European Power Prices Fall for a Third Straight Week as August Heatwave Spike Unwinds

European wholesale electricity markets are cooling from one of the sharpest short-term price spikes in years, according to the latest edition of Epignosis Insights' 

Europe Electricity Wholesale Price Tracker, a weekly market intelligence report covering five major day-ahead baseload benchmarks. Germany, France, Italy, Spain and the Southeast European bloc — spanning Serbia, Hungary, Bulgaria, Romania, Greece, Croatia and Slovenia — all recorded their third consecutive week of price declines in the week ending August 24, 2026, as an exceptional early-August heatwave that pushed Italian spot prices and German front-month contracts to their highest levels in three and a half years continues to unwind.

Germany's EPEX day-ahead baseload benchmark has eased from a heatwave peak of €129 per megawatt-hour in the week of August 3 to €91/MWh. Italy's PUN — structurally the most expensive of the five markets tracked, owing to its heavier reliance on gas-fired marginal generation — has fallen from €178/MWh to €121/MWh over the same three weeks, while still trading well above Germany and France on an absolute basis.

A Heatwave That Cut Supply and Spiked Demand at Once

The dominant driver of the spike was a severe heatwave that simultaneously cut generation and boosted demand across the continent. On August 4, French utility EDF cut output from roughly 12 percent of the country's nuclear fleet because of heat-related cooling constraints, extending a forced outage at one of its reactors. That single operational fact cascaded into a continent-wide story: Italian spot power prices and German front-month power contracts both hit their highest levels in three and a half years on the same day, while southeastern European countries moved toward formal demand rationing.

Southeast Europe experienced the most extreme price dislocation of the period. Across seven regional power exchanges, day-ahead prices during the August 3–4 peak rose to between roughly €598 and €715 per megawatt-hour in the evening hours, compared with pre-heatwave weekly averages generally in the €75-to-€90 range.

Clean Power Cushioned the Worst of the Gas Shock

Not every price signal this year has pointed the same direction. Between February and March 2026, the EU average day-ahead electricity price actually fell 9 percent even as benchmark European gas prices rose 60 percent following the outbreak of conflict in the Middle East, a divergence industry data attributes to strong spring renewable output, including a monthly solar generation record of 48 terawatt-hours. That resilience has limits, however: average hourly EU electricity prices outside solar hours — before 09:00 and after 18:00 — reached €122/MWh during May and June 2026, compared with €90/MWh in the same period a year earlier, as below-average wind and hydro output combined with nuclear maintenance to increase reliance on more expensive fossil generation.

Utilities Are Capturing the Volatility

Listed European utilities have captured the upside of this volatility in their latest earnings. One major German utility's second-quarter 2026 results showed adjusted earnings per share up more than 60 percent year-on-year, prompting the company to raise its full-year guidance, with leadership noting that a tight winter system with low gas storage and underfilled hydro reservoirs typically favors flexible generation portfolios. A separate German integrated energy company reported first-half adjusted EBITDA nearly doubling year-on-year, even as it flagged lower hydropower inflows and nuclear outages as a drag on its green generation segment.

France and Spain Hold the Widest Discount

France and Spain continued to trade at the largest discount among the five tracked markets, closing the week at €57/MWh and €44/MWh respectively. France's lower-cost position reflects its large nuclear baseload fleet, even after the heatwave-driven curtailments, while Spain's discount is reinforced by strong solar penetration that regularly pushes midday prices down across the Iberian peninsula. Both markets nonetheless tracked the broader continental pattern of a sharp early-August spike followed by three consecutive weeks of easing.

Outlook: A Structural Bifurcation Is Emerging

Epignosis Insights' analysis points to continued easing through September as cooler weather reduces cooling demand and French nuclear availability recovers. But the report also highlights a deeper structural shift: European markets are simultaneously seeing more frequent negative daytime prices, with negative-price hours reaching roughly 6 percent of the year in France, Germany, the Netherlands and Spain in 2025, up from 3 to 5 percent in 2024, as solar additions increasingly outpace midday demand.

"Europe now runs two power markets in one — abundant, cheap-to-free midday solar power alongside expensive, gas-set evening and heatwave pricing. That bifurcation, not the headline average, is what procurement and generation strategy now has to be built around." — Epignosis Insights, Europe Electricity Wholesale Price Tracker, August 2026

About This Report

The Europe Electricity Wholesale Price Tracker is published weekly by Epignosis Insights and synthesizes regional benchmark movements, structural demand and supply drivers, and forward-looking signals drawn from European government and regulatory bodies, an industry association, listed-company disclosures, consulting-firm analysis, and financial and trade news coverage. The full report, including a nine-week regional price trend, week-on-week movement analysis, and a regional heatwave spotlight, is available on request.