By 2025, the electricity market in South-East Europe has evolved into a complex network of cross-border exchanges, where nations frequently act as both importers and exporters within the same day. The region has transitioned from being a peripheral part of the EU energy landscape to a more integrated and sometimes volatile trading area. Key players such as Slovenia, Croatia, Hungary, Romania, and Bulgaria serve as critical nodes, while the Western Balkans—comprising Serbia, Bosnia and Herzegovina, Montenegro, Albania, and North Macedonia—navigate domestic limitations alongside regional opportunities.
Slovenia’s role as a transit market is significant. With an annual electricity consumption between 14 and 15 TWh, Slovenia relies heavily on imports due to limited domestic generation from nuclear, hydro, and some thermal sources. Despite this dependency, Slovenia exports during periods of high output from its Krško nuclear plant and hydro resources. Typically, net imports are low but gross flows are substantial because Slovenia connects vital north-south and east-west corridors. In 2025, average day-ahead prices are expected to range between 70 and 90 euros per MWh, closely mirroring Central European benchmarks.
Croatia’s electricity trade is influenced by hydro conditions. The country consumes approximately 17–18 TWh annually, with domestic production fluctuating between 11 and 15 TWh based on water availability. While Croatia often finds itself a net importer—usually by about 3 to 6 TWh—it can export during favorable hydro years. In 2025, prices are projected to align with regional averages of around 75 to 85 euros per MWh, showing volatility linked to seasonal renewable generation patterns.
Hungary remains an industrially driven market with significant import needs. With consumption exceeding 45 TWh annually and domestic generation falling short by a considerable margin, Hungary typically sees net imports ranging from 10 to 14 TWh. The country imports primarily from Slovakia, Romania, and Croatia while also facilitating transit flows to the Western Balkans. Day-ahead prices in Hungary are anticipated to hover around 80 to 90 euros per MWh in 2025, reflecting regional demand dynamics influenced by gas prices and renewable output variations.
Serbia has re-emerged as a net exporter. By maintaining an annual consumption level of approximately 33–34 TWh against a generation capacity that exceeds it by up to 4 TWh under normal hydrological conditions, Serbia has positioned itself favorably for exports. In recent years, particularly in 2024 and 2025, Serbia has exported low single-digit terawatt-hours mainly to neighboring countries. Prices on the Serbian exchange have converged with regional levels, averaging between 70 and 85 euros per MWh.
Romania plays a dual role as both an exporter and occasional importer. With total consumption around 55–57 TWh and a diverse generation mix that includes hydro, nuclear, gas, coal, wind, and solar power, Romania can achieve net exports of up to 6 TWh during favorable conditions. However, adverse weather can lead to short-term import requirements. Price levels generally align with those in Hungary and Bulgaria at around 70 to 90 euros per MWh.
Bulgaria stands out as a significant net exporter. Its domestic generation ranges from 40 to 45 TWh against an internal demand of about 30–32 TWh. Bulgaria regularly exports between 10 to 12 TWh annually primarily to Greece and Romania. Despite declining coal utilization trends, Bulgaria maintains a robust export profile supported by nuclear and expanding solar capacities. Average day-ahead prices align closely with Romanian levels but reflect Bulgaria’s strong export capabilities.
Bosnia and Herzegovina’s export potential is tempered by volatility. With annual generation around 17–18 TWh compared to domestic consumption of roughly 13–14 TWh, Bosnia generally maintains a net export position but faces fluctuations based on hydrological conditions. Price stability is affected by these variations; high regional prices can benefit Bosnia during tight supply situations while poor conditions may necessitate imports.
Montenegro’s small system is highly sensitive to external factors. Annual consumption stands at about 3.2–3.5 TWh while domestic generation fluctuates between 2 and 3 TWh. This results in net imports ranging from half a terawatt-hour to one-and-a-half terawatt-hours annually. Price dynamics reflect regional trends but have pronounced effects on Montenegro’s economy due to its limited size.
Albania’s electricity trade is predominantly hydropower-driven. With consumption around 7–8 TWh and generation varying significantly based on water availability—from as much as 9 TWh in wet years down to only about 5 TWh in dry years—Albania’s trade balance can swing dramatically between surplus exports or heavy imports depending on hydrological conditions.
North Macedonia remains structurally import-dependent. It consumes around 8–9 TWh while generating only about 5–6 TWh annually. Although recent increases in wind and solar output have slightly eased import needs during shoulder seasons, North Macedonia continues to rely heavily on imports from neighboring countries at prices reflective of regional scarcity.
Greece exhibits dual trading behavior throughout the year. With consumption at approximately 50 TWh and a generation mix dominated by gas and renewables, Greece alternates between being an importer during peak demand periods or low-renewable hours and an exporter when solar and wind production peaks. Average prices typically range from 80 to 95 euros per MWh due to higher gas dependence but are gradually improving with increased renewable integration.
The overall regional trading landscape illustrates clear structural patterns. Countries like Bulgaria function as stable exporters while Serbia acts as a swing supplier based on hydrological conditions. Slovenia and Croatia navigate modest domestic deficits with active trading roles; Hungary serves as a significant price-setting hub due to its industrial demand. The interconnectedness of these markets leads to increasingly synchronized pricing dynamics across the region despite underlying structural differences.
The implications for stakeholders are clear. Nations with stable export profiles benefit from stronger trade balances and reduced macroeconomic risks while those reliant on imports face heightened exposure to external shocks necessitating diversification strategies. South-East Europe is now recognized as an active participant in the broader European energy market landscape—a dynamic trading zone where interdependencies shape pricing mechanisms significantly.
