On March 25, power prices across Southeast Europe and Hungary experienced a significant decline, retreating from earlier highs as a marked increase in wind generation coincided with reduced demand. This combination led to an oversupply in the electricity system, prompting a synchronized drop in day-ahead market prices across the region.
Benchmark contracts reflected this trend, with Hungary’s HUPX clearing at €107.6/MWh, down €16.7 from the previous day. Romania’s OPCOM recorded a price of €96.9/MWh (down €17.8), while Bulgaria’s IBEX fell to €87.3/MWh (down €23.3). Greece’s HENEX dropped to €78.9/MWh, down €30.1, and Serbia’s SEEPEX fell sharply to €71.7/MWh, marking a substantial daily correction of €41.4.
This widespread decline indicates a regional repricing rather than isolated local factors, with prices converging toward a range of €70–110/MWh.
The primary catalyst for this downturn was a notable increase in renewable energy output, particularly from wind sources. Wind generation surged to 4,062 MW, an increase of 1,427 MW day-on-day, which significantly altered the merit order and displaced gas-fired generation. Concurrently, gas output decreased to 5,680 MW, down 1,035 MW, diminishing its influence as the marginal price-setting technology.
Solar generation also saw a slight decrease to 3,436 MW, down 122 MW. However, the overall contribution from renewables increased due to the robust wind output, compressing peak prices and flattening intraday spreads across Central Eastern and Balkan markets.
The decline in demand further reinforced bearish market conditions as total consumption decreased to 32,902 MW, down 1,600 MW. This reduction is attributed to milder temperatures across the region, averaging around 10–11°C. The combination of lower heating needs and higher wind output exerted additional downward pressure on pricing.
Cross-border electricity flows adjusted accordingly, with net imports falling to -550 MW, a decrease of 425 MW. Core imports from Austria and Slovakia into the region also declined to 1,940 MW, down 172 MW. This shift suggests an improvement in internal generation adequacy and a reduced dependency on higher-priced Central European markets.
The spread between Hungary and Germany widened to approximately €69.9/MWh, emphasizing ongoing structural differences between Central Western and Southeast European markets due to congestion and varying generation mixes.
The gas market showed signs of easing as well, with the Austrian CEGH benchmark at €55.5/MWh, reflecting a day-on-day decline. Greek hub levels also softened to €44.3/MWh. However, the role of gas in power pricing diminished significantly as gas-fired generation was increasingly supplanted by wind energy.
Despite lower average prices across markets, intraday volatility remained prominent. Peak hourly prices in several areas still reached between €180–260/MWh, while minimum prices approached near-zero levels in zones closely linked to Central European flows. This situation reflects persistent structural imbalances throughout the day driven by midday oversupply from renewables and evening ramp constraints that maintain peak pricing.
The regional generation mix on March 25 illustrated significant transition dynamics: coal constituted 22%, hydro accounted for 21%, nuclear represented 18%, gas made up 17%, wind contributed 12%, and solar added another 10%. The increased reliance on wind relative to gas underscores a shift toward more volatile price formations influenced by intermittent generation.
Cros-border commercial flows remained active, with Romania exporting electricity towards Hungary and Greece while Bulgaria supplied Serbia and Greece. This dynamic highlights a semi-integrated regional system sensitive to local constraints and weather-driven shifts in generation.
The near-term outlook appears bearish as it remains contingent on renewable output levels. Should wind generation continue at elevated levels while demand stays below approximately 34 GW, day-ahead prices are expected to stabilize within a range of €65–100/MWh. Nevertheless, intraday volatility is likely to persist with continued disparities between low midday prices and elevated evening peaks.
This evolving market structure increasingly reflects a transition from fuel-driven pricing mechanisms toward those influenced by weather variability, where fluctuations in renewable energy output play an essential role in determining short-term price trajectories.
