South East Europe’s electricity market is entering a new phase. The region is no longer defined only by the aftershocks of the 2021–2022 energy crisis, imported gas costs or coal availability. Those factors still matter, but the deeper story is changing. The new structural issue is flexibility.
For years, the main question in South East Europe was whether the region had enough electricity. Today, the more important question is whether the system has the right kind of electricity at the right hour. That distinction is becoming central to prices, investment decisions and security of supply.
The clearest signal came from the summer 2024 price spikes. ACER found that most Southeast European bidding zones experienced significant price increases during that period, particularly in the evening hours, with prices reaching up to €1,000/MWh in some cases. ACER’s conclusion was important: the spikes were not simply a fuel-price event. They were linked to a lack of flexible resources able to replace solar generation after sunset, combined with limited cross-border capacity to import cheaper power from other regions.
That finding changes how the market should be read. South East Europe has strong renewable-resource potential, especially solar. It also has legacy hydro, coal and gas assets that can provide firm supply under certain conditions. But the system is increasingly exposed to the gap between daytime renewable output and evening demand. In other words, the problem is not always total annual generation. It is hourly balance.
This is why average baseload prices are becoming less useful as a market indicator. A market can look adequately supplied on an annual basis and still experience severe price stress in a few evening hours. It can also experience very low or negative midday prices during high solar output, while scarcity pricing appears just a few hours later. For utilities, traders, renewable developers and industrial consumers, the value of electricity is moving from the megawatt-hour alone to the timestamp attached to it.
The price gap between South East Europe and Central Europe reinforces the point. ACER reported that, although prices in 2025 did not reach the extreme levels seen in summer 2024, the price gap between Southeast and Central Europe persisted throughout 2025 and into early 2026. That suggests the region’s volatility is structural, not accidental.
Three factors explain this structural volatility.
First, solar is growing faster than system flexibility. Solar lowers prices during daylight hours, especially at midday, but it does not solve evening peak demand. Without batteries, pumped hydro, flexible gas, demand response or stronger interconnectors, the system becomes long during the day and tight after sunset.
Second, grid constraints matter as much as generation mix. If lower-cost electricity cannot move into the region when needed, local prices separate. This is why cross-border capacity, market coupling and transmission investment are now core market issues, not technical side topics.
Third, the region is unevenly integrated. EU member states in South East Europe operate inside the EU electricity-market framework, while Western Balkan markets are still progressing toward full integration. Serbia’s market is moving closer to EU practice, but wider Western Balkan market coupling remains unfinished.
The move to 15-minute day-ahead trading in the EU from 30 September 2025 is part of the same transition. The European Commission says the shift from hourly to 15-minute pricing helps markets reflect expected generation and demand more accurately. That matters in systems with high wind and solar shares, because imbalances can appear within much shorter time intervals than traditional hourly markets captured.
For South East Europe, this creates a new hierarchy of value. Pure generation remains important, but flexible generation is more valuable. Solar remains attractive, but solar with storage or flexible offtake is more valuable. Hydro remains strategic, but hydro availability depends on weather. Coal remains relevant for security of supply, but its economics are weakening under carbon and pollution pressure. Grid capacity, once treated as background infrastructure, is now a price-setting asset.
The investment implications are clear. The next wave of value creation in South East Europe will likely come from batteries, pumped hydro, grid upgrades, balancing-market participation, demand response, shaped PPAs and smarter trading capabilities. The region does not just need more megawatts. It needs more controllable megawatts.
This is the central thesis for South East Europe’s electricity markets in 2026–2028: the crisis has changed shape. It is no longer only about shortage. It is about flexibility scarcity.
Elevated by virtu.energy