Europe faces 10% summer power price surge as heat and gas risk converge

Europe faces 10% summer power price surge as heat and gas risk converge Analysts warn hot, dry conditions combined with gas supply uncertainty could push EU power prices sharply higher through the summer months. European power prices are heading into summer under pressure from two directions: an expected heatwave and persistent uncertainty over gas supply, a combination that analysts told Montel could push prices 10% above current levels before the season ends.³ That matters because European power markets have already been stretched by months of elevated commodity costs, low wind output, and tight margins. A sustained heat episode layered on top of that structural tightness leaves little room for error.⁷ Industry experts who spoke to Montel were unambiguous about the dominant driver: gas. The fuel remains the marginal price-setter across most European markets, meaning any upward pressure on gas — whether from weather-driven demand or supply disruption — transmits directly into power. The experts also flagged El Niño as an amplifying factor, warning that the weather phenomenon raises the probability of the kind of prolonged hot, dry conditions that strain hydro output and push thermal generation higher.² Germany offers a preview of what that strain looks like. During the week of May 18, Germany's available power margin — the buffer between supply capacity and demand — fell to its lowest level of the winter season, according to Bloomberg models cited by OilPrice.com, as wind speeds dropped and cold weather lifted consumption. Wind speeds that week were below seasonal norms, tightening an already stretched system.⁶ The Strait of Hormuz adds a geopolitical layer. Analysts told Montel that if the strait remains closed, it would disrupt energy imports to Europe, compounding what is already a difficult supply picture. A closure severe enough to reroute or reduce LNG flows would test the market's ability to balance through the injection season.³ On the gas side, NYMEX Henry Hub front-month futures settled at $2.96 per million British thermal units as of Friday (2026-05-15), up 2.3% on the day and about 7.4% over the week, as expectations of hotter weather firmed up demand forecasts for US power burn. Weekly LNG vessel departures reached 141 billion cubic feet, up 26 Bcf from the prior week despite maintenance at several export terminals — a signal that export capacity is being pushed despite the operational friction.¹ Higher US gas prices and strong LNG export volumes matter for Europe because the Atlantic arbitrage window determines how much flexible US supply reaches European terminals. If Henry Hub rises far enough to compress the arb, European buyers competing for the same cargoes face a tighter market. For now, European demand has generally managed to outbid Asian buyers, but that advantage is not guaranteed through a hot summer.⁵ The seasonal backdrop is unusual. Montel's EnAppSys analytics head André Bosschaart noted earlier this spring that Europe had spent roughly two months in a period of sub-zero or near-zero power prices — a "season of negatives" driven by high renewables output and weak demand. That phase appears to be ending. The transition from surplus to scarcity can be abrupt when summer heat arrives alongside maintenance outages.⁸ The global context makes European vulnerability harder to hedge away. Asia is already experiencing severe power shortages, with hours-long daily blackouts affecting more than a billion people across Pakistan, Myanmar, Sri Lanka, and India, according to insurancejournal.com. India's power deficits are approaching levels last seen in 2014, when outages were estimated to have reduced GDP by around 5%. The scale of Asian demand destruction — or the capital cost of preventing it — will shape how aggressively Asian buyers compete for LNG cargoes over the summer.⁴ The immediate question for European traders is how quickly temperatures rise and whether gas storage can continue to build through June. Any significant shortfall in injection progress — whether from higher-than-expected power burn or a supply disruption — would arrive at the market when summer demand peaks are still ahead. The 10% price rise analysts flagged to Montel is a forecast, not a floor. If the Hormuz risk materialises alongside a genuine European heatwave, the ceiling is harder to estimate.^3,2