FERC Draft Would Drop Air Modeling and Add LNG Blanket Permits
FERC wants to cut two of the slower steps out of gas infrastructure permitting: air dispersion modeling in environmental reviews, and full applications for certain LNG plant work. Utility Dive reported that the commission advanced both proposals at its Oct. 15, 2026 meeting, with Chairman Laura Swett saying the only current restriction on getting American gas is moving it to market through bottlenecked infrastructure.
Background
The first proposal is a draft policy statement, adopted on a 4-1 vote, that would end air dispersion modeling in FERC’s National Environmental Policy Act reviews of gas projects. Utility Dive describes these models as simulations of how a project’s emissions spread and interact with background pollution and nearby sources. FERC argues that the models duplicate Clean Air Act review and permitting that belongs to EPA and state air agencies. Swett called them “an unnecessary source of confusion, delay and litigation risk.” Commissioner Judy Chang dissented, calling the models the best tool available for understanding local and regional air impacts outside of physical monitors.
The second proposal is a three-tier blanket authorization framework for LNG projects. Certain activities would proceed automatically with no application filed at FERC. Others would need a 60-day notice and comment period. Larger additions to an existing plant, including liquefaction trains, LNG tanks and marine berths, would need a 90-day period. Commissioner Lindsay See, who pushed the idea, said it follows the blanket program FERC already runs for gas pipeline projects.
Swett also tied the work to Senate permitting legislation, the Bipartisan American Affordability and Jobs Act. Backers hope to pass it in the lame-duck session after the midterm elections, and it would still need to clear the House, which has passed its own bill.
Analysis
Start with what is and is not final. This is a draft policy statement and a proposal. The source does not give a comment deadline, so we can’t say when the record closes or when anything takes effect. Until FERC publishes those dates, nothing here changes a project schedule.
The air modeling change targets litigation more than construction. Swett said the models have been “a tremendous boon” to opponents who challenge FERC’s gas authorizations. Removing a technical record that plaintiffs can attack makes certificates harder to unwind. For a contractor, a certificate that survives court challenge is what lets crews mobilize on schedule. Chang’s dissent is a reminder that opponents will find other angles, and the source gives no indication the proposal ends litigation risk, only that FERC wants to reduce it.
The LNG blanket framework matters more for brownfield work. Our inference: the 90-day tier is aimed at expansions at existing terminals, since liquefaction trains, tanks and berths are the examples FERC cited. The source does not say which activities qualify for the automatic tier, and it does not state how long a full application takes. We can’t quantify the time saved, only that a 90-day notice period replaces a full application for some expansion work.
On pipelines, the source says only that FERC already has a blanket program, and the air modeling change would apply to its NEPA reviews of gas projects generally. The source does not mention compression stations. Our inference: compression added to move more gas on existing systems is the kind of work that benefits from lighter air review, because compressor emissions are an air permitting issue. Whether specific compression projects qualify depends on final text.
The demand side explains the push. Swett said gas-fired generation needs fuel, and Commissioner David Rosner laid out the power-side constraints. A gas plant in the PJM Interconnection was assigned $1.3 billion in network upgrade costs, which killed the project. Only 400 miles of 345-kV and above interstate transmission came online last year, versus 4,000 miles in 2013. Interconnection review plus build can take five years. Faster gas pipeline permits do not fix those grid limits, so power projects can still stall on the electrical side.
What It Means for Subcontractors
- Brownfield LNG trades: Civil, piling, tank erection, piping and mechanical crews at existing LNG plants are the likely beneficiaries. The 90-day tier covers liquefaction trains, LNG tanks and marine berths. If finalized, expansion packages could reach subcontract stage on a notice timeline rather than a full application. Ask owners which add-ons they would file under the blanket tier.
- Pipeline and compression: Air dispersion modeling would no longer be part of FERC’s NEPA review for gas projects under the draft. Projects stuck on air analysis may clear FERC sooner, but state air permits still apply. Check the state permit status on any compression job before committing crews.
- Don’t price in the draft: The comment deadline is not in the source, and this is a proposal on a 4-1 vote. Hold bid schedules to current FERC timelines until the final policy statement and final LNG framework are published.
- Watch the legislation: Backers want the Senate bill passed in the lame-duck session after the midterms, and the House must also act. The Senate bill would require nine FERC rulemakings, so rules would follow any passage and not arrive with it.
- Electrical and E&I: Transmission remains the choke point, with 400 miles of 345-kV and above built last year and a five-year interconnection-to-build cycle cited by Rosner. Gas-fired power work can still stall on grid upgrade costs, such as the $1.3 billion assignment that killed the PJM project. Weigh that risk when bidding on generation-linked scopes.
- Litigation risk: Chang’s dissent signals the policy could be challenged. If a project’s certificate relies on the new approach, ask whether the owner has a fallback schedule before you commit labor and equipment.
