Southeast European day-ahead electricity prices jumped sharply for Monday, Oct. 19, as the return of weekday demand, weaker renewable forecasts and continued heavy import requirements tightened the regional power balance, pushing Serbia above €300/MWh and widening the premium over western European markets.
Serbia’s SEEPEX market was the most expensive in the region at €300.22/MWh, up €46.3/MWh from Sunday. Hungary’s HUPX followed at €292.39/MWh, an increase of €36.4, while Romania rose to €281.07/MWh, Bulgaria to €279.48/MWh, Albania to €280.60/MWh, North Macedonia to €277.18/MWh and Montenegro to €276.23/MWh. Croatia settled at €260.47/MWh and Slovenia at €254.49/MWh. Greece remained the cheapest SEE market at €232.43/MWh, despite posting a €51.7 daily increase.
The move was therefore not an isolated Serbian price event but a broad regional repricing after the weekend. Every major SEE day-ahead market rose strongly, with increases ranging from roughly €36/MWh in Hungary to almost €58/MWh in Albania.
The principal driver was the Monday recovery in electricity demand. Combined Hungary and SEE consumption was forecast at 31,426 MW, almost 3 GW higher than Sunday. Regional net imports simultaneously increased by 635 MW to 3,525 MW, showing that additional domestic generation was insufficient to cover the full increase in load.
Renewable conditions offered limited support. Solar generation was forecast at 3,800 MW, down 677 MW day on day, while wind was expected at 2,412 MW, 42 MW lower. Imports from the core Central European markets reached 3,431 MW, up another 132 MW from Sunday.
The broader balance data reinforce the tightening picture. Regional consumption increased from 28,454 MW on Sunday to 31,426 MW on Monday, while imports rose from 2,889 MW to 3,525 MW. Sunday generation had stood at 25,565 MW, with hydro at 3,236 MW, coal at 6,763 MW, gas at 4,796 MW, wind at 2,455 MW and solar at 4,478 MW.
Serbia develops the strongest regional premium
The most notable pricing signal came from Serbia. SEEPEX at €300.22/MWh traded €7.83/MWh above HUPX, around €68/MWh above Greece and almost €92/MWh above Germany.
Serbia’s own balance improved compared with Sunday, but not enough to detach its price from the wider regional squeeze. Consumption increased to 3,871 MW from 3,629 MW, while generation recovered to 2,650 MW from 2,180 MW. Serbia nevertheless remained a substantial net importer at about 1,221 MW on average.
The hourly profile was even more significant for generators, storage investors and traders. SEEPEX fell to a daily minimum of €185/MWh around H14 before climbing to a maximum of €404/MWh at H19. Peak-load electricity averaged €297.7/MWh and off-peak power €302.7/MWh, underscoring that scarcity was not limited to conventional business hours.
That shape strengthens the commercial case for flexible generation and batteries. The market is increasingly showing a combination of relatively softer midday hours followed by very expensive evening ramps, creating a potentially valuable arbitrage window even on days when the daily base-load price is already high.
Montenegro followed the same regional pattern. BELEN climbed €39.6/MWh to €276.23/MWh, with the hourly maximum reaching €360/MWh. The minimum price was still relatively elevated at €210/MWh, meaning Montenegro experienced less of the deep daytime price compression visible further south.
Greece shows the other side of the flexibility trade
Greece provided the sharpest illustration of increasingly volatile intraday power economics.
HENEX averaged only €232.43/MWh, almost €60 below HUPX, but the hourly range stretched from just €2.8/MWh to €375.8/MWh. The minimum occurred during the daytime period, while the maximum arrived at H21.
Greek peak-load prices averaged only €171.6/MWh compared with €293.2/MWh off peak, an unusual structure reflecting the impact of daytime renewable generation followed by a steep evening repricing.
This is becoming one of the most important trading and investment characteristics of the southeastern European market. Average daily prices alone increasingly conceal the value of flexibility. Solar-heavy systems can move from near-zero marginal pricing during parts of the day to several hundred euros per megawatt-hour during the evening ramp.
Albania showed a similarly extreme evening signal, with its maximum price reaching €449/MWh, the highest hourly level among the markets covered, while the daily average stood at €280.60/MWh.
Germany gap remains the key regional constraint signal
The most important cross-border indicator remains the Hungary-Germany spread.
German day-ahead electricity settled at €208.44/MWh, compared with €292.39/MWh on HUPX, leaving Hungary at a premium of €83.96/MWh. The spread widened by €3.2/MWh from Sunday despite more than 3.4 GW of core imports into the Hungary-SEE region.
Austria traded at €236.72/MWh and Italy at €262.63/MWh, meaning much of SEE remained substantially more expensive than the western and central European supply centres.
The persistence of that premium despite large imports is a significant signal for regional trading and infrastructure investment. It indicates that access to cheaper western electricity remains unable to fully eliminate southeastern Europe’s scarcity premium during tighter hours.
Forward prices suggest traders expect the extreme spot conditions to moderate, but not disappear.
Hungarian Week 43 power was quoted at €268/MWh, Week 44 at €262.50/MWh and November at €246.50/MWh, while the Hungary-Germany forward spread remained exceptionally wide at €92/MWh for Week 43, €78/MWh for Week 44 and €55/MWh for November.
Fuel prices offer limited prospect of immediate relief. Austrian CEGH gas stood at €89.56/MWh, November gas at €89/MWh, EUA carbon allowances at €85.41/tonne and November coal at €152.5/tonne, keeping the marginal cost environment for thermal generation elevated.
The Oct. 19 market therefore points to a familiar but increasingly pronounced SEE structure: strong weekday demand is rapidly translating into higher imports and triple-digit regional premiums over Germany, while renewable-heavy markets are simultaneously developing deep intraday price swings. Serbia’s €300/MWh base price and €404/MWh evening peak show where the immediate scarcity risk is concentrated, but the wider investment signal is regional — additional transmission, storage and flexible generation are becoming increasingly valuable as the gap between cheap renewable hours and expensive system-balancing hours grows.