Predevelopment underwriting · gas feasibility
Air-permit feasibility tells you whether you can run the turbine. Gas feasibility tells you whether you can fuel it. Hover any state for the rationale, click to open that state's PUC. Reference fleet is a representative behind-the-meter turbine deployment (~184 MW aggregate, ~70 MMcf/day peak).
State cartogram · reference load
A zoom-out view of where firm gas at a defensible basis is available for a representative ~184 MW behind-the-meter turbine fleet. Green = inside or adjacent to a producing basin; amber = served by major interstate trunk capacity; red = end-of-pipe or under capacity moratorium. State-level for v1; the production product resolves to the parcel.
Firm gas at low basis
Firm gas typical, basis varies
Firm capacity scarce or absent
Hover a tile for the state-specific rationale; click to open that state's gas/PUC authority. Demo classification at state resolution; the production product runs per parcel against live HIFLD/EIA pipeline GIS, FERC tariff capacity, and intrastate registries.
Why this is interesting
The data underneath — HIFLD pipeline GIS, EIA Form 176/191/757 capacity reports, FERC tariff filings, intrastate registries (TX RRC for example), EIA daily basis differentials — has always been public. What was missing was a surface that stitches them against an actual fleet spec at parcel resolution. v1 is state-level; v2 is per-parcel, including distance to the nearest transmission-class trunk, operator and tariff zone, and the basis differential vs Henry.
Constraint 1 · physical proximity
Anything below 12-inch diameter at sub-500 psig is a distribution lateral, not transmission. For a ~70 MMcf/day peak demand you need to interconnect to a transmission-grade trunk (typically 24-inch+, 800-1,400 psig). The county-level question is: how far is the parcel from one, and which operator runs it?
Constraint 2 · firm capacity
Even with a pipe in the right-of-way, capacity may be fully subscribed. FERC tariff capacity is checkable; intrastate (TX RRC, OK, etc.) is opaque. Many developers pay $500K/month for 24 months to reserve future capacity that, even when delivered, isn't truly firm if the pipe is unconstrained.
Constraint 3 · basis economics
A turbine sited on a Texas producing-basin pipe at Waha pays sub-Henry basis (sometimes negative). The same turbine on Algonquin zone 6 pays Henry+$2-5 in winter peaks. Heat rate × hours × delta basis is six-to-eight-figure annual swing on a 184 MW fleet.