Europe power bills rise by €120 due to gas, IEEFA says — NRG-IA

Europe’s structural exposure to gas generation — what happened European electricity consumers risk paying up to €120 more per year on their utility bills, according to a newly released report by the Institute for Energy Economics and Financial Analysis (IEEFA). The analysis published on June 9, 2026, demonstrates that continued exposure to gas-fired power generation keeps electricity prices elevated and highly volatile across the continent. Although the European Union has accelerated its transition toward renewable energy, natural gas remains the marginal fuel that sets the market clearing price during most trading hours. This structural vulnerability directly impacts both the financial stability of households and the competitiveness of European industries. IEEFA experts stress that, despite temporary price drops recorded after the peak of the energy crisis, power generation costs remain well above historical averages seen before 2021. The heavy reliance on liquefied natural gas (LNG) imports acts as an anchor pulling retail tariffs upward. The report highlights that decarbonization efforts are not fast enough to shield consumers from the fluctuations of the global gas market. While wind and solar capacities break generation records during sunny and windy days, the lack of utility-scale storage solutions forces national grid operators to fire up gas plants to cover peak demand hours. Massive LNG imports and global market exposure Replacing Russian pipeline gas with imported liquefied natural gas, primarily sourced from the United States, has established a new commercial and geopolitical dynamic with high embedded costs. A previous IEEFA report, published on August 4, 2025, had already detailed how massive U.S. LNG exports directly influence domestic power prices in America while inflating acquisition costs for European partners. Maritime transport, liquefaction, and regasification processes add significant fixed costs that cannot be eliminated from the final fuel price. This tight correlation means that European gas prices are now directly influenced by Asian demand, weather conditions in the Northern Hemisphere, and technical incidents at American export facilities. Any unscheduled shutdown of a liquefaction plant in Texas or Louisiana instantly translates into higher megawatt-hour prices on European exchanges, such as the Dutch TTF hub. Furthermore, the long-term contracts signed by European companies to secure LNG volumes often feature rigid destination clauses and pricing formulas indexed to volatile benchmarks. This contractual rigidity limits the flexibility of member states to negotiate better terms during periods of global oversupply. The marginal pricing mechanism and direct bill impact The European electricity market operates on a marginal pricing model (merit order), where the last production unit needed to meet demand sets the market price for all generators. Because gas-fired power plants carry the highest variable operating costs, they are frequently the ones setting the market-clearing price. This mechanism causes gas price spikes to reflect disproportionately in final electricity prices, even when the share of gas in the total energy mix is low. For an average household in Europe, this market dynamic translates into an estimated increase of up to €120 annually on their electricity bill, according to IEEFA projections. The impact is felt differently depending on each member state's national energy mix, but highly interconnected European markets mean that high prices propagate rapidly even to regions with significant renewable or nuclear generation. European heavy industry, which competes directly with manufacturers in regions with cheaper energy resources, such as the US or the Middle East, is critically affected. High electricity costs compress profit margins, forcing some companies to curtail production or relocate operations, thereby accelerating the risk of continental deindustrialization. Accelerated transition and the risk of stranded assets The European Union's strategic decision to phase out fossil fuels faces the technical reality of transmission and distribution grids. Before the end of this decade, member states must massively accelerate the deployment of battery storage and expand cross-border interconnectors to minimize the need for gas plants as system reserves during peak hours. The primary risk in the short and medium term is the emergence of stranded assets. Massive investments made in recent years in new LNG regasification terminals and pipeline interconnectors risk becoming unprofitable as gas demand declines in line with the EU's 2030 and 2050 climate targets. The amortization costs of this large-scale infrastructure will likely be passed on to consumers through network tariffs. Additionally, regulatory uncertainty surrounding the European carbon market (ETS) adds an extra cost layer to gas-fired generation. Without deep structural reforms to decouple electricity prices…