The storage report is the story
The U.S. has too much gas. That is not a slogan. That is the weekly print.
For the week ending August 7, EIA reported a 36 billion cubic foot injection. Traders wanted something closer to 30 to 33. Working gas hit 3,153 Bcf, 25 Bcf below last year and 198 Bcf above the five-year average of 2,955. The surplus grew through the stretch of summer that was supposed to shrink it.
The next week, ending August 14, the national build shrank to 16 Bcf and inventories sat at 3,169 Bcf. That looked tighter until you read the regional table. South Central salt storage withdrew 18 Bcf. The East and Midwest still injected. National inventories were 6.2 percent above the five-year average and about 1 percent below a year ago.
EIA's August outlook takes that path and runs it to the end of October: 3,985 Bcf. A record. Five percent above average. Highest heading into winter since 2016. The July outlook was already high. August added another 19 Bcf to the call.
Why the price forecast cracked
Henry Hub for the third quarter is now $2.87, down 50 cents from July. The 2026 average is $3.44, down from $3.67. Next year is $3.31. Back in February, after Fern, the agency had this year at $4.31. That number has been walked down all year.
Two drivers sit in the text. Production is on a record run. EIA has dry gas averaging 111.2 Bcf per day in 2026, up 3.3 percent from the 2025 record. Marketed production is near 123 Bcf per day. AGA, using S&P data through August 20, said Lower 48 output was about 3 percent above last August and 3.6 percent higher year to date. The Permian is throwing off associated gas. Haynesville is answering Gulf Coast feedgas demand when the plants are actually running.
The other driver is missing LNG demand. Maintenance at Freeport started July 10 and is supposed to finish late August. That is about 2 Bcf per day of nameplate sitting idle. EIA cut third-quarter U.S. LNG exports to 16.5 Bcf per day. Feedgas to the nine major plants has been running around 17.1 to 17.3 Bcf per day this month, well below the early-year daily record of 19.6. Gas that would have been on a ship stayed in Texas and Louisiana caverns.
Heat showed up. The surplus did not leave
A heat dome sat on the southern United States. Texas and the Southeast burned gas for air conditioning. AGA said those two power regions were up 5.4 percent week over week into August 20. The rest of the country was cooler, so national power burn still fell.
That is why the prompt did not spike. Local heat is not a national shortage. Traders know the difference. EIA still expects gas-fired generation to rise 2 percent this year and 3 percent next year because cheap gas is winning in the power stack again. Gas is still about 40 percent of U.S. electricity. That is demand. It is not enough demand to clear a record supply stack plus a Freeport outage.
The winter argument starts now
Sellers do not need October to arrive before they trade 3,985 Bcf. They are already positioned for it. Buyers need Freeport back, a storage miss to the downside, or a first cold snap that actually draws the surplus. None of those have shown up in the data that matters.
The American Gas Association put the next question cleanly. Will strong production and fading seasonal demand accelerate injections into the shoulder? Or does recovering LNG export and a thin European winter bid finally give the prompt a reason to leave the twos?
Until one of those breaks, the official forecast is the honest one. Henry Hub stays cheap because the inventory is already built.