Southeastern European electricity markets showed mixed pricing on 11 August 2026, with declines in Hungary and several closely linked Central European markets. Prices increased in Greece, Bulgaria, Albania and Montenegro. Hungary’s HUPX day-ahead baseload price fell by €5.10 to €151.44/MWh. Romania cleared at €149.54/MWh, while Slovenia, Croatia, Serbia and Albania were also around €150/MWh.
Elsewhere, the largest rise was recorded in Albania, where the price increased by €18.30 to €149.84/MWh. Montenegro gained €14.60 to €155.59/MWh, while Bulgaria advanced €11.40 to €146.72/MWh. Greece rose by €11.80 but remained the lowest-priced market in the region at €115.78/MWh. Italy posted the highest regional level at €181.14/MWh.
The Italy-Hungary premium was €29.71/MWh, while Germany cleared at €110.38/MWh, leaving HUPX €41.05/MWh higher. The Hungarian premium over Greece stood at €35.66/MWh, although the spread narrowed by €16.90 versus the previous day.
Day-ahead hourly profile shows solar-driven daytime softness
Hungary’s hourly price pattern contrasted solar-rich daytime hours with the evening peak on HUPX. The minimum price was €62.70/MWh in hour 13, while the maximum reached €245.10/MWh in hour 21, producing a spread of more than €182/MWh. The peak-load block averaged €125.10/MWh compared with €177.80/MWh during off-peak hours.
Similar intraday shapes appeared in neighboring markets, including periods of very low prices around midday followed by higher evening levels. Germany briefly recorded a negative price of €0.10/MWh before rising to €199/MWh in hour 21, while Greece registered zero-priced hours around midday and reached €241/MWh in the evening.
Forecast generation pointed to higher solar and lower wind output across the region, with solar expected to rise by 1,461 MW to 8,653 MW. Wind output was forecast to decline by 660 MW to 2,616 MW. Higher solar production eased daytime conditions, while weaker wind generation tightened balances later in the day.
Consumption outlook and cross-border flows increase net imports
Regional electricity consumption was forecast at 34,426 MW, up by 2,010 MW or about 6.2% from the previous day. Net imports increased from 982 MW to 1,569 MW. Imports from core Central European markets rose by 527 MW to 2,649 MW.
Hungarian electricity consumption climbed to 4,963 MW. With domestic generation estimated at 2,926 MW, Hungary required average net imports of 2,037 MW, up by 191 MW. Slovakia, Romania and Austria were identified as the main sources of electricity imports.
Romania moved further into net-import status as average imports rose to 476 MW from 195 MW. Greece remained a regional exporter with an average surplus of 1,666 MW. Flow data indicated that Hungary’s price premium over Germany continued to draw power from Central Europe.
Prompt contract moves track fuel cost rises and curve shifts
Hungarian prompt electricity contracts declined despite higher fuel prices. The Week 34 contract fell by €6.50 to €154.50/MWh and Week 35 dropped by the same amount to €153.50/MWh.
The September contract increased by €0.50 to €163.50/MWh, while the calendar contract gained €3 to €126.50/MWh. The changes reflected weaker near-term pricing alongside firmer deferred power.
Pursuing spreads against Germany also narrowed for Hungarian products: the HU-DE Week 34 spread fell by €12.50 to €23.50/MWh and the September spread declined by €4.50 to €27.50/MWh.
Gas, coal and carbon prices rise; Paks recovery and wind weakness affect prompt baseloads
European gas and coal prices rose sharply during the period described for 11 August trading activity. CEGH September gas increased by €5 to €62/MWh and the fourth-quarter contract gained €5.50 to reach €62.50/MWh.
Northern API-2 coal rose by €6 to €121.50/MWh for September and fourth-quarter coal reached €124.50/MWh after gaining €124?
