Serbia’s electricity price averaged €247.89/MWh in Week 42 as Southeast Europe’s power markets became more fragmented despite prices rising across the region. Hungary averaged €246.87/MWh and Romania €240.51/MWh, while Bulgaria reached €235.89/MWh and Croatia €230.49/MWh. Greece remained substantially cheaper at €186.57/MWh.
Analysis by Virtu.Energy put the reported gap between the highest- and lowest-priced European SEE markets at €60.30/MWh, up from €51.66/MWh the previous week. Greece traded at a discount of €53.94/MWh to Romania and €60.30/MWh to Hungary. The widening differences, rather than the rise in average prices alone, increased the commercial importance of cross-border capacity.
Cross-border flows and congestion
In interconnected electricity markets across Southeast Europe, wide price spreads indicate that available generation is not moving freely enough to eliminate differences between neighbouring bidding zones. Physical congestion, available transmission capacity, generation patterns and national demand consequently become more valuable variables for traders and flexible generators. Greece offered the clearest example: its comparatively low price coincided with substantially stronger electricity exports.
Serbia and Hungary, meanwhile, increased their net import requirements. Bulgaria, traditionally an important regional exporter, saw its net export position almost disappear. These conditions can create substantial value for holders of cross-border transmission rights and traders able to move supply between lower- and higher-priced markets.
The spreads also strengthen the investment case for interconnection, although a €50–60/MWh difference does not mean a transmission project would capture that amount continuously. Repeated periods of structural divergence increase the economic value of transfer capacity by allowing lower-cost generation to reach constrained markets more effectively. Hourly flows, available cross-border capacity and congestion forecasts therefore carry greater weight in trading decisions.
Implications for storage and renewables
The same price structure has implications for storage. A battery connected in a high-priced market can capture intraday volatility without trading directly across borders. Larger storage projects may also ease the effects of congestion by shifting electricity from lower-demand periods into system peaks.
For renewable producers, wider regional spreads bring both opportunity and risk. A wind or solar plant in a lower-priced bidding zone may generate competitively priced electricity yet earn less merchant revenue than a comparable project in a structurally tighter market. Developers in high-priced zones may capture stronger revenues but face greater balancing and grid-connection risks.
Serbia, Hungary and Romania effectively formed a high-price cluster in Week 42. Bulgaria and Croatia were slightly cheaper but remained elevated, while Greece was a lower-priced southern market supported by rising renewable and thermal output. Italy, at €225.21/MWh, fell between those groups; Türkiye remained structurally separate at €52.69/MWh.
For utilities and industrial buyers, the fragmentation increases the value of geographical diversification in electricity procurement. For investors, it makes project location almost as important as generation technology. Renewable investment depends not only on low-cost output, but also on where electricity enters the grid, available transmission capacity and whether storage or contractual structures can protect producers from persistent local price discounts.
