Serbia’s wholesale electricity prices climbed above €300/MWh, increasing procurement costs for electricity suppliers, traders and energy-intensive manufacturers. The surge reflects tighter regional supply, significant import requirements and weaker domestic generation performance.
According to SEEPEX, baseload electricity reached €330.04/MWh, while the average price for delivery on October 30 stood at €303.29/MWh. Prices later eased to €291.58/MWh, following an evening peak of almost €500/MWh.
Evening Prices Approach €500/MWh
SEEPEX baseload prices increased from €241.69/MWh to €292.65/MWh and then €330.04/MWh over three consecutive trading sessions.
Peak-load electricity averaged €369.69/MWh, while the highest hourly price reached €499.99/MWh between 17:00 and 18:00. Even the lowest hourly price remained around €205/MWh. The following session, baseload electricity averaged €303.29/MWh, peak-load power reached €331.30/MWh, and the highest hourly price stood at €416.27/MWh.
The price pattern highlights the importance of hourly supply and demand balances. Solar generation can reduce daytime demand for conventional power, but declining output in the late afternoon increases reliance on dispatchable generation, storage and imports.
Regional Markets Record Similar Price Increases
The price surge extended across Southeast Europe. Electricity traded at approximately €323.76/MWh in Romania, €320.13/MWh in Bulgaria, €324.58/MWh in Hungary and €325.80/MWh in North Macedonia.
Montenegro recorded approximately €313–315/MWh, while Albania reached €366.85/MWh.
Regional market assessments indicated that forecast wind and solar availability had fallen by more than 2,200 MW, alongside lower electricity imports from Central Europe. Stronger demand and weaker wind generation further tightened supply during evening hours. High prices across neighbouring markets increase Serbia’s import exposure and reduce opportunities to secure cheaper electricity through cross-border trading. Actual transaction costs also depend on hourly price differences, transmission capacity, congestion and balancing requirements.
Electricity Imports Increase Financial Exposure
Serbia recorded approximately 515 GWh of net electricity imports during the first 22 days of October, according to preliminary estimates. The estimated net import cost reached €107.6 million, implying an average price of approximately €209/MWh.
The import balance corresponds to around 23.4 GWh per day, equivalent to almost 1,000 MW of continuous imported capacity. These estimates represent national cross-border electricity flows, not verified purchases or final import expenditure by Elektroprivreda Srbije (EPS). At an average price of €209/MWh, purchasing 100 GWh would cost approximately €20.9 million. At €300/MWh, the same volume would cost €30 million, an increase of €9.1 million, excluding trading, transmission and balancing costs.
Actual procurement expenditure depends on forward contracts, bilateral agreements, hedging arrangements and the timing of purchases. EPS’s exposure also depends on domestic generation, contracted supply obligations and electricity requirements.
Domestic Generation and Industrial Costs
EPS relies heavily on lignite-fired power stations and hydropower facilities. Thermal generation depends on coal quality, mining performance, maintenance and equipment availability, while hydropower output is influenced by reservoir management, river flows and seasonal conditions.
When domestic production cannot cover demand, additional electricity must be secured through imports or market transactions. Assessing the contribution of individual power plants to price increases requires hourly generation, outage, import and procurement data. Higher wholesale prices also affect steel, cement, chemical, metals-processing and other electricity-intensive industries.
Companies with spot-indexed contracts or uncovered electricity requirements face more immediate exposure than businesses operating under fixed-price agreements. For an industrial facility consuming 10 GWh, every €50/MWh increase in its effective electricity price adds €500,000 to procurement costs.
Higher energy expenditure can reduce manufacturing margins and export competitiveness, particularly for companies unable to pass additional costs on to customers. Fixed-price contracts, power purchase agreements, self-generation and demand management can reduce exposure, although suppliers must also account for hedging, credit and balancing risks.
Transmission Capacity and Storage Investment
Access to cheaper electricity from neighbouring markets depends on available cross-border transmission capacity. Congestion can limit imports even when lower-priced electricity is available elsewhere, increasing the commercial value of transmission rights and interconnection capacity.
Price differences between SEEPEX and neighbouring markets, including Hungary’s HUPX, Romania’s OPCOM and Bulgaria’s IBEX, can create trading opportunities, subject to transmission availability and associated costs.
The volatility also highlights the potential commercial role of battery storage and flexible generation. During the peak-price session, the difference between the highest and lowest hourly SEEPEX prices approached €295/MWh.
Such spreads can create opportunities for storage operators to charge during cheaper hours and discharge during expensive periods. Investment viability depends on charging costs, efficiency losses, battery degradation, operating expenditure, grid connections and the frequency of profitable trading cycles.
Hydropower flexibility, gas-fired generation, industrial demand response and battery storage can all help manage peak-hour exposure. Combining renewable generation with storage or flexible consumption may also become more important as solar output is concentrated in lower-priced daytime periods.
Winter Demand Raises Procurement Risks
Higher electricity prices ahead of the winter period could increase costs as colder temperatures and heating requirements raise consumption.
For EPS, independent suppliers and traders, prolonged high prices could increase procurement expenditure, working-capital requirements and collateral needs. Industrial consumers may face stronger incentives to review supply arrangements, adjust production schedules and limit consumption during expensive hours.
Although prices eased from the peak, they remained elevated across several consecutive trading sessions. Serbia’s exposure during the winter will depend on domestic generation availability, fuel supplies, hydrological conditions, regional electricity prices and its ability to secure imports when neighbouring markets are also under pressure.
