Wholesale electricity markets across Europe saw sharp price pressure in the third week of April, with the highest daily levels appearing early in the period. Prices then eased gradually through the week, but weekly averages still finished higher than in the prior week. For grid planners and renewable developers, the episode matters because it highlights how quickly system economics can shift when generation availability and carbon-linked costs move out of sync.
Weekly averages climb despite mid-week relief
During the week of April 13, weekly average prices were above €95/MWh in most European markets. Spain, Portugal and France stayed below that benchmark, posting €50.38/MWh, €50.73/MWh and €70.93/MWh respectively. Italy recorded the highest weekly average at €123.19/MWh, while the Nordic region and Germany sat at €97.42/MWh and €109.09/MWh.
Market-to-market dispersion was also reflected in week-on-week changes. Italy showed the smallest increase at 2.7%, while France recorded the largest rise at 109%. Across other markets tracked by AleaSoft Energy Forecasting, growth ranged from 21% in Great Britain to 67% in the Nordic market.
Daily extremes point to early-week tightness
On individual trading days, Spain posted the lowest level among the analyzed markets at €23.80/MWh on April 13, with Portugal close behind at €23.88/MWh on the same day. Italy’s lowest daily price during the week came later, reaching €89.39/MWh on April 18—its lowest point since late February. Such swings are relevant for operational scheduling and for battery energy storage dispatch planning, where revenue sensitivity can be tied to intraday price shape.
Most markets also experienced at least one day above €100/MWh, with peaks concentrated early in the week. On April 14, Italy recorded its highest daily average of the period at €150.62/MWh, while the Nordic market reached €111.14/MWh, its highest level since late February.
Drivers: carbon costs, demand strength and weaker wind/solar output
The upward pressure during April 13 was attributed to rising CO₂ allowance prices alongside lower wind generation and higher electricity demand across most markets. Reduced solar output in Germany and Italy added another layer of supply pressure during a period when demand remained firm. For developers preparing engineering studies and EPC readiness work—especially for wind and solar interconnection—these conditions underline why resource variability continues to influence short-term system pricing.
Outlook: expected April easing, but gas price volatility remains a risk factor
AleaSoft Energy Forecasting expects price declines in the fourth week of April, supported by lower demand and higher wind and solar generation across most markets. Even with that outlook, movements in natural gas prices are expected to remain a key factor shaping short-term dynamics across European electricity markets.
For utilities and investors managing CAPEX planning and contracting strategies—whether for transmission upgrades, renewable buildout or battery energy storage systems—the implication is clear: procurement schedules and operational delivery assumptions need to account for carbon-linked cost swings and renewable output variability, while also monitoring gas-driven marginal pricing signals.