Interactive calculators and reference data for C&I energy buyers, independent power producers, and data center energy developers — covering PJM capacity markets, gas-to-power economics, BTM generation, and Northeast gas supply.
Estimates are illustrative and for budgeting purposes only. Not a price quote. Last updated: August 2026.
Shows gross spark spread ±$2 gas price around your input at your stated power price and heat rate. Does not include variable O&M, fixed costs, emissions, or capacity revenue.
These default to real, non-zero values so the comparison is apples-to-apples out of the box. The capital line uses a capital recovery factor (return of and return on capital), not a simple interest charge. Zero out any line you want to exclude.
| Cost Component | Annual Amount |
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| Annual Grid Cost (baseline) | — |
| BTM Annual Cost Components | |
| Gas Fuel Cost | — |
| Variable O&M | — |
| Fixed O&M | — |
| Annualized Capital Cost | — |
| Gas Transport / Reservation | — |
| Utility Standby / Backup | — |
| Residual Grid Purchases (generator offline hours) | — |
| Total Estimated BTM Annual Cost | — |
| Estimated Annual Cost Difference | — |
Illustrative Historical Winter Basis Ranges. These ranges illustrate historical basis volatility and relative regional pipeline risk over recent winter periods. They are not current forward-market quotes and should not be used as executable pricing. Actual daily basis varies materially from these ranges and can exceed them during extreme weather or pipeline outages. Source: ICE, broker market data, pipeline tariff filings.
| Hub / Delivery Point | Pipeline | Region | Illustrative Non-Winter Basis | Illustrative Winter Basis Range | Notes for BTM / IPP Fuel Supply |
|---|---|---|---|---|---|
Henry Hub Benchmark |
Sabine Pipe Line | Erath, Louisiana | $0.00 (index) | $0.00 (index) | NYMEX natural gas futures benchmark. No physical delivery in the Northeast — the difference between Henry Hub and your delivery point is what you actually pay. |
Transco Zone 6 NY Constrained |
Transcontinental Gas Pipe Line (Transco) | New York City pricing location; parts of the NYC metro area | +$0.25 to +$1.50 | +$2 to +$20+ | Primary NYC city-gate pricing point on the Transco system. Note: New Jersey project delivery pricing may reference Transco Zone 6 non-NY, TETCO M-3, or other points depending on physical delivery location — do not assume Zone 6 NY applies to all NJ projects. Transco is the most heavily subscribed pipeline in the Northeast corridor; winter spikes are common when firm capacity is fully allocated. |
Algonquin Citygate Highly Constrained |
Algonquin Gas Transmission | New England (CT, MA, RI, NH) | +$0.50 to +$2.00 | +$5 to +$35+ | Historically the most constrained pipeline hub in the country during cold snaps. New England pipeline infrastructure is severely capacity-limited. Basis spiked above $35/MMBtu during Winter Storm Elliott (December 2022). Any data center or power plant in New England should treat basis hedging at contract execution as non-negotiable. Consider firm transport acquisition and/or alternative supply options. |
Tennessee Zone 6 (New England) Highly Constrained |
Tennessee Gas Pipeline | New England (MA, CT, NY border) | +$0.25 to +$1.50 | +$3 to +$30+ | Parallel path to Algonquin serving New England. Similar constraint dynamics to Algonquin Citygate; the two pipelines serve overlapping markets and typically move in tandem during cold weather events. Both should be considered in supply portfolio construction for New England generation. |
TETCO M-3 Moderate–High |
Texas Eastern Transmission (TETCO) | Philadelphia / South Jersey / Delmarva | +$0.10 to +$0.75 | +$1 to +$8 | Primary delivery point for Philadelphia-area industrial customers and South Jersey generators. Less volatile than Algonquin/Tenn Z6 but subject to winter tightness. Relevant for PJM PECO and PSEG zone generators and BTM data center projects in the Philadelphia metro corridor. |
Eastern Gas South (formerly Dominion South) Appalachian Discount |
Equitrans / Equitable Gas | SW Pennsylvania / WV Marcellus Basin | −$0.25 to −$2.00 | −$0.50 to −$3.00 | Trades at a persistent discount to Henry Hub because Appalachian (Marcellus/Utica) production regularly exceeds local takeaway capacity. A generator or data center with physical access to this point has a structural fuel cost advantage over those buying at constrained Northeast delivery points. The challenge is securing firm transport capacity out of the Appalachian basin to where the gas is needed. |
Waha (Permian Basin) Often at or Below Zero |
Various (El Paso, Permian Basin pipelines) | Permian Basin, West Texas | −$1.00 to −$5.00+ | −$0.50 to −$3.00 | Shown for comparative context. Waha can trade at or below zero when Permian production exceeds available takeaway capacity, a recurring dynamic in recent years. A Northeast project cannot access Waha economics without the pipeline capacity to move gas east — but this hub illustrates how dramatically basis varies across the country and why delivery-point basis risk must be explicitly addressed in every fuel supply agreement. |
This is a qualitative planning reference comparing the relative basis and pipeline risk of major U.S. and Northeast delivery points. The ranges are illustrative orders of magnitude drawn from historical winter behavior, not a current forward curve, a settlement study, or an executable quote. Actual daily basis at your delivery point varies materially and can exceed these ranges during extreme weather or pipeline outages. For firm supply structuring and basis hedging at your specific delivery point, contact Digby Ferrara at Aggressive Energy. Sources: ICE, pipeline tariff filings, and public EIA and pipeline references. Last reviewed: August 2026.
These tools provide a framework — but real project economics depend on your specific delivery point, firm transport availability, interconnection status, and deal structure. That's the work I do with data center developers, BTM project teams, and C&I buyers across PJM and NYISO.