Hungary’s day-ahead electricity premium to Germany widened to almost €75/MWh for Oct. 8 delivery even as wind and solar generation recovered across Southeast Europe, highlighting how cross-border constraints and outages are increasingly preventing cheaper power from reaching the region’s tightest markets.
German day-ahead electricity dropped €52.68/MWh to €139.35/MWh, while Hungary’s HUPX benchmark rose €3.47 to €214.28/MWh.
The resulting €74.93/MWh spread was one of the clearest signals that regional transmission capacity, rather than aggregate European generation, is driving short-term SEE pricing.
Austria also traded below Hungary at €188.88/MWh, while scheduled imports into the monitored Hungary-SEE region from Austria and Slovakia fell by around 542 MW to 1.53 GW.
Within Southeast Europe, price movements were mixed.
Serbia’s SEEPEX benchmark fell €18.58/MWh to €179.39/MWh, widening its discount to Hungary to €34.89/MWh even as Serbia’s scheduled net imports increased to around 988 MW.
Montenegro rose €11.39 to €208.80/MWh, Bulgaria gained €9.80 to €208.40/MWh and Albania climbed €9.40 to €221.53/MWh, the highest monitored SEE daily average.
Romania was little changed at €209.38/MWh, Croatia fell to €200.81 and Slovenia to €197.10.
Greece remained cheaper at €165.25/MWh, while North Macedonia averaged €167.78/MWh.
Renewables recover but structural tightness remains
Regional demand increased only modestly, by around 284 MW to 29.94 GW, meaning the price moves were not primarily driven by consumption.
Supply conditions improved.
Forecast wind generation increased by around 959 MW to 2.32 GW, while solar gained 470 MW to 6.12 GW.
Total scheduled generation rose to approximately 27.94 GW, cutting regional net imports by about 466 MW to 2.00 GW.
Romania produced the largest improvement.
Its scheduled import requirement fell from roughly 1.44 GW to 314 MW as forecast generation increased by more than 1 GW to 5.21 GW.
But the improvement remains vulnerable because Romanian nuclear output is still absent.
Without Cernavodă, the system remains dependent on weather-sensitive generation and cross-border support.
Slovenia also swung strongly, moving from a roughly 251 MW import position to about 469 MW of scheduled exports.
Hungary moved in the opposite direction.
Its scheduled imports increased to around 1.70 GW as domestic generation fell to roughly 3.06 GW, reinforcing the country’s dependence on Slovakia, Romania and other neighbouring systems.
Kozloduy cuts increase Bulgarian supply risk
Bulgaria remained a major regional exporter, but its scheduled surplus fell sharply to about 826 MW from 1.50 GW.
Demand increased while forecast generation declined, and Bulgaria now faces an additional nuclear constraint.
Output from both Kozloduy units 5 and 6 was reduced by around 90 MW each because of critically low Danube water levels.
Kozloduy had already been managing unit 5 under a low-water operating regime.
Extending restrictions to both operating reactors increases the regional significance because Bulgaria has become one of Romania’s most important marginal sources of imported electricity.
The development adds hydrological risk to a market already dealing with weak Romanian nuclear availability.
Bosnia and Herzegovina, meanwhile, remained an important exporter, with scheduled net exports of roughly 386 MW, supplying Serbia and Montenegro.
Croatia continued to import around 703 MW, Albania 148 MW and Montenegro about 30 MW.
Greece remained a net exporter, although its scheduled surplus narrowed to around 240 MW.
Intraday volatility eases but storage value remains
Hourly volatility moderated compared with earlier sessions.
Serbia traded between about €110.60 and €250.10/MWh, considerably narrower than the previous day’s €45.90-295.10 range.
Hungary ranged from roughly €139.80 to €266.50/MWh, while Greece moved between zero and around €256.60/MWh.
No monitored SEE market recorded a negative day-ahead price.
Albania produced the highest regional hourly maximum at about €300/MWh, while Montenegro reached roughly €273/MWh.
The narrower ranges reduce immediate arbitrage margins from the extreme levels seen earlier in October but do not weaken the broader investment case for flexibility.
Repeated daily swings of more than €100/MWh continue to support batteries, pumped hydro and active load management.
Turkey remains isolated low-cost source
Turkey remained dramatically cheaper than the rest of the region.
Its provisional day-ahead average was around TRY3,006/MWh, equivalent to approximately €55/MWh.
That leaves Turkish electricity more than €150/MWh cheaper than Bulgaria, yet scheduled exports into Bulgaria remained around only 100 MW.
The price difference demonstrates the economic value of additional cross-border capacity.
Cheap generation exists close to the SEE market, but the network cannot move enough electricity to materially compress regional prices.
A similar constraint is visible farther north, where Germany’s €139/MWh electricity has limited impact on a Hungarian market clearing above €214/MWh.
Forward market keeps scarcity premium
Hungarian forward prices strengthened even as German spot power collapsed.
Week 42 rose to around €216/MWh, November climbed to approximately €219.50/MWh and Calendar 2027 reached about €157.50/MWh.
Higher gas and carbon prices added support, with CEGH gas around €78.93/MWh and EU allowances near €85.25/tonne.
The forward curve suggests traders do not expect Germany’s sharp spot decline to translate automatically into sustained relief for Southeast Europe.
Hungary remains heavily import dependent, Romania lacks nuclear generation and Bulgarian export capability is now being constrained by low Danube levels.
For generators, traders and lenders, the Oct. 8 market reinforces a structural shift already visible throughout the region.
Renewable generation is increasing and daily physical balances can improve quickly, but the commercial value of electricity is increasingly determined by where it is produced, when it is available and whether the grid can move it.
The nearly €75/MWh Hungary-Germany spread shows that in Southeast Europe, transmission scarcity can overwhelm even a major fall in neighbouring wholesale prices.