Europe Power
EPEX SPOT / EEX
Electricity for a continent that cannot store it, coupled into one price, set by gas and increasingly turned negative by the sun.
Top Producers
EU27 generation mix, 2024 (Ember). Gas-vs-coal split varies a point or two by source.
Top Consumers
share of EU electricity demand, 2024 (Ember)
Main Uses
EU electricity consumption by sector, approximate (Eurostat)
Top Exporters
indicative share of net cross-border power exports; France (nuclear) and the Nordics (hydro) are the structural exporters. Power is not traded globally, only across interconnectors.
Top Importers
indicative share of net cross-border imports; Italy is the structural importer, with most flows balancing adjacent zones
EU generation
roughly 2,700 to 2,850 TWh
as of 2024
Renewables share
about 47 percent, overtaking fossil (about 29 percent); nuclear about 24 percent
as of 2024
Benchmark price
German baseload day-ahead averaged about 78 EUR/MWh (2024), about 89 (2025)
as of 2025
2022 crisis peak
near or above 1,000 EUR/MWh; French monthly spot about 1,130 (Aug 2022)
as of 2022
Negative-price hours (Germany)
about 457 to 468 in 2024, about 575 in 2025
as of 2025
Europe is the second-largest regional power market on earth after China, but unlike oil, electricity is not a globally traded commodity: it cannot be stored or shipped in bulk, so it moves over interconnectors region by region. A single "European market" exists only because national day-ahead auctions are coupled into one algorithm, Single Day-Ahead Coupling using the Euphemia engine, that routes power to the highest-priced zone up to each interconnector's limit. The EU27 generated roughly 2,700 to 2,850 TWh in 2024. Germany and France together are more than a third of demand: France runs the continent's largest nuclear fleet and is a structural net exporter, while Germany is the largest single market and completed its nuclear phaseout in April 2023, leaving an accelerating coal exit as its remaining fossil question.
The year 2024 was a structural turning point. Renewables reached roughly 47 percent of EU generation while fossil fuels fell to a record-low share near 29 percent, and solar overtook coal for the first time. That build-out reshaped how prices behave. After the 2022 energy crisis, when Russia's gas cutoff collided with a near-collapse of French nuclear output from stress-corrosion cracking and drove German and French calendar baseload toward or above 1,000 euros per MWh (French monthly spot peaked near 1,130 in August 2022), wholesale prices normalized through 2023 to 2025, with German calendar baseload settling roughly in the 70 to 100 euros per MWh range. The flip side of the renewables surge is a structural rise in negative prices: Germany logged roughly 457 to 468 hours of negative day-ahead prices in 2024, up from about 300 in 2023, and around 575 in 2025, as solar and wind flood the grid on sunny, windy, low-demand hours.
Trading splits by function across three venues. EPEX SPOT (Paris and Amsterdam) and Nord Pool run the physical day-ahead and intraday auctions; EEX in Leipzig is the dominant derivatives venue, listing German, French, Italian, and Spanish power futures in baseload and peakload shapes. The German baseload calendar-year future, cash-settled against the German day-ahead auction, is the de facto European benchmark. Because gas usually sets the marginal price through the merit order, European power and the Europe TTF gas price move together, with EU carbon allowances, weather, French nuclear availability, and Nordic and Alpine hydro levels as the main secondary drivers.
How It Trades
| Venue | EPEX SPOT and Nord Pool (physical spot); EEX (derivatives); national auctions coupled via SDAC/Euphemia |
| Benchmark contract | German baseload calendar-year future (EEX), cash-settled to the German day-ahead auction; baseload and peakload shapes, monthly through yearly |
| Contract size | Quoted in euros per MWh; a baseload future delivers 1 MW around the clock across the period |
| Price terms | Euros per MWh |
| Settlement | Cash-settled against the EPEX SPOT German day-ahead auction average; the physical spot clears hourly, and increasingly in 15-minute units, in each bidding zone |
| Typical curve | Double-peaked winter and summer seasonality over a steep daily shape: midday solar can push spot negative while the evening ramp spikes; calendar futures stay liquid two to three years out |
| Liquidity | EEX is the dominant power-derivatives venue and the German baseload future is the European benchmark; EPEX SPOT and Nord Pool run the physical auctions. Liquidity thins beyond a few years, so long-dated renewable deals are done as bespoke PPAs. |
Where It Trades
approximate split of European power trading, 2025; power is regional and cleared by bidding zone, not a single global market
Supply and Demand
Top producers
- Nuclear (roughly 24 percent, dominated by France, the continent's big net exporter)
- Wind (roughly 17 percent and rising, onshore plus growing offshore)
- Gas (roughly 16 percent, usually the marginal price setter via the merit order)
- Hydro (roughly 13 percent, concentrated in the Nordics and the Alps)
- Solar (roughly 11 percent; overtook coal for the first time in 2024)
- Coal and lignite (roughly 10 percent and falling to record lows)
Germany completed its nuclear phaseout in April 2023; France is rebuilding nuclear output after the 2022 corrosion outages. The fossil share fell to a record low near 29 percent in 2024 as renewables passed 47 percent.
Top consumers
- Germany (roughly 19 percent of EU demand, the largest market)
- France (roughly 17 percent, the large nuclear net exporter)
- Italy (roughly 12 percent)
- Spain (roughly 10 percent)
- Poland and Sweden (the next tier)
Major uses
- Industry: motors, electrochemistry, process heat
- Households: heating, cooling, appliances
- Services and commercial buildings
- Transport electrification (rail and a growing EV load)
Power is consumed close to where it is made; cross-border flows balance zones up to interconnector limits rather than trading globally.
What Moves the Price
- Natural gas (Europe TTF), usually the marginal price setter through the merit order
- EU carbon (EUA) prices, which lift the clearing price when fossil plants are marginal
- Wind and solar output and weather, including Dunkelflaute (dark, wind-still spells) that spike prices and oversupply that turns them negative
- French nuclear availability, the primary 2022 crisis driver and the 2025 recovery story
- Hydro and reservoir levels in the Nordics and the Alps
- Interconnection capacity and cross-border flows between bidding zones
- Demand with heating and cooling load
Moments That Made the Market
1996
Nord Pool becomes the world's first multinational power exchange (Norway and Sweden), pioneering cross-border power trading.
1990s-2000s
EU electricity directives drive liberalization and the unbundling of generation, transmission, and supply.
2000s-2010s
Spot exchanges (EPEX SPOT, EEX) consolidate and market coupling progressively links national day-ahead markets into one cleared price set.
2022
The Russian gas cutoff plus a French nuclear collapse drive records near or above 1,000 euros per MWh; the EU responds with an inframarginal revenue cap and the Iberian gas-price exception.
April 2023
Germany completes its nuclear phaseout, shutting its last three reactors.
2024
Renewables overtake fossil generation in the EU; solar passes coal for the first time.
2025
French power futures fall to multi-year lows as nuclear output surges; German negative-price hours rise to around 575.
What Changed Since the 2010 Era
- Renewables overtook fossil generation in 2024 (about 47 percent versus 29 percent), and solar passed coal for the first time.
- Negative prices went from a curiosity to a structural feature, with hundreds of negative-price hours a year in Germany.
- The 2022 crisis drove record prices and EU market interventions, after which wholesale prices normalized.
- Germany completed its nuclear phaseout while France's nuclear recovery pulled 2025 futures to multi-year lows.
- Single Day-Ahead Coupling turned national markets into one price-coupled European system.