Natural gas prices in summer 2026 are sitting close to $3 per million British thermal units (MMBtu), a fraction of the winter spike, because record production is refilling storage nearly as fast as it did a year ago. The Henry Hub spot price averaged $3.34 per MMBtu in the week ending July 3, 2026, up from $2.66 in the week ending May 1, while working gas in storage reached 2,922 billion cubic feet (Bcf) as of June 26, 2026, only 31 Bcf below the same week of 2025 [1][2]. The front-month futures contract settled at $3.20 on July 2, according to DataPorium commodity price data [5]. This note reviews the price path, the storage arithmetic, and what the U.S. Energy Information Administration (EIA) expects for the rest of the injection season.
How natural gas prices in summer 2026 compare with the winter spike
The contrast with January is stark. Henry Hub averaged $7.72 per MMBtu in January 2026, the highest monthly average in this cycle, then fell to $3.62 in February, $3.04 in March and $2.77 in April before recovering to $2.94 in May and $3.15 in June [3]. The June average was only 13 cents above June 2025, when Henry Hub averaged $3.02 [3]. In other words, the market has fully unwound the winter premium and is trading close to where it was one year ago.
The weekly series shows the same shape. After bottoming at $2.66 in the week ending May 1, the spot price climbed steadily: $2.86 in mid-May, $3.16 at the end of May, $3.20 in the week ending June 26 and $3.34 in the week ending July 3 [2]. Warmer weather and higher power burn explain most of the increase. The EIA noted in its June outlook that daily prices moved above $3.00 late in May as cooling demand began to lift natural gas consumption in the electric power sector [4].
What the storage data say about supply
Storage is the clearest measure of how well supply is keeping up with demand. Working gas in the Lower 48 states stood at 1,900 Bcf on April 3, 2026, near the seasonal low, and reached 2,922 Bcf on June 26 [1]. That is an increase of 1,022 Bcf in 12 weeks, an average injection of about 85 Bcf per week. The week ending June 26 alone added 87 Bcf [1].
A year earlier, on June 27, 2025, storage held 2,953 Bcf [1]. The 2026 level is therefore 31 Bcf, or about 1%, lower than last year despite a colder winter that drained inventories and a record price spike in January. Closing that gap so quickly required sustained production growth.
Weekly storage and price snapshot
| Week ending | Working gas (Bcf) | Weekly change (Bcf) | Henry Hub weekly average ($/MMBtu) |
|---|---|---|---|
| May 29, 2026 | 2,578 | +95 | 3.16 |
| June 5, 2026 | 2,686 | +108 | 3.03 |
| June 12, 2026 | 2,759 | +73 | 3.16 |
| June 19, 2026 | 2,835 | +76 | 3.12 |
| June 26, 2026 | 2,922 | +87 | 3.20 |
Source: EIA weekly storage and Henry Hub spot price tables [1][2].
Why production growth is capping prices
The EIA's June 2026 Short-Term Energy Outlook, published June 9, expects U.S. marketed natural gas production to grow 3.3% in 2026, about 3.9 Bcf per day, and another 2.5% in 2027 [4]. Most of the upward revision since January comes from associated gas in the Permian region, where higher crude oil prices in the first half of 2026 encouraged more drilling for oil and, with it, more gas [4]. The Haynesville region, which responds more directly to gas prices and to demand from Gulf Coast liquefied natural gas (LNG) export terminals, is also growing [4].
The result is a forecast in which inventories stay above the five-year average and prices stay contained. The EIA expects Henry Hub to average about $3.34 per MMBtu in the second half of 2026 and $3.46 in 2027, and it lowered its 2027 forecast by $1.13 per MMBtu compared with its January outlook [4]. For the full year 2026 the agency's headline forecast is $3.60 per MMBtu, a number that includes the expensive January [4].
From a market perspective, this is a supply response working as intended. High prices in January signaled scarcity, producers and pipeline operators responded, and the price fell back. No policy intervention was needed; private capital did the work.
What could move natural gas prices before winter
Three variables matter most for the rest of the injection season:
- Summer heat. Power burn is the main source of seasonal demand growth. A hotter than normal July and August would slow injections and support prices, as the late May move above $3.00 showed [4].
- LNG export capacity. Feedgas demand from export terminals removes gas from the domestic balance. Any maintenance or new capacity changes the weekly storage math.
- End-of-season storage. The market will focus on whether inventories reach the upper end of the historical range by the end of October. At the current pace of injections, storage is on track to exceed the 2025 level before autumn if production holds.
The counterpoint is that low prices carry their own risk. If Henry Hub stays below $3.00 for long, gas-directed drilling in basins like the Haynesville tends to slow, and the market can tighten quickly when winter demand arrives. The January 2026 spike is a reminder that a balanced storage picture in summer does not guarantee a calm winter.
Record production has erased the winter premium, leaving natural gas near $3 with storage almost level with last year as the second half of the injection season begins.
Key takeaways
- Henry Hub averaged $3.34 per MMBtu in the week ending July 3, 2026, up from a spring low of $2.66 but far below the $7.72 January monthly average [2][3].
- Working gas in storage reached 2,922 Bcf on June 26, 2026, 31 Bcf below the same week of 2025, after 1,022 Bcf of injections in 12 weeks [1].
- The EIA expects marketed production to grow 3.3% in 2026 and forecasts Henry Hub near $3.34 in the second half of the year [4].
- Summer heat, LNG feedgas and the end-of-October storage level are the main swing factors for prices into winter.
- Live futures and EIA series are available on DataPorium's commodities and energy pages [5].
Frequently asked questions
Why are natural gas prices low in summer 2026 after the January spike?
Production is growing about 3.3% in 2026, driven by associated gas from Permian oil wells, and storage has been refilled to within 1% of last year's level. With supply ahead of demand, the January premium has disappeared and Henry Hub trades near $3 per MMBtu [1][4].
How much natural gas is in storage as of late June 2026?
Working gas in underground storage in the Lower 48 states was 2,922 Bcf as of June 26, 2026, after a weekly injection of 87 Bcf, compared with 2,953 Bcf a year earlier [1].
What is the EIA forecast for Henry Hub prices in the second half of 2026?
The June 2026 Short-Term Energy Outlook projects Henry Hub to average about $3.34 per MMBtu in the second half of 2026 and $3.46 in 2027, with the full-year 2026 average near $3.60 because of the high January prices [4].
Where can I track natural gas futures and storage data?
DataPorium's commodities page carries daily Henry Hub futures (NG=F) and its energy page carries EIA production and inventory series, while the EIA publishes weekly storage every Thursday [1][5].
