Natural Gas Price Forecast: Henry Hub($2.825) Fades Seasonally; Europe Confronts a €100B Import Shock

Natural Gas (NG/F) is trading at $2.825 on April 1, 2026, down 2.05% on the session. UK natural gas futures dropped to approximately 123 pence per therm, retreating from a more than three-year high of 156.6 pence recorded in March. The U.S. Henry Hub market is behaving like a domestic seasonal trade: spring has arrived, temperatures are warming, residential heating demand is collapsing, and the market is mechanically gravitating toward the floor. The 50-day EMA sits at approximately $3.25, and the $3.00 psychological level caps any meaningful rally attempt. The $2.75 level is functioning as the technical floor, with the market bouncing off it repeatedly without any sustained conviction in either direction. On a pure domestic U.S. seasonal basis, the natural gas trade is a fade — sell rallies toward $3.00, take intraday shorts at signs of exhaustion, avoid chasing moves. That is the U.S. picture. The European and global picture is entirely different, and the divergence between U.S. Henry Hub's sleepy seasonal pattern and the structural LNG supply crisis playing out globally is the most important gap in the current energy market.

UK Natural Gas at 123p Has Retreated 21% From Its 156.6 Three-Year High — But the Structural Problems Haven't Resolved

UK natural gas futures at 123 pence per therm represent a 21% decline from the 156.6 three-year high set in March, driven almost entirely by Trump's statement that U.S. forces will leave Iran in two to three weeks. The market is pricing de-escalation hope rather than supply resolution. On Bulgaria's IBEX power exchange, the day-ahead electricity price for April 2 reached €136.6 per MWh — compared to €67.5 per MWh on February 27, just before the conflict began. That is a 102% increase in day-ahead electricity prices in a single month. Bulgaria has become the first EU member state to introduce financial compensation for energy-intensive industries, covering up to 50% of the electricity price above the €63 per MWh threshold, with the measure being implemented retroactively from July 1, 2025. Energy-intensive industries generate 26% of Bulgaria's GDP — the government is not subsidizing a marginal sector. It is defending its industrial base from an energy shock it cannot absorb through market mechanisms alone. Spain's average electricity price for the rest of 2026 is forecast at approximately €66 per MWh — roughly half of Italy's — because Spain has cut the share of hours in which gas sets the electricity price from 75% in 2019 to just 15% in 2026 through rapid wind and solar deployment. Italy, where gas sets the electricity price 90% of the time, is pricing electricity at approximately €130 per MWh. Singapore raised household electricity tariffs 2.1% to 29.72 cents per kWh for Q2 2026, with city gas rising to 23.89 cents per kWh — a relatively modest increase that nonetheless underscores the global reach of a conflict that Singapore's energy infrastructure, 95% dependent on imported natural gas, cannot insulate against.

The EU's €100 Billion Gas Import Bill Addition and the Storage Problem That Must Be Solved by November

The Bruegel analysis of the Iran gas shock on the European Union produces numbers that frame the entire European energy situation for 2026. A doubling of gas prices from the pre-crisis baseline of approximately €30 per MWh to a post-crisis level of approximately €60 per MWh — slightly above current price levels — adds approximately €100 billion to European gas import costs over the next 12 months. The EU spent €117 billion on gas imports in 2025. A sustained increase in oil prices from $60 to $100 per barrel simultaneously adds roughly another €100 billion to the 2026 European oil import bill. The combined energy import shock is therefore potentially approaching €200 billion above 2025 levels — equivalent to roughly 1.1% of EU GDP consumed by higher energy import costs alone. EU gas storage on March 1, 2026, sat below previous years' levels. Reaching the mandated 80% storage target by November will be more difficult and more expensive than in recent years, with the refilling cost ranging from approximately €26 billion at €45 per MWh gas prices to €35 billion at €60 per MWh to €44 billion at €75 per MWh. The most likely scenario at current pricing sits around the €35 billion refilling cost — approximately 55% higher than the 2025 refilling season cost. Rapid refilling over the coming months could push prices higher because summer refilling activity accounts for a significant share of European gas demand, creating a temporary demand surge that conflicts with the need to keep prices manageable.

Qatar Supplies Only 8% of EU LNG Imports — But Global Market Tightness Hits Every European Buyer

The mechanism through which the Strait of Hormuz closure reaches European natural gas prices is indirect but powerful. Qatar provides approximately 8% of EU LNG imports and 4% of total EU gas imports — a relatively small direct share. Qatar accounted for approximately one-third of Italy's LNG imports in 2025, a quarter of Belgium's, and nearly a fifth of Poland's — meaning the countries most exposed to Qatari supply disruption are EU member states with significant manufacturing and heating demand. But the transmission channel is global market tightening rather than direct supply loss. With Qatar's export capacity reduced by the conflict, Asian LNG buyers — who source nearly a third of their LNG from the Gulf — are now competing with European buyers for flexible cargoes from the United States and other non-Gulf sources. Multiple LNG tankers have already been diverted from Europe to Asia since the start of the Iran war. U.S. LNG, which previously accounted for approximately two-thirds of EU LNG imports, is now subject to Asian bidding that Europe must match or lose. The critical constraint: the EU has limited alternative diversification options. Australia's LNG has historically been directed to Asian markets. New export capacity primarily from the U.S. and Canada is insufficient to replace lost Qatari volumes fully. Pipeline alternatives from neighboring countries are limited. The EU is in a competitive bidding situation for a shrinking pool of flexible LNG with buyers who have deeper pockets or more urgent supply needs.

EU Coal Demand Is Rising — the Fuel Switching That Nobody Wanted Is Happening Anyway

The EU's coal-fired power plants had unused generation potential of 568 terawatt hours in 2024. As gas prices rose through March, generating electricity with coal became progressively more economically attractive, and coal-fired generation has been increasing across the EU since early March. EU coal demand rose 10% in the first half of 2022 during the Russia energy crisis — the current shock is producing the same behavioral response. Germany, Poland, the Netherlands, and the Czech Republic are all turning toward coal as an alternative amid the gas crisis, which is driving up global coal prices as demand accelerates simultaneously in Asia and Europe. The natural gas price signal is doing exactly what price signals are supposed to do — driving fuel switching away from the more expensive commodity — but the environmental cost of that switching conflicts with the EU's decarbonization trajectory. Spain provides the counterfactual: by reducing the share of hours where gas sets the electricity price from 75% to 15% through renewable deployment, Spain has insulated itself from the worst of the shock. Countries that did not make that transition are paying the full price.

The Russian Gas Temptation and Why the EU Must Refuse It

The energy price shock has revived discussions about whether the EU should reopen Russian pipeline gas or LNG imports to ease the supply crunch. The EU spent three years and substantial political capital diversifying away from Russian gas after the 2022 invasion of Ukraine, reducing Russian gas dependence from approximately 45% of imports to near zero. Reversing that — even partially or temporarily — would recreate the dependency that cost Europe hundreds of billions of euros in the 2022 energy crisis and provided Russia with direct leverage over European foreign and economic policy. The EU has confirmed it will end Russian spot LNG purchases in April 2026 and terminate long-term contracts by January 2027, with energy officials explicitly stating there will be no backtrack. Beyond the geopolitical leverage problem, any uncertainty about potential Russian gas return would undermine clean-energy investment by reducing the risk premium that makes renewable energy economically superior to continued fossil dependency. The discipline required to hold that position through a €100 billion energy import shock is considerable, but the long-term cost of abandoning it is higher.

U.S. Henry Hub at $2.825: Why the Domestic Seasonal Trade and the Global LNG Export Story Are Diverging

The most analytically interesting dynamic in the current natural gas market is the divergence between the U.S. Henry Hub price at $2.825 — approaching a seasonal floor as spring warming reduces heating demand — and the global LNG premium that the Qatar supply disruption has created for buyers worldwide. U.S. natural gas producers are the marginal supplier to the global LNG market, and the Iran conflict has dramatically increased the demand for U.S. LNG exports. But the build-out of additional LNG export capacity is not instantaneous. Existing U.S. LNG export facilities are operating at or near full utilization. The increased Asian demand for U.S. LNG is competing with European buyers for the same fixed export capacity. New U.S. and Canadian LNG export capacity that would resolve the supply bottleneck is measured in years, not months. The domestic Henry Hub price at $2.825 reflects the seasonal reality that U.S. producers are generating supply that exceeds domestic demand as spring reduces heating needs. The export premium — the difference between Henry Hub and Asian LNG spot prices — is at historically wide levels, which is exactly what attracts capital toward LNG export infrastructure but cannot resolve the immediate supply shortage. U.S. natural gas is cheap domestically and expensive globally, and the bottleneck is the finite liquefaction capacity that converts it from a domestic commodity into an internationally tradable one.