Gas Power Margins Remain Compressed as European Thermal Spreads Offer Little Recovery Room
German baseload at €98/MWh and ICE Endex TTF front-month at €41 leave gas-fired generators covering fuel costs but unable to recoup capital.
German baseload power was trading at €98.18 per megawatt-hour on Friday (2026-06-26), while ICE Endex TTF front-month natural gas held at €41.02. At typical combined-cycle efficiency, a €41 gas input translates to variable generation costs in the high €60s per megawatt-hour, leaving a gross margin below €30 before carbon charges and capital expenses are counted.
The spread's significance extends beyond individual plant economics. Gas accounted for 31% of British electricity generation in 2025, compared with just 3% in France, where a large nuclear fleet provides a buffer against gas price volatility, according to analysis published in the Economist on 17 May (2026-05-17).4 That dependence on thermal generation makes power prices across much of the continent acutely sensitive to the margin between gas input cost and power output price.
Britain's power market has demonstrated how quickly that spread can move. Day-ahead electricity prices rose nearly 19% to reach 475 pounds ($656.50) per megawatt-hour on Wednesday (2026-05-13), driven by cold weather coinciding with low wind output and constrained continental interconnection capacity, CNBC reported.3 At those levels, dispatchable generators earn substantial rents. The frequency and duration of such episodes determines annual plant revenue — and scarcity events are, by definition, intermittent.
The renewable expansion underpinning this market structure has accelerated significantly. Renewables generated only 4% of British electricity in 2004; by 2024, that share had exceeded half, according to the same Economist analysis.4 The shift has introduced a growing volume of hours in which wind and solar output pushes marginal prices toward zero, compressing the average price that thermal plants realise across their full dispatch schedule.
Carbon costs add a further layer. The EU Emissions Trading System covers roughly 40% of the bloc's greenhouse gas emissions and charges gas-fired generators for every megawatt-hour they produce, CNBC reported.3 When European gas benchmarks rise, gas plant operators face a dual squeeze: higher fuel costs and no corresponding relief on carbon liabilities, since carbon allowances price independently of gas.
Atlantic LNG flows remain a key variable linking US supply conditions to European gas prices. NYMEX Henry Hub front-month natural gas settled at $2.96 per million British thermal units on Friday (2026-05-15), gaining 2.3% that day and about 7.4% for the week, before recovering to $3.34 on Friday (2026-06-26).2 Weekly LNG vessel departures from US terminals reached 141 billion cubic feet in the week of 2026-05-11, up 26 billion cubic feet from the prior week, despite maintenance activity at several export facilities.2
Underlying US supply conditions add context to that export picture. US working gas in storage added 52 billion cubic feet for the week reported in mid-May, well below the five-year average withdrawal of 168 billion cubic feet, leaving inventories 141 billion cubic feet — roughly 8% — above the year-earlier level, according to EIA data.1 A well-stocked US position limits sustained upward pressure on Henry Hub and, by extension, constrains the LNG floor price that European buyers must clear to attract Atlantic cargoes.1
The unresolved structural issue is market design. Capacity mechanisms, contracts for difference on nuclear output, and long-term power purchase agreements attempt to decouple investment decisions from spot price volatility — but their coverage varies significantly across member states, and Germany lacks a national capacity mechanism.4 Until that structure is clearer, the gap between what spot markets are currently offering and what project developers require to commit capital will persist. Winter will provide the next stress test: heating demand, suppressed renewable output, and storage drawdowns periodically produce the extreme prices that briefly improve the annual economics for gas and nuclear developers alike.3