Natural Gas Futures Price Forecast: Henry Hub Climbs to $3.06 as Qatar LNG Force Majeure and $15 TTF Spread

Henry Hub natural gas futures (NG1!) are trading at $2.99-$3.06 per million British thermal units Friday, up roughly 2% on the session and reaching the highest level since March 23. Meanwhile, the European TTF benchmark sits at $17.68-$18 per mmBtu and the Asian Japan-Korea Marker (JKM) trades at $20.50 per mmBtu. The spread between U.S. gas and European gas is approximately $15 per mmBtu. As recently as January, that spread did not exist in any meaningful form — U.S. Henry Hub was above $7 per mmBtu due to cold weather, European TTF was near $12, and the arbitrage was essentially closed. The Iran war that began February 28 destroyed that equilibrium in a matter of weeks. The Strait of Hormuz closure blocked approximately 20% of global LNG supply. Iranian attacks knocked out 17% of Qatar's LNG export capacity — Qatar being the world's largest LNG producer — causing an estimated $20 billion in lost annual revenue for QatarEnergy, with damage that Raymond James estimates could keep capacity offline for up to five years. Henry Hub barely moved because the United States has ample domestic supply — production runs at 109.3 billion cubic feet per day — while every other benchmark in the world has repriced violently to reflect supply scarcity. The result is the widest sustained U.S.-to-global LNG price gap in modern market history, and it is not narrowing.

Qatar Force Majeure Changes Everything — 17% of Global LNG Supply Is Gone for Years

The catastrophic development that separates the current LNG crisis from prior geopolitical disruptions is Qatar's force majeure declaration on all of its LNG output. QatarEnergy's CEO confirmed to Reuters that Iranian attacks have removed 17% of Qatar's export capacity. Qatar produces approximately 77 million tonnes of LNG annually — 17% of that figure represents roughly 13 million tonnes of annual production capacity offline. The damage is not a temporary disruption requiring weeks to repair. It is structural damage to critical infrastructure that Raymond James has assessed as requiring up to five years for full restoration. Shell's Pearl gas-to-liquids facility in Qatar — a 140,000 barrel per day operation — had its 70,000 barrel per day Train 2 knocked offline with a confirmed one-year repair timeline. The global LNG market had already been strained by the Strait of Hormuz closure restricting transit flows. The Qatari production damage adds a supply destruction layer on top of the transit disruption layer — two simultaneous shocks hitting the same commodity supply chain. Japan, South Korea, and Taiwan receive approximately 85% of their LNG supplies through routes passing the Strait of Hormuz. Bank of America flagged these economies as critically exposed. Japan has already announced plans to increase coal use in power generation to compensate for LNG unavailability. China's LNG imports are on track for their lowest monthly reading since 2018 — below 3.7 million tonnes in March, a 25% year-over-year decline — as high prices and Qatari supply disruption eliminate buying interest. TotalEnergies CEO Patrick Pouyanné warned directly that European TTF prices could hit $40 per mmBtu over the summer if the conflict persists, as Asian demand rises seasonally while Europe simultaneously tries to refill storage.

The Bullish Inventory Report: 54 Bcf Draw vs. 44 Bcf Expected — Storage Math Is Tightening

The U.S. Energy Information Administration's weekly storage report released Thursday provided the near-term technical catalyst that pushed NG1! higher Friday. The actual draw for the week ended March 20 came in at 54 billion cubic feet — significantly above the 44 bcf analyst consensus expectation and dramatically above the 33 bcf injection recorded in the same week a year ago. Total U.S. gas in storage stands at 1,829 billion cubic feet, which is 0.8% above the five-year average. Current storage versus the five-year average has improved to +2.0% as of March 27. The forecast for the current week is a modest build of 18 bcf, but the directional trend matters more than any single week's number. The 54 bcf draw versus the 33 bcf injection a year ago is a 87 bcf year-over-year swing in a single week — reflecting the combination of higher U.S. LNG export feedgas demand (18.8 bcfd currently versus 16.1 bcfd a year ago) and weather-driven domestic consumption increases. LNG export feedgas running at 18.8 bcfd represents near-maximum utilization of existing U.S. LNG export terminal capacity — every molecule of American gas that can be liquefied and shipped abroad is being chilled and loaded right now, because the $15 spread makes it extraordinarily profitable.

The Technical Structure: Triangle Formation With Resistance at $3.136-$3.157

NG1! is forming a triangle chart pattern on the near-term timeframe with resistance concentrated at $3.136-$3.157 — the breakout trigger zone that would confirm bullish momentum and open a path toward higher targets. The April contract expires Friday, creating settlement-day volatility that is amplifying the upside move as traders roll into May. The May contract is being watched with resistance at $3.02 already being tested, with a break through that level targeting the next consolidation area near $3.09, while support is found just above $2.90, according to Tradition Energy's Gary Cunningham. The front-month April contract rose 5.6 cents or about 2% to $3.06 on Friday — the highest since March 23 — on a combination of settlement positioning, weather outlook revisions favoring cooler temperatures beyond next week, and the broader market reaction to war risk signals. The bears have a competing technical case: the Economies.com analysis places the key barrier at $3.450, below which bearish momentum is expected to drive prices toward $2.810, with the key support at $2.620 representing the critical level for the main trend. The expected daily range sits at $2.810-$3.150. The two frameworks — bullish breakout above $3.136 and bearish continuation toward $2.810 — reflect the genuine uncertainty about whether the domestic Henry Hub price can remain anchored near $3 while global benchmarks trade at six times that level.

The Negative Waha Hub Price Is the Most Bizarre Signal in Any Energy Market

The most extraordinary data point in the entire U.S. natural gas price picture is the Waha Hub spot price — currently at negative $2.61 per mmBtu. Negative gas prices mean producers in the Permian Basin of West Texas are literally paying buyers to take their gas away, because the regional pipeline infrastructure cannot move the supply fast enough and producers would rather pay disposal fees than shut in their oil production, which generates associated gas as a byproduct. The prior day Waha was -$3.06. A year ago Waha was $0.78. This extreme regional basis differential — negative $2.61 at Waha versus positive $2.99 at Henry Hub versus positive $17.68 at TTF — is a function of Permian pipeline capacity constraints that have persisted for years. The strategic implication is significant: the U.S. has gas that is literally worth less than zero in one region while Europe is paying $18 for the same molecule. The infrastructure buildout required to connect Permian production to Gulf Coast LNG export terminals would unlock enormous value — but it takes years and billions of dollars, neither of which can be deployed instantaneously to respond to the current crisis.

The LNG Arbitrage Golden Ticket: Venture Global's $6 Billion Revenue Upside

The commercial winner from the Henry Hub-TTF spread is precisely identified by Reuters Breakingviews: Venture Global (VG), up over 80% since the start of March. The arithmetic is stark. If the TTF-Henry Hub spread, after associated shipping, insurance, and regasification costs, holds around $10 per mmBtu net, Venture Global would generate approximately $6 billion in extra revenue from deploying its uncontracted 2026 production — approximately 11 million tonnes out of 35 million total tons — at spot market prices. That $6 billion compares to a total 2025 top line of $14 billion. The critical distinction between Venture Global and other LNG companies like Shell (SHEL), TotalEnergies (TTE), and BP (BP) — which all have offtake agreements providing access to millions of metric tons of cheap U.S. LNG — is that only 69% of Venture Global's 2026 production has been pre-contracted at lower pre-war prices. The remaining 31% is free to be deployed at the current spot market arbitrage, and because Venture Global doesn't pay the tolling charge to itself (unlike offtakers who pay the tolling cost on top of the gas price), its effective spread is even wider than Shell's or TotalEnergies'. UBS analysts estimate that every $1 per mmBtu widening in the TTF-Henry Hub spread adds approximately $600 million to Venture Global's EBITDA. TotalEnergies' Pouyanné warning of TTF at $40 per mmBtu over summer implies a spread expansion that would add multiple billions to Venture Global's EBITDA relative to current expectations. The Plaquemines commissioning phase risk — historical legal battles with European customers over timing — has been partially mitigated by the March 26 Edison dispute settlement, and Venture Global has confirmed Phase One remains on target for Q4 2026 commercial operation date.

Maintenance Season May Get Cancelled — The Qatar Damage Creates Multi-Year LNG Tightness

A growing concern flagged by Tradition Energy's Gary Cunningham is that the combination of prolonged Qatari LNG supply interruption and Hormuz disruption may force U.S. LNG facilities to forego their scheduled spring maintenance programs. LNG liquefaction trains typically undergo several weeks of maintenance during the spring shoulder season when both heating demand and cooling demand are relatively low. In the current environment, where European storage refill needs are competing with elevated Asian demand and 17% of Qatar's export capacity is offline for potentially years, the economic incentive to keep U.S. facilities running without interruption is overwhelming. A decision to cancel or defer spring maintenance by U.S. LNG operators would boost near-term LNG export feedgas demand — currently at 18.8 bcfd — even higher, and would incrementally support Henry Hub prices through increased domestic demand for the gas that feeds the export terminals. It would also increase the longer-term risk of unplanned outages, but in a market trading at $15 spread between U.S. and European prices, the incentive to run flat out is dominant.

U.S. Power Generation Mix Is Shifting — Natural Gas at 34%, Wind at 16%

The domestic U.S. power generation data for the week ended March 27 shows natural gas at 34% of the generation mix — down from 35% the prior week and down from the 40-42% range in 2024-2025. The decline in gas's power generation share is not demand destruction — it is fuel switching driven by weather and the availability of renewables. Wind reached 16% of generation this week (up from 15% the prior week and significantly above the 10-11% levels seen in 2023-2024), while solar contributed 9% (up from 5-6% in prior years). Renewable penetration growth is incrementally reducing natural gas's domestic power burn — but total U.S. demand at 109.9 bcfd this week and projected at 109.9 bcfd next week is essentially flat. The residential and commercial sectors are consuming 12.8 bcfd and 9.3 bcfd respectively — numbers that would increase materially if the cooler temperature forecast beyond next week that Ritterbusch flagged materializes. The combination of April contract expiry positioning, weather outlook revisions toward cooler temperatures, and war risk premium keeps the near-term upside bias alive despite the technical uncertainty around the $3.136-$3.157 breakout zone.

The Positioning Verdict: Henry Hub Is a Buy on Dips, LNG Infrastructure Stocks Are the Bigger Trade

Henry Hub natural gas is a buy on any dip toward the $2.810-$2.900 support zone. The structural backdrop — 17% of global LNG capacity offline due to Qatar damage, Hormuz restricting transit of 20% of global LNG supply, spring maintenance potentially deferred at U.S. export terminals, TTF at $18 with Pouyanné warning of $40, storage draws running 25% above consensus, and LNG export feedgas at 18.8 bcfd near maximum utilization — creates a floor under Henry Hub that did not exist three months ago. Every U.S. molecule that can be exported is being exported because the $15 spread makes it the highest-returning trade in the energy complex. The $3.136-$3.157 breakout level is the near-term trigger — a confirmed close above it shifts the technical bias from range-bound to bullish and opens the path toward $3.50 and potentially $4.00 if TTF approaches Pouyanné's $40 target. The United States Natural Gas Fund (UNG) at $11.84, down 42% from its 52-week high of $22.12, represents a compressed entry point on the same thesis through a listed vehicle. The bigger trade, however, is in LNG infrastructure: Venture Global (VG) up 80% this month is the clearest expression of the arbitrage thesis, and Shell, TotalEnergies, and BP with locked-in offtake agreements are structurally positioned to generate extraordinary margins for as long as this spread persists. The bear case — a ceasefire that reopens Hormuz, restores Qatar output, and drops Brent below $80 — would collapse the spread and reverse every one of these trades rapidly. That scenario is possible but not the near-term base case given Friday's peace talk evidence.