Day-ahead electricity prices in Southeast Europe were corrected sharply for delivery on 18 July 2026 amid lower weekend demand and strong daytime renewable production. Hungary fell 32% to €106.14/MWh, while Romania declined 29% to €110.21/MWh. Bulgaria dropped 31% to €101.31/MWh and Serbia eased 29% to €101.27/MWh. Slovenia settled at approximately €113.10/MWh, about 25% below the preceding session.
Weekend averages fall as solar-period prices stay low
The lower regional averages were accompanied by a wide separation between daytime and evening pricing. The combination of very cheap solar-period electricity and expensive evening hours shaped the session outcomes. In Romania, the 15-minute market ranged from €3.94/MWh to €288.93/MWh, producing an intraday spread of almost €285/MWh. Hungary moved from €1.29/MWh around midday to €205.86/MWh in the evening.
Slovenia showed a similar pattern, with prices ranging between €4.52/MWh and €199.58/MWh. Romania’s intraday range included a maximum value of €288.93/MWh alongside a minimum of €3.94/MWh within the same market window. The pricing profile indicated that generation value shifted quickly away from the solar production period rather than remaining uniformly lower across all hours.
Intraday spreads in Romania, Hungary and Slovenia
Bulgaria followed the same overall shape, with electricity falling to €8.16/MWh at midday before reaching €187.48/MWh at 19:00. Its most expensive hour was approximately 23 times the cheapest hour during the session. Hungary’s midday-to-evening movement reflected a shift from near-minimum levels to substantially higher prices later in the day.
Slovenia’s range also highlighted the contrast between low daytime pricing and higher evening levels, with a low of €4.52/MWh and a high of €199.58/MWh. The session dynamics were reflected across multiple markets rather than being confined to a single trading interval or country.
Implications for solar capture, flexibility and tariff design
The commercial impact varies by technology as prices move away from solar generation hours. Standalone solar plants without storage face increasing captured-price erosion even when daily baseload remains above €100/MWh. Batteries, pumped-storage plants and flexible hydropower can buy or retain energy during the midday trough and sell it after solar generation declines.
Industrial demand response and electric-vehicle charging can capture part of the same value without building a generation asset . The volatility also supports arguments for shorter settlement periods and dynamic tariffs, given that consumers on flat retail prices have limited incentive to shift demand relative to real-time conditions . Generators settled against daily or monthly reference prices may not receive payment aligned with the true value of their production profile under these intraday spreads.
Regulators designing renewable premiums and network tariffs will increasingly need to preserve the price signal created by intraday spreads, particularly when weekend patterns combine low daytime prices with high evening scarcity pricing . This requirement links tariff structures to how market participants experience hourly price movements across delivery days.
