Henry Hub natural gas futures started the final week of September on weaker footing, falling to about $3.11 per MMBtu after touching a 13-week high just days earlier. The retreat came as the October Nymex contract expired and trading shifted into November, a rollover that often amplifies short-term volatility.
The price move matters because it tests whether last week’s rally reflected a genuine tightening in the U.S. gas market or a temporary short-covering squeeze. For traders, producers and energy investors, the immediate focus has narrowed to one level: support near $3.10.
Behind the pullback is a market being pulled in two directions. Domestic production remains strong at a near-record 112.8 Bcf/d for September, while LNG feedgas demand has climbed to 17.8 Bcf/d, underscoring how global gas shortages continue to absorb U.S. supply.
Key Facts
- Henry Hub natural gas traded near $3.11 per MMBtu, down 2.65% from $3.20 after an early slide toward $3.100.
- U.S. natural gas production averaged 112.8 Bcf/d in September, close to record levels despite a temporary dip to 108.4 Bcf/d on September 24.
- LNG feedgas flows reached 17.8 Bcf/d in September, up from 17.2 Bcf/d in August.
- Working gas in storage stood at 3,351 Bcf for the week ended September 18, or 95 Bcf above the five-year average.
- November futures rallied as high as $3.377 last week before retreating, leaving a near-term trading range of $2.976 to $3.377.
Henry Hub Natural Gas
The latest retreat in Henry Hub natural gas follows one of the strongest single-session gains of the year. Futures surged 5.80% on September 24 after a mechanical issue on TC Energy’s Columbia Gas Transmission pipeline in Appalachia disrupted flows, while the latest storage report showed a smaller-than-normal injection. At the same time, Lower 48 production briefly dropped, adding to the sense that the market was tightening faster than expected.
That bullish setup faded over the weekend. The pipeline issue was resolved, reducing the immediate supply threat, and seasonal demand is shifting as the U.S. moves out of peak cooling season. The October contract’s expiry also encouraged position-closing and contract rolls, which can distort price action and exaggerate gaps in either direction.
Even after the pullback, the broader picture is more balanced than bearish. Storage remains above the five-year average, which limits the urgency of supply concerns, but the surplus has narrowed. Smaller injections through September suggest domestic balances are tightening, especially along the Gulf Coast, where LNG facilities are pulling heavily on nearby supply. That leaves Henry Hub caught between comfortable inventories and a structural export bid.
Henry Hub is no longer trading on domestic supply alone; strong LNG demand is steadily shrinking the margin of comfort in U.S. gas balances.
Why $3.10 Has Become the Pivot
Technically, the market has established a new short-term range after last week’s squeeze. November futures surged from roughly $2.976 to $3.377, then slipped back below the retracement area between $3.129 and $3.177. That makes $3.10 an important line for near-term sentiment.
If prices hold above $3.10, bulls can argue that the breakout remains intact and that the market may retest $3.377. A clean break below that level would raise the odds of a fuller retracement toward $2.976, especially if production recovers quickly and weather stays mild into early October.
Implications for Investors
For investors, the natural gas setup remains highly tactical. On one side, near-record output continues to cap upside. U.S. production at 112.8 Bcf/d in September suggests supply remains abundant, particularly with associated gas growth tied to strong oil drilling activity in the Permian. If output returns toward 112 Bcf/d after recent operational interruptions, rallies above the mid-$3 range may struggle to hold.
On the other side, LNG demand remains the market’s strongest support. Feedgas flows of 17.8 Bcf/d in September point to robust export utilization, and Gulf Coast storage data shows how that demand is tightening regional balances. South Central inventories are especially important because they supply export terminals. If LNG feedgas rises further as maintenance eases or new capacity ramps, the domestic storage surplus could continue to shrink heading into winter.
Energy equities may respond differently depending on where value accrues. Gas-weighted producers such as EQT and Coterra Energy are more directly exposed to Henry Hub price changes, while LNG-linked names such as Cheniere benefit from a wide international price spread. Investors should also monitor weather forecasts, weekly EIA storage data, pipeline operations in Appalachia and the Gulf Coast, and any signs that global LNG supply disruptions are easing. Those factors will determine whether natural gas remains range-bound or pushes toward the 200-day moving average near $3.529.
The next few sessions are likely to clarify whether the late-September rally marked the start of a stronger autumn move or the end of a contract-expiry squeeze. If storage continues tightening and LNG demand stays elevated, Henry Hub could regain momentum; if production rebounds and demand softens, pressure on the $3.10 support level may intensify.