Negative electricity prices in Europe: why they happen, where and how often

A few years ago a negative electricity price was a curiosity. Today it is a routine feature of sunny spring weekends across much of Europe: for some hours, generators effectively pay to keep feeding power into the grid. This article explains why that happens, how often it now occurs, and what it means for households on dynamic tariffs and for owners of rooftop solar.

Why a price can fall below zero

The day-ahead market sets one price for each bidding zone and each time slot by matching supply and demand bids. Normally the last power station needed to cover demand sets that price. Prices turn negative when there is more power on offer than buyers want, and a large part of that supply would rather keep running than switch off.

There are three usual reasons. First, weather-driven surpluses: on a sunny, breezy Sunday in May, solar and wind output can exceed demand in several neighbouring countries at once. Second, inflexible plants: some nuclear, lignite and combined heat-and-power units cannot ramp down quickly or cheaply, so they bid below zero to stay online. Third, subsidy design: older renewable support schemes pay a fixed tariff per kWh regardless of the market price, so many small solar systems keep exporting even when the market is oversupplied.

Interconnectors normally soak up local surpluses by exporting them, but when neighbouring zones are in the same situation there is nowhere for the power to go. That is why negative hours tend to appear across large parts of the continent at the same time.

How often it happens: country examples

The trend is clearly upwards. Germany’s regulator, the Bundesnetzagentur, counted 457 hours with negative day-ahead prices in 2024 and 573 hours in 2025, roughly 6.5% of the year. France’s grid operator RTE reported 361 negative hours in 2024, more than double the 147 hours of 2023.

Spain only recorded its first-ever negative day-ahead price on 1 April 2024, at a symbolic −0.01 €/MWh. A year and a half later it had become one of Europe’s most affected markets. According to a pv magazine analysis of 2025 data up to the end of October, the Netherlands had 584 negative hours, Germany 576, Spain 569, Belgium 519 and France 513, while Finland and both Danish zones each exceeded 400.

The pattern differs by region. In Germany, the Netherlands and Spain the negative hours cluster around midday from April to August, driven by solar. In Finland and Denmark they are more often caused by strong wind at night or at weekends, and can occur in any season. You can see which sources are running in a given hour on the generation pages, for example electricity generation in Germany or Finland.

Who benefits from negative prices

Households only see negative prices directly if they have a dynamic (spot-price) contract that passes the hourly or quarter-hourly market price through. Even then, the final price per kWh rarely drops below zero, because network charges, levies and VAT are added on top. What the customer gets is a very cheap slot rather than a payment.

A simple example: suppose the day-ahead price at 13:00 is −20 €/MWh, i.e. −2 cents per kWh, and your network charges and taxes add 15 cents per kWh. You pay about 13 cents per kWh in that hour. Running a 2 kW dishwasher cycle and charging a car with 20 kWh then costs roughly 22 kWh × 0.13 € = 2.86 €, against about 6–7 € on an evening where the market price is 15 cents per kWh. The benefit is real, but it comes from shifting usage, not from being paid to consume.

Other winners are electricity storage, heat pumps with buffer tanks and industrial users who can increase demand at short notice. The losers are generators that must keep running, and, indirectly, taxpayers in countries where subsidies keep flowing during negative hours.

What it means for rooftop solar owners

For solar owners, negative hours are the reverse of good news. In Germany, systems commissioned after 25 February 2025 under the so-called Solarspitzengesetz receive no feed-in payment for any quarter-hour with a negative price; the lost periods are added to the end of the 20-year support period. New systems without a smart meter must also cap their grid export at 60% of installed capacity until one is fitted.

Elsewhere the rules vary. In the Netherlands, the generous net-metering scheme is being phased out and many suppliers already charge a fee for exported power. In Spain, self-consumption surplus is typically valued at the hourly market price, so midday exports are often worth close to nothing. The practical conclusion is the same everywhere: power you use yourself at midday is worth far more than power you export.

Practical tips

• Check tomorrow’s prices in the afternoon: day-ahead results for your zone are published around midday, for example on the Germany, Netherlands, Spain or France price pages.
• Schedule flexible loads (EV charging, washing machine, hot water) into negative or near-zero hours if you are on a dynamic tariff.
• If you own solar panels, prioritise self-consumption and consider a battery or a heat pump timer rather than exporting at midday.
• Expect the effect to be strongest from April to August around midday, and on public holidays and weekends when demand is low.

Negative prices are also a reason why interconnectors matter: more cross-border capacity spreads surpluses over a wider area. We explain how in interconnectors and electricity prices.

Frequently asked questions

Sources

• Bundesnetzagentur – 2025 electricity market data (SMARD)
• RTE – Bilan électrique 2024: prices
• AleaSoft – Spanish market registers negative prices for the first time
• pv magazine – Europe faces surge in negative power prices (Nov 2025)
• RatedPower – Solarspitzengesetz and negative pricing

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