The electricity market in South-East Europe experienced significant shifts in January, characterized by elevated wholesale prices and volatility that highlighted existing structural disparities. The dynamics of the month underscored how different segments of the market were impacted variably, with certain entities capitalizing on the conditions while others faced considerable challenges.
Merchant thermal generators, particularly those operating gas-fired and lignite-based plants, emerged as the primary beneficiaries of January’s price fluctuations. These operators leveraged their flexible dispatch capabilities to capitalize on price spikes that frequently exceeded €120–130/MWh during colder periods. In countries like Serbia, Romania, and Bulgaria, lignite plants, benefiting from regulated or legacy fuel cost structures, enjoyed a disproportionate advantage as their marginal costs remained significantly lower than prevailing market prices. This scenario allowed them to extract substantial scarcity rents amid heightened winter demand and restricted cross-border capacity.
In tandem with thermal generators, cross-border traders and those benefiting from congestion rents also found favorable conditions. Transmission system operators (TSOs) and market participants positioned on constrained interconnections were able to capture significant congestion income throughout January. The persistent bottlenecks along north-south and east-west corridors resulted in wide price spreads between South-East European hubs and Central European markets during peak demand hours. Traders with physical access rights and adaptable portfolios successfully arbitraged these spreads, leading to TSOs accumulating congestion revenues that surpassed off-winter averages.
Hydropower operators also saw selective gains during this period. Although overall hydro availability varied, plants equipped with reservoir flexibility could strategically time their generation to coincide with peak price hours. Selling moderate volumes into price windows ranging from €110 to €130/MWh significantly enhanced revenue profiles compared to average yearly expectations.
Conversely, retail suppliers and utilities bound by fixed-price obligations faced considerable risks. Suppliers locked into regulated tariffs or long-term contracts encountered a widening gap between procurement costs and retail revenues. In several Western Balkan markets, January’s developments made it increasingly clear that tariff adjustments would be necessary as short-term losses mounted within supply portfolios. State-owned suppliers bore the brunt of this volatility, resulting in fiscal pressure as wholesale fluctuations strained their balance sheets.
Energy-intensive industrial consumers were another group adversely affected by the market conditions. Large industrial off-takers tied to spot or index-linked contracts experienced significantly higher electricity input costs throughout January, which compressed profit margins in sectors such as metals, construction materials, and chemicals. For exporters competing against producers in lower-priced Western European markets, the pricing environment exacerbated competitiveness gaps rather than alleviating them.
Some renewable energy generators also struggled relative to broader market trends. Merchant solar installations underperformed due to structurally low seasonal solar output in January, limiting their ability to benefit from price spikes. While wind energy performed better during certain periods, overall variability meant many renewable assets failed to fully capitalize on peak pricing events due to curtailment or grid constraints.
Public finances and consumers indirectly absorbed losses from these market dynamics as well. Although household tariffs did not immediately reflect the wholesale prices from January across all regions, the month exerted additional pressure on future regulatory decisions regarding tariff adjustments. Deferred pass-through mechanisms increased fiscal exposure for utilities that remain state-backed and politically constrained in adjusting prices.
This month’s trends reinforced established patterns within the South-East European electricity landscape: flexible dispatchable assets and strategically positioned traders profited from volatility rents while fixed-price suppliers, industrial consumers, and inflexible renewable portfolios suffered the consequences. The distributional effects observed were not merely cyclical anomalies but indicative of how scarcity factors, fuel linkages, and grid constraints continue to define the landscape of electricity markets in South-East Europe.
