Noreva Prompt, Forward Natural Gas Price Forecasts Featured by NGI

What the NGI coverage examined

NGI’s December 8, 2025 report covered a sharp single-session reversal in the prompt-month contract and asked what was actually driving it. The market data behind the move (NGI, Dec. 8, 2025):

• The prompt-month contract settled down 37.7 cents at $4.912, after trading between $4.850 and $5.205 during the session.
• NGI’s Spot Gas National Avg. fell 14.5 cents to $5.510.
• Working gas inventories stood at 3,923 Bcf for the week ended November 28, 18 Bcf below year-ago levels but 191 Bcf above the five-year average (EIA, via NGI).
• Production slipped to 109.3 Bcf/d, with the December-to-date average at 109.4 Bcf/d (Wood Mackenzie, via NGI).
• NGI modeled a 163 Bcf withdrawal for the following report, against a 167 Bcf year-ago draw and an 89 Bcf five-year average decrease.
• LNG feed gas deliveries to Lower 48 export facilities ran at 18.7 Bcf/d, up from 18.3 Bcf/d the prior session (NGI LNG Export Flow Tracker).

The setup was unusual: a large storage withdrawal was coming, and futures fell anyway. That is the kind of session where the fundamental print and the price move point in opposite directions, and where the explanation has to come from what the market is pricing forward rather than what it just observed.

Gardett’s first point was that the rally had been resting on a narrow condition. As quoted in NGI: “With inventories running a bit ahead of this point last year and robust November production numbers, it would have required a lengthy period of cold weather to keep prompt-gas futures prices where they were in recent sessions.”

When mid-range models trimmed expected cold, that condition failed. On the demand signal: “Anticipated demand urgency is lessened.”

And on why the reversal was structural rather than surprising: “Of the three legs of the stool holding up elevated prices – storage levels, production comparables and cold weather – all three have weakened in the most recent data sets. No surprise there’s been a reversion.”

His forward point was the one that matters most for anyone holding winter risk. Gardett separated the 2026 baseline from the remaining upside in the current winter: “The baseline price for natural gas could be higher in 2026 as LNG export contracts take away supply, but the usual pattern for gas trading is that if you don’t see ‘trouble’ by the end of January, you’re in the clear. So, the number of sessions remaining where we could see a market pop or a higher price structure go into place for this winter is steadily wearing away.”

Why the prompt-versus-forward split matters

The two halves of that argument pull in opposite directions, and both can be true. Winter 2025-26 lost most of its upside case as weather, storage, and production moved the same way at once. The 2026 baseline is a different question, set by export commitments rather than by a cold snap.

For asset owners, gas marketers, and power desks, conflating the two is expensive. A prompt-month reversion says nothing about where the curve sits twelve or twenty-four months out, and a structurally higher LNG-driven baseline says nothing about whether January delivers a spike. Noreva’s fuels work keeps those layers separate: transaction-aligned forward curves for natural gas and LNG, scenario forecasts that price the export-driven baseline, and the basis detail that determines what a given molecule is worth at a given hub.

Time decay is the underrated part of Gardett’s read. Optionality on a winter price event is not static. Every session that passes without a cold-driven move removes sessions in which one can occur, which is a position-management fact before it is a forecasting one.