Projects most likely to change gas flows, prices, LNG supply and energy security
Assessing Pipeline Projects Around the Globe
We previously covered some of the largest LNG export projects in the United States as well as export growth in other countries. But today’s pipeline projects deserve the same spotlight because they determine whether gas can actually reach the market, connecting real supply to real demand, relieving a bottleneck, or opening a new route.
In North America and several other export-oriented regions, LNG projects have become the strongest demand anchors for new pipeline construction. But LNG is not the only driver. A pipeline’s market importance increasingly depends on what sits at the downstream end, whether that is a liquefaction plant, power or industrial load, or whether it is for need of import-substitution or regional security-of-supply.
Project Breakdown
In this two-part series, we break down these projects into three different Categories:
- Commercially grounded: Relieves a constraint or connects proven supply to visible LNG, power or industrial demand. Projects in this category such as Coastal GasLink and Blackcomb have identifiable supply, identifiable demand and a practical reason to operate.
- Diversification and resilience: Adds route diversity, interconnection, reversal capability or new regional access. Projects in this category such as Baltic Pipe and TAP strengthen route diversity, connect Black Sea or Caspian supply to new markets, and reduce dependence on a single corridor.
- Geopolitical optionality: Large strategic potential. But pricing, financing, gas allocation and/or timing remains unresolved. These projects [are far larger in scale than categories 1 and 2] such as Power of Siberia 2 and TAPI.
How to Read the Numbers
U.S. pipeline capacity is generally reported in billion cubic feet per day (Bcf/d). European and Asian projects are usually reported in billion cubic meters per year (bcm/year), while Argentina and Brazil often use million cubic meters per day (MMm³/d). In this paper we use the units in the form most commonly employed in each market.
North America: LNG Demand Is Fueling the Pipeline Buildout
North America’s pipeline geographically separated story has evolved from connecting regions to transporting more gas out of producing basins and removing constraints. Now, it is increasingly about connecting production areas to LNG export terminals, coastal industry and power plant demand. And it is Permian Basin takeaway which had become one of the most important gas-infrastructure themes in the world due to size [and scope.]
EIA estimates that the United States could add 44.9 Bcf/d of pipeline capacity during 2026–27, with 31.6 Bcf/d already under construction. About 29.7 Bcf/d is fueled by production in Texas and another 8.4 Bcf/d in Louisiana
North American Pipelines at a Glance:
United states:
- 9 Bcf/d planned during 2026–27
- 6 Bcf/d under construction
- 7 Bcf/d originating in Texas
- 4 Bcf/d originating in Louisiana
Canada:
- 1 BCF/D
For example, the recently completed Matterhorn Express (WhiteWater, ONEOK, MPLX, Enbridge), a 580 mile pipe has added 2.5 Bcf/d of new takeaway capacity from the Permian Basin, moving this gas to the Katy Hub area near Houston, Texas. And this is just one of many projects that have relieved the pressure on Permian takeaway requirements. Matterhorn is the proof that additional Permian takeaway can materially relieve congestion at the Waha Hub in the Permian. Because much Permian oil is produced alongside gas, moving the oil helps prevent local gas prices from collapsing when gas production exceeds available transportation.
Permian Takeaway Supply
Blackcomb (WPC, Targa Resources) another recently completed project, provides additional 2.5 Bcf/d from Waha to the Agua Dulce Hub. Agua Dulce is an important demand source for South Texas LNG terminals, exports to Mexico and other coastal market demand and will give further relief to the Permian.
Hugh Brinson (Energy Transfer) planned for opening by the end of 2026, will connect West Texas production to existing pipeline infrastructure south of the Dallas-Fort Worth area, giving access to the broader Texas network, including local hubs, power demand, etc. From there, customers will have the flexibility to reach multiple destinations in Texas and Louisiana, including export facilities along the Gulf Coast.
Moving Gas to Meet Gulf Coast Demand
Trident Intrastate (Kinder Morgan) a new 219-mile, 2.2 Bcf/d pipeline project (opening in Q4 2026) will deliver gas brought to Katy via the Matterhorn Express pipeline to the industrial corridor near Port Arthur, Texas with its demand anchor being Golden Pass LNG. This pipeline will also help meet gas-fired power plant demand in Southeast Texas.
Rio Bravo and Bay Runner (WhiteWater/I Squared, MPLX, Enbridge) link Permian via Agua Dulce Hub in South Texas to Rio Grande LNG in Brownsville, thus creating a major new demand pull at Agua Dulce. This additional capacity will support regional gas prices, increase the value of upstream systems such as Blackcomb, and intensify competition for gas among LNG terminals, Mexican exports, power plants and industrial users.
Together, the two pipelines will provide up to 5.3 Bcf/d. Bay Runner is expected to be in service in the third quarter of 2026, while Rio Bravo is currently expected in 2029. Once fully operational, the system will help supply five LNG trains totaling about 30 million tons per year, about 25% of all U.S. LNG exports.
Haynesville and Louisiana LNG
Pelican Pipeline provides the other side of the Gulf Coast supply story. While many Texas projects are designed to move Permian gas hundreds of miles toward LNG demand, Pelican will transport up to 2.5 Bcf/d of Haynesville gas in Louisiana north to the Gillis Hub in southern Louisiana. Its proximity to Louisiana’s LNG corridor makes Haynesville one of the most direct supply sources for the next wave of US LNG export capacity.
The Port Arthur Pipeline Louisiana Connector (Sempra), much like the Trident Intrastate Pipeline (in-service since June 9th, 2026), is a direct LNG-feedgas project rather than a general-purpose takeaway line.
Canadian Opening the Pacific
Coastal GasLink (Aimcorp Group, KKR & Co, TC Energy) is Canada’s first large direct bridge for northeast British Columbia gas to Pacific LNG export projects . The initial system will carry about 2.1 Bcf/d to LNG Canada and could potentially expand to about 5 Bcf/d through additional compression.
The next step depends on LNG Canada Phase 2 and Cedar LNG. Coastal GasLink and LNG Canada reached new commercial agreements in March 2026 to advance the Phase 2 pipeline work, but the expansion remains subject to LNG Canada’s final investment decision. Cedar Link adds a smaller but important 0.4 Bcf/d connection to Cedar LNG near Vancouver.
Without LNG Canada Phase 2, Coastal GasLink is still a major export corridor, but it will not reach the potential of a full 5 Bcf/d expansion.
