U.S. commercial natural gas rates average $1.20/therm nationally. Henry Hub benchmark spot price is $2.72/MMBtu (as of 2026-04-27). 26 states offer competitive gas supply choice. Compare rates, track market trends, and find gas suppliers in your state.
Source: static-eia-snapshot | Updated 2026-04-27
Analysis of natural gas basis differentials in the US Northeast for 2026. Why severe pipeline constraints cause Algonquin Citygate prices to decouple from Henry Hub.
Golden Pass LNG begins exports from Sabine Pass, Texas with 18 MTPA capacity. Impact analysis on Henry Hub prices and commercial natural gas procurement.
Pipeline constraints into New England drove delivered gas costs well above Henry Hub. CT, MA, NY, and NJ commercial buyers saw delivery charges spike during the cold snap.
26 states allow commercial customers to choose their natural gas supplier. Click a state for rates and market data.
EIA's April 30 Weekly Natural Gas Storage Report showed a 79 Bcf injection for week ending April 24, 2026. Lower 48 working gas reached 2,142 Bcf, 116 Bcf above last year and 153 Bcf above the five-year average.
EIA's April 23 Weekly Natural Gas Storage Report showed a 103 Bcf injection for week ending April 17. Lower 48 working gas reached 2,063 Bcf, 142 Bcf above last year and 137 Bcf above the five-year average. Procurement read-through for gas-indexed electricity.
Side-by-side 2026 Henry Hub forecasts from Wood Mackenzie ($4.10), EIA STEO ($3.72), S&P Global ($3.95), Goldman, BofA, and Morgan Stanley. Consensus ~$3.85/MMBtu, range $3.20–$4.60. LNG feedgas, data-center burn, and winter 2026-2027 risk breakdown for procurement teams.
NGI forecasts 62 Bcf injection for week ending April 10 — more than double the initial 27 Bcf consensus. Storage surplus widens to 122 Bcf above 5-year average. Henry Hub at $2.58/MMBtu, lowest since Q4 2025 and 32% below EIA's $3.80 annual forecast. Commercial procurement window analysis.
Forecast archive for the April 16, 2026 EIA storage report: a 27 Bcf consensus missed the final 59 Bcf build, later revised to 60 Bcf implied flow. Current readers should use the April 30 storage report and Natural Gas Storage hub.
EIA reports 50 Bcf net injection for week ending April 3, 2026. Working gas at 1,911 Bcf — 87 Bcf above the 5-year average. Henry Hub spot at $2.65/MMBtu, 30% below EIA's $3.80 annual forecast. NYMEX summer curve tops at $3.18. Commercial procurement window analysis.
EIA reports a 36 Bcf net injection for the week ending March 27, 2026 — the first build of the season, arriving two weeks earlier than the 5-year average. Working gas at 1,865 Bcf. Henry Hub holds at $2.90. What early injections mean for gas-indexed electricity procurement.
EIA natural gas storage at 1,829 Bcf entering the 2026 injection season. Refill math: ~67 Bcf/week needed over 30 weeks to reach comfortable pre-winter levels. Henry Hub at $2.90 vs $3.80 EIA forecast. Commercial procurement timing analysis.
Henry Hub natural gas falls to $2.90/MMBtu entering the April 2026 injection season. Storage above 5-year average despite record winter. EIA forecasts $3.80 annual average. Commercial procurement window analysis and why gas prices still matter for your electricity bill.
EIA weekly storage report March 26, 2026: 54 Bcf net withdrawal, working gas at 1,829 Bcf. Henry Hub spot at $3.82/MMBtu. Injection season outlook and commercial procurement analysis.
EIA weekly storage report shows 38 Bcf draw for week ending March 6, 2026. Working gas at 1,848 Bcf remains 17 Bcf below the 5-year average. Henry Hub at $3.13/MMBtu. Commercial procurement window analysis.
The EIA March 2026 STEO slashes the Henry Hub forecast from $4.30 to $3.80/MMBtu — the largest monthly downward revision of 2026. Spot price at $3.19, 16% below revised forecast. Commercial procurement window analysis.
March 2026 EIA natural gas storage snapshot: 132 Bcf draw, working gas at 1,886 Bcf, and Henry Hub rebound to $3.37/MMBtu.
Henry Hub March 2026 futures collapsed to $2.90/MMBtu—a 30% discount to the EIA's $4.12 forecast. Storage at 2,018 Bcf. Procurement window analysis for gas and electricity buyers.
EIA's April 28 Today in Energy update reports TTF LNG futures up 35% and JKM up 51% after the Strait of Hormuz closure, while U.S. Henry Hub fell 9%. Current buyer guidance separates confirmed global LNG stress from conditional U.S. gas and power pass-through risk.
A larger-than-expected 52 Bcf withdrawal erased the winter storage cushion, dropping national gas inventories 0.3% below the historical average going into spring.
Natural gas crashed from $7.72/MMBtu in January to $2.83 on Feb 26. Record 360 Bcf withdrawal, then warm weather collapse. Storage 123 Bcf below 5-year average.
EIA: Natural gas storage at 2,070 Bcf, down 144 Bcf weekly. Stocks 123 Bcf below 5-year avg. Henry Hub pricing and commercial gas rate analysis.
Analysis of the ERCOT natural gas-to-power correlation in Texas. Learn how the implied heat rate dictates commercial wholesale electricity prices in 2026.
A 2026 playbook for industrial and manufacturing natural gas procurement. How to execute Block and Index hedges to protect chemical and metals plants.
Analysis of natural gas basis differentials in the US Northeast for 2026. Why severe pipeline constraints cause Algonquin Citygate prices to decouple from Henry Hub.
How record oil production in the Permian Basin drives massive associated natural gas supply. Analysis of new pipelines like Matterhorn Express on 2026 rates.
Analysis of the 2026 Henry Hub natural gas forward curve. Learn why steep contango driven by LNG exports requires commercial buyers to hedge during spring.
Golden Pass LNG begins exports from Sabine Pass, Texas with 18 MTPA capacity. Impact analysis on Henry Hub prices and commercial natural gas procurement.
An analysis of Massachusetts' commercial natural gas market in 2026. How National Grid customers can mitigate severe physical pipeline constraints and rising delivery tariffs.
An analysis of Minnesota's commercial natural gas market in 2026. How Xcel Energy's court-approved rate hikes and pipeline modernization costs are driving up winter heating bills for businesses.
Track the massive buildout of U.S. Liquefied Natural Gas (LNG) export terminals in 2026 and understand how rising global demand is driving up domestic natural gas prices.
PG&E commercial customers are facing extreme natural gas rate volatility in Winter 2026 due to regional pipeline constraints and storage deficits. Discover hedging strategies.
Chicago metro natural gas buyers face elevated delivered costs. Analysis of the Citygate basis premium impacting Nicor Gas and Peoples Gas territories.
Commercial facilities in Georgia face rising Henry Hub spot prices in 2026. Guide to navigating Atlanta Gas Light (AGLC) territory marketer contracts.
US natural gas working inventories remain supportive exiting winter 2026, but Henry Hub forward contango incentivizes spring commercial procurement.
The EIA Short-Term Energy Outlook expects dry natural gas production to increase by an average of 2 Bcf/day (2%) in 2026, relieving supply constraints in Q3/Q4.
Henry Hub spot at $3.13/MMBtu. EIA storage at 2,070 Bcf (-123 below 5yr avg). Cold snaps drive basis spikes in Northeast and Chicago. LNG exports nearing record capacity.
EIA storage at 2,070 Bcf, which is 123 Bcf (5.6%) below the five-year average. Recent net withdrawals of 144 Bcf/wk signal tightening supply buffer.
Pipeline constraints into New England drove delivered gas costs well above Henry Hub. CT, MA, NY, and NJ commercial buyers saw delivery charges spike during the cold snap.
Chicago Citygate basis running above Henry Hub. IL and MI commercial buyers facing higher delivered costs. Nicor Gas and Peoples Gas territories most affected.
PA remains the most competitive gas choice market with Columbia Gas, PECO Gas, and UGI territories all fully open. Commercial buyers can lock sub-$0.95/therm fixed rates.
Georgia natural gas market fully deregulated under AGLC. Atlanta Gas Light serves as distribution-only utility. 10+ certified marketers competing for commercial load.
EIA projects natural gas prices to nearly double from 2024 lows ($2.20/MMBtu) driven by LNG export growth and colder winters. Commercial buyers should evaluate fixed-rate contracts before winter 2025.
Residential and commercial gas consumption surged 11.9% in Q1 2025 vs 2024. Storage inventories swung from surplus to deficit. This pattern signals higher winter costs ahead.
Weekly EIA storage report shows 85% capacity heading into the 2025-2026 heating season. While adequate, it leaves limited buffer against a severe winter scenario or production freeze-offs.
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