 2026 in the Permian may be this: the basin set oil output records in the same months it set records for paying people to remove its own gas. The bill got written. The drillers signed it and kept going.
Hugo is an engineer with strong technical expertise. Multilingual from an early age, his writing combines technical clarity with a strong interest in science and energy.
