On 15 May 2026, the Southeast European (SEE) power markets exhibited a pronounced divergence in pricing dynamics, with Central European markets maintaining elevated levels above €110/MWh. In stark contrast, Serbia experienced a significant collapse in day-ahead prices, attributed to diminished regional demand, reduced reliance on imports, and favorable hydrological conditions.
The Serbian day-ahead market saw prices plummet to €65.79/MWh, marking a decrease of nearly €49.5/MWh from the previous day and positioning Serbia as the lowest-priced market in the region. Neighboring Montenegro recorded prices at €93.41/MWh, while North Macedonia and Albania traded at €83.18/MWh and €90.11/MWh respectively. Conversely, Slovenia, Croatia, Romania, and Hungary remained closely aligned within a price range of €117–120/MWh.
This fragmentation in pricing underscores a significant structural shift in regional power balances. Serbia’s advantage stemmed from robust domestic generation capabilities and lower import needs, contrasting sharply with northern markets that are more tightly linked to Italian pricing structures. Total regional imports dropped to just 167 MW, down almost 950 MW from the previous day, signaling a notable decrease in external balancing requirements across the SEE region.
The generation landscape played a crucial role in this pricing shift. Hydro output remained strong at 6,404 MW—accounting for approximately 24% of the overall power mix—while coal generation increased to 4,876 MW and gas-fired generation rose to 3,736 MW. However, wind production fell sharply by nearly 1,800 MW day-on-day to just 1,897 MW.
Typically, such a steep decline in wind generation would lead to increased prices across SEE markets; however, the combination of enhanced hydro availability and lower demand mitigated this effect. Regional consumption saw a slight uptick to 28,694 MW but remained manageable within the existing thermal-hydro framework.
Within this context, the Serbian market illustrated how localized balancing pressures can disrupt broader pricing trends. Hourly prices on SEEPEX were heavily discounted throughout most of the day; they reached a low of €30/MWh with peak prices only hitting €121.1/MWh. This widening spread against HUPX created one of the most pronounced arbitrage signals noted recently across the Balkan corridor.
Cross-border flow data indicated ongoing export activity from several SEE markets towards neighboring systems facing deficits. Hungary sustained substantial exports to Croatia and Austria while Romania directed significant exports towards Hungary. Greece continued its dependence on imports from Bulgaria, with average flows into Greece reaching about 987 MW over the preceding week.
Italian market strength also played a pivotal role; Italy traded at €136.36/MWh—making it the highest-priced market in the region—which supported northwestern SEE markets like Slovenia and Croatia through interconnected flow dynamics and export economics into Italy.
Despite sharp fluctuations in spot prices, forward markets exhibited relative stability. Week-ahead baseload contracts in Hungary hovered around €117/MWh while calendar year contracts for 2026 remained above €112/MWh. Carbon prices under EUA were sustained at approximately €75/t alongside CEGH gas trading near €49/MWh; these figures suggest that traders perceive current spot weaknesses in Serbia and parts of the Balkans as temporary rather than indicative of long-term trends.
The underlying thermal generation capacity has remained active throughout the week as Danube hydrological conditions improved significantly—enhancing hydro dispatch flexibility essential for accommodating increasing renewable penetration across SEE markets amid rapid solar expansion in Hungary, Romania, Greece, and Serbia.
This evolving landscape highlights growing fragmentation within SEE electricity pricing following recent adaptations to negative-price capable market structures introduced earlier in 2026. Even as physical interconnections deepen within the region, local surpluses from renewables combined with hydro variability and transmission constraints are leading to wider temporary price discrepancies among neighboring markets.
This situation is particularly relevant for battery storage developers and cross-border traders as well as industrial consumers; the differential between Serbia’s low price of €65.79/MWh and Italy’s high price of €136.36/MWh represents an intra-regional spread exceeding €70/MWh during this trading session—improving prospects for cross-border balancing assets and flexible industrial demand management strategies.
Recent developments also indicate an accelerating trend toward renewable energy infrastructure expansion across the region: Kosovo’s Zatriq wind farm (72 MW) is nearing commissioning phase while Romania’s Green Breeze project (99 MW) is entering final stages of commissioning. Turkey continues its growth trajectory by enhancing both wind generation capacity and underground gas storage facilities.
Simultaneously, Serbia’s Electric Power Industry (EPS) reported quarterly profits amounting to €129 million due to improved hydrological conditions coupled with higher coal output and reduced debt levels—underscoring the critical role played by traditional thermal-hydro systems during periods characterized by renewable volatility.
The data emerging from these developments suggests that short-duration swings from renewables along with hydro conditions are increasingly shaping market dynamics rather than traditional fuel-based pricing mechanisms alone. The diverging trends between Balkan pricing structures and core European markets are becoming defining features of electricity trading within SEE throughout 2026.
