Henry Hub natural gas reaches $3.20/MMBtu by September 30, 2026 in the base case, $3.70 in the bull case and $2.60 in the bear case. The mechanism is counterintuitive: the same Strait of Hormuz shock that has driven crude 19% higher this month is bearish for US gas, because $80 oil pulls more Permian associated gas out of the ground than Hormuz-disrupted LNG can pull out of the country.

Henry Hub fell to $2.90/MMBtu on July 13, 2026, its lowest in two months, even as West Texas Intermediate (WTI) crude ran from $67 to nearly $80 a barrel. That divergence is not an anomaly to be arbitraged away. It is the correct response to a supply shock that hits the global liquefied natural gas (LNG) market and the US drilling economy in opposite directions. The thesis breaks if any one of four signals fires, listed in the Disconfirmation section.

Key Levels:

• Asset: Henry Hub natural gas front-month, $2.90/MMBtu — spot, July 13, 2026
• Base case target: $3.20/MMBtu by September 30, 2026 — seasonal power burn lifts the strip, capped by associated-gas supply
• Bull case target: $3.70/MMBtu — the EIA’s 2026 annual average; requires a hot late summer plus a sustained LNG export pull
• Bear case target: $2.60/MMBtu — requires the Permian supply response to accelerate into mild weather
• Major support: $2.60/MMBtu — the level below which producers begin curtailing dry-gas programmes
• Major resistance: $3.19/MMBtu — the June month-to-date average, now the ceiling of the range
• Invalidation level: a weekly close above $3.60 — signals the LNG pull has beaten the supply response, killing the thesis

Methodology

Price data is NYMEX Henry Hub front-month as of July 13, 2026. Supply and demand forecasts come from the US Energy Information Administration’s (EIA) Short-Term Energy Outlook, published July 7, 2026. Global LNG balance data comes from the International Energy Agency’s (IEA) Q3 2026 Gas Market Report. Production figures are EIA Lower 48 marketed gas.

The main caveat is weather, which dominates gas at this horizon and is not forecastable at a quarter’s distance. A single sustained heat dome can add more to the strip than every structural factor in this note combined. Treat the base case as a fundamental anchor around which weather will do most of the observable work.

The data

The bearish inputs are not marginal. Lower 48 marketed gas production averaged 117.2 Bcf/d in the first quarter of 2026, up 4% year-on-year, driven primarily by Permian Basin associated gas — gas that comes up as a by-product of oil drilling and is therefore priced off the oil rig count, not the gas price. Storage is comfortable and running above the five-year average. And the immediate trigger for the two-month low was mundane: milder weather and reduced flows to LNG export facilities.

The bullish input is real but slower. The EIA forecasts LNG feedgas demand to grow 9% (1.3 Bcf/d) in 2026 and 11% (1.7 Bcf/d) in 2027, making it the single largest source of incremental demand across the forecast period. Rystad Energy sees feedgas volumes reaching 18.7 Bcf/d in 2026 and 21.1 Bcf/d in 2027. Hormuz should, in theory, supercharge that: the IEA notes that Strait of Hormuz LNG flows have accounted for almost 20% of global LNG supply.

Input	Value	Source / date	Direction for Henry Hub
Henry Hub spot	$2.90/MMBtu	NYMEX, July 13, 2026	Two-month low
Lower 48 marketed production	117.2 Bcf/d (+4% YoY)	EIA, Q1 2026	Bearish
LNG feedgas demand growth	+1.3 Bcf/d (+9%)	EIA STEO, July 7, 2026	Bullish
Hormuz share of global LNG	~20%	IEA Gas Market Report Q3 2026	Bullish (global), neutral (US)
Gulf LNG decline offset	~75% replaced	IEA, March–June 2026	Bearish
EIA 4Q26 forecast	$3.57/MMBtu (−5% YoY)	EIA STEO, July 7, 2026	Modestly bullish vs spot
WTI crude	$80/bbl (from $67)	NYMEX, July 14, 2026	Bearish (associated gas)

Sources: NYMEX front-month settlements; EIA Short-Term Energy Outlook, July 7, 2026; IEA Gas Market Report Q3 2026; Rystad Energy feedgas forecasts.

Why is an oil shock bearish for US natural gas? Because the two commodities are joined at the wellhead. Roughly a third of US gas supply now arrives as associated gas from oil wells, concentrated in the Permian. When crude runs from $67 to $80, the economics of oil drilling improve sharply — and every incremental oil well brings gas with it, regardless of what the gas price is doing. That gas is price-insensitive: the producer is drilling for the oil. So a crude rally mechanically increases US gas supply within a couple of quarters. Meanwhile the demand side of the Hormuz story — a global LNG shortage pulling US cargoes — is real but slow, capped by liquefaction capacity that cannot be added on a headline. Supply responds in quarters; export capacity responds in years.

“The supply response from higher crude prices would likely outweigh any increase in LNG exports from the US here, at least in this calendar year… the more bullish it is for crude oil prices. And that in turn adds a little bit of a bearish note to US gas prices, at least for the rest of calendar 2026.”

— Patrick Rau, Analyst, East Daley Analytics (Natural Gas Intelligence)

The mechanism

The path back to $3.20 is seasonal, not structural. Summer power burn is the one demand source large enough to absorb 117 Bcf/d of supply, and it arrives on schedule. The EIA’s own July 7 Short-Term Energy Outlook has Henry Hub averaging $3.57/MMBtu in the fourth quarter — 5% below the same quarter last year, but 23% above where spot printed on July 13. Even the official forecast, in other words, sees the current level as a trough rather than a trend.

What it does not see is a Hormuz-driven melt-up, and neither do we. The IEA’s most important finding is the one the bulls skip: new LNG supply from North America and Africa, plus improved feedgas availability from legacy producers, offset about three-quarters of the decline in Gulf LNG deliveries between March and June. The global LNG market absorbed a 20% supply hit and replaced most of it. That is a market with more slack than the headline suggests, and it caps how hard the export arbitrage can pull on Henry Hub.

This is the cross-market point, and it is why this call sits alongside rather than against our others. Our WTI-to-$66 call has been overrun by the blockade; our DXY-to-105 case reads the same shock as dollar-positive through the front end; and our USD/CAD reversal reads it as CAD-positive through terms of trade. Gas is the fourth branch: the same event, transmitted through the drill bit rather than the discount rate, arrives with the opposite sign. An “energy shock” is not a shock to all energy.

The steelman for the bulls: liquefaction capacity is being commissioned through 2026 and 2027, and if a hot August coincides with a Hormuz closure that persists, the export pull and the power burn could arrive together and overwhelm the supply response before the rigs can answer. That is a genuine path to $3.70, and it is why the bull case is not dismissed.

What the model misses

The associated-gas response has a lag the model treats as shorter than it is. Permian operators are under capital discipline from equity holders and do not add rigs on a two-week oil rally; they add them on a sustained strip. If the Hormuz premium proves brief, the supply response never arrives and the bearish leg of this thesis evaporates with it.

The model also underweights takeaway constraints. Permian gas needs pipe to reach Henry Hub, and Waha basis has historically gone negative precisely because it cannot. More associated gas does not automatically mean more Henry Hub supply — it can simply mean a wider Waha discount and stranded molecules, which is bearish for West Texas and neutral for the national benchmark.

And storage is a two-sided risk. Analysts at Gelber & Associates frame the summer question as “whether the warmer forecast can overpower the reminder that inventories remain above the five-year average” — noting that “the storage cushion remains meaningful even as summer demand begins to build”. A cushion cuts both ways: it caps rallies, but a hot quarter drains it faster than the market expects.

Disconfirmation

The call to $3.20 is wrong if any of these fire:

• A weekly close above $3.60/MMBtu. That would signal the LNG export pull has beaten the associated-gas supply response — the core claim of this note — and puts the EIA’s $3.57 fourth-quarter figure in play a quarter early.
• WTI closes below $70 on a Hormuz de-escalation. Remove the oil rally and the associated-gas supply impulse never materialises. The bearish cap comes off, and gas trades on weather and storage alone.
• Lower 48 production falls below 115 Bcf/d. The supply-glut premise is the whole argument. A production roll-over — from capital discipline, takeaway constraints or well depletion — invalidates it directly.
• Storage falls below the five-year average before September. The cushion is what caps the rally. If a hot summer drains it early, the bear case is gone and the bull case is live.

What to watch next

The weekly EIA storage report is the single highest-frequency input, and the five-year-average comparison is the number that matters, not the headline injection. Then the Baker Hughes rig count: a rising Permian oil rig count in August and September is the leading indicator of the associated-gas wave this call depends on. Watch LNG feedgas flows for evidence that the Hormuz dislocation is actually pulling US cargoes rather than being absorbed by Atlantic-basin supply. And watch the Waha basis — if it widens sharply negative, the Permian gas is being produced but not delivered, and the bearish transmission to Henry Hub is weaker than modelled.

FAQ

What is the Henry Hub forecast for Q3 2026?

Our base case is $3.20/MMBtu by September 30, 2026, from $2.90 on July 13. The bull case is $3.70, matching the EIA’s 2026 annual average, and requires a hot late summer plus a sustained LNG export pull. The bear case is $2.60, driven by an accelerating Permian associated-gas supply response into mild weather.

Why did natural gas fall while oil surged?

Because roughly a third of US gas arrives as associated gas from oil wells. When crude runs to $80, oil drilling economics improve and every new oil well brings gas with it regardless of the gas price. Supply responds in quarters; LNG export capacity, the offsetting demand channel, responds in years.

Doesn’t the Hormuz closure mean a global gas shortage?

It removed roughly 20% of global LNG supply, but the IEA reports that new North American and African supply, plus better feedgas availability from legacy producers, offset about three-quarters of the decline between March and June. The global market had more slack than the headline implied — which caps how hard the export arbitrage can pull on US prices.

What would make this call wrong?

A weekly Henry Hub close above $3.60; WTI back below $70 on a de-escalation, which removes the supply impulse; Lower 48 production falling below 115 Bcf/d; or storage dropping below the five-year average before September.

This article is informational analysis only and is not financial, investment, or trading advice. Foreign-exchange, commodity, and equity markets are highly volatile and can lose substantial value rapidly. Leveraged products carry total-loss risk and may exceed the initial margin posted. Past performance and historical correlations do not guarantee future results. Do your own research and consult a regulated financial adviser before making any investment decision.