Europe's gas shock is a heating bill, and the capital that could cut it is going to American power
European gas is trading near €73 per megawatt hour with storage well short of normal. The investable fixes for heat exist, from geothermal to server waste heat, but they only attract money when heat comes attached to an electricity or compute contract.
Europe goes into this winter with gas at roughly three times its January price and storage that would have alarmed ministers in any normal year. The Dutch TTF benchmark was around €73 per megawatt hour this week, having touched almost €84 in the past month and started the year near €27, according to the Commission. Storage was 65.4% full on September 1, against 77.4% a year earlier. Energy ministers meet informally in Dublin on Monday and Tuesday to talk about prices.
Brussels has already named the problem. Dan Jørgensen, the energy commissioner, told the Financial Times on Friday that close to 50 million Europeans face a choice this winter between heating and eating, and that he will tell ministers "you need to act." He warned that far-right parties are feeding on the failure. The same day the Commission confirmed talks with Washington to keep diesel flowing after Trump threatened supplies.
They will mostly talk about electricity, but most of the gas Europe burns in winter heats buildings and runs industrial processes. Capital that could replace it is flowing into electricity projects instead. Power has buyers who sign 15-year contracts. Heat does not. Until heat has one, Europe will keep paying for gas shocks with relief packages instead of pipes and wells.
The stakes are already in the macro data. Eurozone inflation rose to 3.3% in August, with energy up 14.3% on the year, and the German 10-year yield hit its highest since 2011, EU Perspectives reported. The trigger is the Middle East: disruption around the Strait of Hormuz has taken LNG volumes off the market. Prices eased this week after Iranian officials suggested the strait could reopen to commercial traffic within days. That helps the forward curve. It does not refill storage in time for January.
Heating and cooling account for about half of the EU's final energy use, and gas is still the single largest fuel in European buildings. When gas triples in price, the pain arrives through boilers and district heating networks as much as through power bills. Governments know this, which is why every crisis produces a round of household subsidies. In 2022 Europe spent hundreds of billions of euros shielding consumers. Almost none of it bought an asset that would shrink the next bill.
Specialist energy capital shows the problem. EIG, a $27.1 billion energy and infrastructure investor, held the first close of its Geothermal Catalyst Partners fund in April. Its first investment, announced in August, backs Power Planet's enhanced geothermal project at Star Peak in Nevada, which expects to deliver power in 2027 or 2028. EIG's pitch is that oil and gas subsurface skills translate into geothermal. They do. The fund is aimed at US electricity, where a project can sell into a grid, and increasingly to data-centre buyers hungry for firm, clean power.
The same drilling skills pointed at Europe would mostly produce heat. The Paris basin has run geothermal district heating for decades, and Munich has built its heat strategy around deep wells. Those projects exist because municipal utilities own the networks and can carry the risk themselves. A private fund has a harder time. Heat cannot travel far, cannot be traded on an exchange and is usually sold through a local monopoly network at a regulated or politically sensitive price. There is no heat equivalent of a corporate power purchase agreement. Without a creditworthy buyer on a long contract, there is nothing to lend against.
Heata, a small British company, shows the workaround. It fits a compute server to a household hot-water cylinder, sells the processing power to cloud customers and gives the waste heat to the homeowner free. Heata pays for the extra electricity and aims to supply around 80% of a home's hot water, TechRadar reported; it says a household can save up to £340 a year. It only works with older vented cylinders, which limits the market, but Britain's ban on gas boilers in new homes from 2027 gives the model a tailwind. British Gas signed an agreement with Heata in July to test whether homes can host a distributed computing platform. The company is still at the stage of a handful of beta testers, so its scale is trivial. Heata's revenue comes from the compute customer. The heat is the byproduct it gives away. It found a way to fund heat by attaching it to something with a contractible buyer.
The argument against a separate heat market is that Europe plans to electrify heat with heat pumps, so money going into power is money going into heat. That may work over twenty years. Over the next five, it breaks down. Heat pumps move winter demand onto the electricity grid at exactly the hours when gas-fired plants set the marginal price, so a gas shock still feeds into the bill. Geothermal and recovered waste heat displace gas directly, with no winter-peak effect and no new strain on congested grids. Europe needs both, and at present it only knows how to finance one.
The policy groundwork is half there. Germany's heat planning law required large cities to publish municipal heat plans by the middle of this year, with smaller towns following by 2028. That creates a map of demand. It does not create a buyer willing to sign for 20 years. The missing instrument is a contract-for-difference for heat, or a state-backed offtake that lets district-heating operators commit to geothermal and industrial waste-heat suppliers on terms a lender can accept. European governments already run that machinery for offshore wind.
The Dublin meeting will not produce it. The agenda is dominated by affordability, and France and 17 other member states want to push back the methane regulation by a year, a request the Commission is reported to be open to. Expect ministers to leave with emergency relief principles and a softer methane timetable, not a financing tool for heat.
The desk expects TTF to stay above €60 per megawatt hour through the winter, even if Hormuz reopens in October, because storage will enter the heating season around 70% to 75% full. The next real chance for a heat offtake scheme is the formal Energy Council in Luxembourg on October 29, and we think it will pass without one. Until that changes, the smartest geothermal money will keep drilling in Nevada.