Electricity markets across Southeast Europe grew more fragmented in Week 42, as prices increased across the region at markedly different rates. The divergence widened the commercial value of cross-border capacity and made congestion more important for traders and flexible generators. This market analysis is courtesy of Virtu.Energy.
Among the region’s electricity markets, Serbia recorded an average of €247.89/MWh, Hungary €246.87/MWh and Romania €240.51/MWh. Bulgaria averaged €235.89/MWh and Croatia €230.49/MWh, while Greece was considerably cheaper at €186.57/MWh.
The gap between the highest- and lowest-priced European SEE markets reached €60.30/MWh, up from €51.66/MWh the previous week. Greece traded at a €53.94/MWh discount to Romania and a €60.30/MWh discount to Hungary. This divergence carried more significance than the straightforward rise in average electricity prices.
Wide price differences in an interconnected market indicate that available generation is not moving freely enough across borders to equalise prices between neighbouring zones. Physical congestion, available transmission capacity, generation patterns and national demand therefore become increasingly valuable commercial factors for market participants.
Cross-border flows and flexibility gain importance
Greece offered the clearest example of the changing regional picture. Its comparatively low price coincided with substantially stronger electricity exports, while Serbia and Hungary increased their net import requirements. Bulgaria, traditionally an important exporter to the region, saw its net export position almost disappear.
These conditions can create considerable value for holders of cross-border transmission rights and traders able to position supply between lower- and higher-priced markets. They also strengthen the investment case for interconnection. A €50–60/MWh spread would not be captured continuously by a transmission project, but repeated periods of structural divergence increase the economic value of transfer capacity by enabling lower-cost generation to reach constrained markets more effectively.
The same principle applies to storage. A battery connected in a high-priced market can capture intraday volatility without taking part directly in cross-border trading. Larger storage projects may also ease the effects of congestion by shifting electricity from periods of lower demand into system peaks.
Regional price differences shape renewable revenues
Widening regional spreads create both opportunities and risks for renewable producers. A wind or solar plant in a lower-priced bidding zone may generate competitively priced electricity but earn less merchant revenue than a comparable project in a structurally tighter market. Developers in higher-priced zones, conversely, may capture stronger revenues while facing greater balancing and grid-connection risks.
The Week 42 price structure points to a more complex investment environment than any single regional average can show. Serbia, Hungary and Romania formed a high-price cluster, while Bulgaria and Croatia were somewhat cheaper but remained at elevated levels. Greece operated as a lower-priced southern market, supported by rising renewable and thermal output.
Italy, at €225.21/MWh, sat between those groups, while Türkiye remained structurally separate at €52.69/MWh. For utilities and industrial buyers, this fragmentation increases the value of geographical diversification in electricity procurement. Traders face greater importance for hourly flows, cross-border capacity and congestion forecasting.
Grid access and location remain central to investment
For investors, the Week 42 market structure reinforces the importance of location alongside generation technology in Southeast Europe. The next phase of renewable investment will depend not only on producing low-cost electricity, but also on where that electricity enters the grid and what transmission capacity is available. Storage or contractual structures may protect producers against persistent local price discounts.
Courtesy of Virtu.Energy