Serbia remained one of Southeast Europe’s lower-priced electricity markets in Week 34, despite a sharp increase in domestic demand. The combination created a renewed price discount against Hungary and Croatia, strengthening the potential value of northbound electricity flows when cross-border capacity is available.
The Serbian day-ahead market averaged €133.02/MWh between 17 and 23 August, representing a 5.8% increase from Week 33. Among the monitored markets, only Türkiye recorded a lower weekly average. Hungary’s price reached €155.16/MWh, putting Serbia at a discount of approximately €22/MWh, while Croatia averaged €153.78/MWh, around €21/MWh above the Serbian market.
Serbia’s relatively strong price position is particularly notable given the sharp increase in electricity consumption. Domestic demand rose 13.54% compared with Week 30, one of the largest increases among the monitored markets. Croatia recorded the only stronger increase, at 14.33%, while most other Southeast European markets experienced declining consumption.
Higher demand was largely absorbed by stronger domestic generation. Serbia’s variable renewable generation increased 48.9%, while hydropower output rose by 66.58%. Thermal generation also increased by 12.45% compared with Week 30. Serbia consequently maintained its position as a net electricity exporter during the period, despite the substantial increase in domestic consumption.
This combination of rising demand, stronger generation and continued exports provides an important explanation for the Serbian market’s relative price resilience. Additional domestic supply reduced the need to rely on higher-cost imports and allowed Serbia to maintain a lower price level even as wholesale prices increased across the wider region.
Hungary presented a contrasting picture. Its thermal generation increased sharply, while net imports rose 139.08% compared with Week 30, indicating a greater reliance on both domestic thermal generation and cross-border electricity supply to meet market requirements.
The Serbian-Hungarian price spread was therefore one of the more significant signals in the Week 34 market data. A differential of more than €20/MWh creates theoretical value for northbound electricity flows, provided sufficient interconnection capacity is available and congestion costs do not eliminate the underlying spread.
The same dynamic was visible in Serbia’s relationship with Croatia, where the Croatian weekly average remained approximately €21/MWh above the Serbian price. Such differentials underline the importance of cross-border market coupling and available transmission capacity in determining whether regional price spreads can translate into actual trading opportunities.
The broader picture shows that Serbia’s market position cannot be assessed solely by looking at the overall direction of Southeast European prices. While the regional power complex became more expensive during Week 34, Serbia’s relative competitiveness improved against several neighbouring markets.
For regional traders, this positions Serbia as an increasingly relevant source of comparatively lower-cost electricity during periods of tighter conditions in Central European markets. Its combination of stronger renewable and hydro generation, rising domestic supply and continued export capability could support northbound flows when price spreads and transmission availability align.
