South East Europe is becoming one of Europe’s most important electricity-market laboratories. The region combines fast solar growth, legacy coal, hydro volatility, constrained grids, incomplete market coupling, rising storage needs and carbon-border pressure. That combination creates risk, but also opportunity.
The base-case outlook for 2026–2028 is not simply “high prices” or “low prices.” It is continued volatility.
Average wholesale prices may remain below the extreme levels seen during the energy-crisis years, but the shape of prices will matter more. Midday prices are likely to weaken as solar grows. Evening prices are likely to remain exposed to scarcity when demand is high and flexible capacity is limited. ACER’s analysis of the 2024 price spikes and the persistent 2025–early 2026 SEE–Central Europe price gap supports this view.
The first major investment signal is storage. Batteries are moving from optional enhancement to core infrastructure. Bulgaria’s RESTORE-backed storage push, including official support for 3,000 MWh of usable capacity and wider project approvals around 9.7 GWh, shows how quickly the region is moving toward flexibility investment.
The second signal is grid value. Transmission capacity, interconnectors, congestion management and cross-border allocation will be decisive. ACER has recommended better use of available network capacity, implementation of the 70% cross-zonal capacity requirement, expanded flow-based capacity calculation and extension of market coupling to non-EU neighbors.
The third signal is market sophistication. The EU’s shift to 15-minute day-ahead trading reflects a system where electricity value changes quickly within the day. South East Europe will need trading, forecasting and balancing capabilities that match this more granular market reality.
The fourth signal is carbon exposure. CBAM is already affecting the commercial relationship between the EU and Western Balkans. The Energy Community reported a 25% fall in commercially scheduled exchanges between the EU and Western Balkans in Q1 2026, while day-ahead prices in Contracting Parties were on average €30/MWh lower than neighboring EU markets.
This creates a clear map of likely winners.
The first winners are flexible assets: batteries, pumped hydro, flexible hydro operation, demand response and fast-ramping plants. These assets benefit from price spreads and system stress.
The second winners are sophisticated traders and optimizers. As markets move toward negative prices, 15-minute products and more volatile intraday conditions, value shifts toward forecasting and flexibility management.
The third winners are renewable projects with storage, hybrid profiles or strong offtake structures. Standalone merchant solar will still be built, but its risk profile is becoming more challenging.
The fourth winners are industrial buyers with flexible demand. Companies able to shift consumption into low-price hours can turn volatility into savings.
The fifth winners are grid and infrastructure investors. Transmission reinforcement, substations, digital grid technologies and interconnectors will be central to market integration.
The likely losers are also clear.
Unhedged consumers will remain exposed to price spikes. Standalone solar projects without storage or shape protection may face declining capture prices. Aging coal assets will face rising carbon, pollution and financing pressure. Utilities that delay transition planning may lose export revenue and market position. Policymakers that slow market coupling may leave consumers paying for inefficient fragmentation.
The upside case for South East Europe is attractive. Faster storage deployment, stronger grids, market coupling, better balancing markets and industrial demand response could reduce scarcity events and improve renewable integration. In that scenario, the region becomes a competitive clean-power corridor linking the EU and Western Balkans.
The downside case is equally plausible. A hot and dry summer, weak hydro output, gas-price volatility, grid outages and CBAM-related trade friction could combine to produce another period of severe price stress.
The strategic conclusion is simple: South East Europe is not short of energy potential. It is short of flexibility, integration and investable market design.
The next two years will reward those who understand that electricity is no longer a simple commodity sold by volume. It is a time-specific, location-specific and carbon-sensitive product.
That is the new electricity market in South East Europe.
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