Blackcomb, Hugh Brinson, and Rio Bravo to Add 9 Bcf/d of New Permian Gas Takeaway by Year End

Three natural gas pipeline projects totaling 9.2 billion cubic feet per day of new takeaway capacity are on track to begin service from the Permian Basin before year-end 2026. Producers have been absorbing deeply negative gas prices at the Waha Hub in West Texas as a direct consequence of constrained outbound pipe capacity. The buildout represents the largest single-year addition to Permian gas export infrastructure since the 2019 through 2021 pipeline construction cycle.

Blackcomb: 2.5 Bcf/d to Agua Dulce

The Blackcomb Pipeline will carry up to 2.5 billion cubic feet per day through 365 miles of 42-inch diameter pipe from the Permian Basin in West Texas to the Agua Dulce hub in south Texas. The project reached its final investment decision in 2024 with four investment-grade anchor shippers: Devon Energy, Diamondback Energy, Marathon Petroleum, and Targa Resources. Operations are expected to begin in the third quarter of 2026, pending regulatory approvals already in progress. Those four companies represent substantial Permian Basin production and processing volumes, providing revenue certainty for construction financing.

The ownership structure of Blackcomb runs through several layers. WhiteWater Partnership Company holds a 70% stake in the pipeline, while Targa Resources holds 17.5% directly and MPLX holds 12.5% directly. Inside WhiteWater Partnership Company, equity is divided among WhiteWater (50.6%), MPLX (30.4%), and Enbridge (19%). Marathon Petroleum controls MPLX, giving Marathon an effective economic interest of approximately 33.8% when combining its WPC share and its direct stake. Enbridge's share of WPC translates to roughly 13.3% of the pipeline's economics.

Hugh Brinson and Rio Bravo Complete the Buildout

The Hugh Brinson Pipeline will add 2.2 billion cubic feet per day in a first phase expected to begin service in the fourth quarter of 2026, with a second phase targeted for the first quarter of 2027. Rio Bravo Pipeline, designed to link Permian supply to Gulf Coast LNG export terminals, will contribute up to 4.5 billion cubic feet per day by end of 2026. Together, the three projects add 9.2 Bcf/d of new Permian gas takeaway capacity, according to EIA pipeline project tracking data.

Waha Basis: The Producer Cost of Constrained Takeaway

Waha Hub spot gas prices averaged negative $6.75 per MMBtu below Henry Hub through the first half of 2026, according to AEGIS Hedging market data. Henry Hub natural gas was trading near $3.23 per MMBtu on Thursday, implying a Waha spot price of approximately negative $3.52 per MMBtu. A Permian producer selling 100 million cubic feet per day at Waha spot rates sacrifices roughly $352,000 per day in direct gas revenue compared to a producer with Henry Hub market access.

Negative realized prices incentivize producers to curtail associated gas from oil wells or route volumes to flare rather than sell into the spot market. Waha has traded as low as negative $10 per MMBtu during periods of peak basin production and pipeline congestion. The incoming 9.2 Bcf/d of takeaway capacity removes the structural bottleneck that keeps Waha persistently disconnected from Gulf Coast pricing.

Permian Gas Production and Basin Context

The EIA projects Permian Basin natural gas production at approximately 27 billion cubic feet per day in 2026, making it the largest single source of associated gas growth in North America. Permian oil wells produce natural gas as a byproduct, meaning gas volumes grow roughly in proportion to oil-directed rig activity. Devon Energy and Diamondback Energy, two of the basin's largest oil producers by acreage, both committed to firm transportation on Blackcomb, securing basis protection through the current constraint period.

Separately, the Gulf Coast Express Expansion will add incremental capacity alongside the three larger projects. The combined 2026 wave of Permian gas takeaway infrastructure is expected to substantially narrow the Waha discount by the fourth quarter, according to RBN Energy market analysis. Producers currently hedged at Henry Hub will benefit most from the basis compression once new pipe comes online.