Holiday demand shock drives the Week 15 price correction
Electricity prices across the South East Europe region fell sharply in Week 15 of 2026, reversing the elevated levels seen in the prior week. The move was tied to lower consumption during the Orthodox Easter period, which eased system tightness across interconnected markets. The steepest weekly declines were recorded in Bulgaria (-24.6%), Greece (-23.5%) and Romania (-22.8%), with other hubs also posting double-digit drops including Croatia (-20.3%), Serbia (-19.3%) and Hungary (-18.6%). Türkiye stood out with a weekly increase of +28.9%, pointing to localized supply-demand imbalances.
For developers and grid planners, the episode underlines how calendar-driven demand shifts can quickly change dispatch needs and cross-border power requirements. It also reinforces that price formation in the region remains sensitive to short-term balancing conditions rather than only long-run fuel and policy trends.
Solar surge offsets weaker wind as variable renewables reshuffle
While total variable renewable energy output declined by 6.6% week-on-week, internal generation patterns shifted markedly during the same period. Wind generation fell by 39.8%, with Greece and Italy each down by more than 60%, reducing wind’s contribution to meeting residual load. By contrast, solar generation rose by 41.8%, supported by better irradiance and longer daylight hours, consistent with a seasonal transition toward solar dominance.
Solar gains were particularly strong in Türkiye (+218%), Greece (+33.8%), Italy (+20.6%) and Hungary (+26.7%). Türkiye also recorded a net +9.3% increase in total RES output, as solar increases outweighed weaker wind conditions, a pattern that can affect how balancing resources are scheduled for portfolios with mixed wind-solar exposure.
Hydro and thermal generation adjust to maintain system balance
Hydropower output increased by 4.8%, led by gains in Italy (+20.2%) and Greece (+22.7%), while Romania remained broadly stable at +8.3%. Croatia saw a sharp rebound from a low base, whereas Serbia (-59.3%) and Bulgaria (-16.8%) experienced notable declines attributed to localized conditions. This uneven hydro performance helped moderate overall variability during the week, even as wind weakened and solar strengthened.
Thermal generation fell by 8.3% overall, with gas-fired output down 12.0% and coal/lignite decreasing 3.9%. Reductions were seen in Greece (-24.5%), Romania (-33.2%) and Hungary (-23.1%), while Serbia cut lignite output by 27.0%. Italy showed internal fuel switching, with lower gas use alongside a sharp rise in coal generation; Türkiye increased thermal generation by 8.3%, mainly through higher gas-fired output.
Cross-border flows ease as regional balances normalize
Cross-border electricity flows decreased by 8.3% week-on-week, reflecting movement toward a more balanced regional system as holiday demand softened constraints. Bulgaria increased exports significantly (+80.3%), while Romania moved from importer to exporter supported by stronger hydro output and lower domestic demand. Greece reduced exports sharply (-81.9%), and Türkiye also scaled back outward flows due to higher internal dispatch.
On the import side, Italy remained the dominant structural importer, while Croatia and Hungary continued relying on imports. Serbia’s nearly balanced position indicated normalization of regional flow patterns—an operational detail that matters for transmission planning assumptions used in congestion studies and cross-border procurement strategies.
Prices dip below €100/MWh before tightening returns
Across Southern Europe in Week 15, most SEE markets traded below €100/MWh, with prices ranging between approximately €25/MWh and €120/MWh. Türkiye recorded the lowest weekly average at €24.89/MWh, while Greece at €84.69/MWh became one of the cheaper markets after a -5.77% weekly decline from its prior level within the broader set of price movements described for the period.
At the upper end, Italy remained the most expensive market at €119.89/MWh despite a -11.94% drop, followed by Hungary at €92.19/MWh among higher-priced hubs; daily patterns showed most markets peaking on 10 April and lowest levels generally observed on 6 April. Across Europe, prices followed a broadly bearish trend driven by weaker demand, lower gas and CO₂ prices, and higher solar output; France led declines (-51.8%), while Spain (+194.0%) and Portugal (+182.4%) surged sharply, indicating partial decoupling of Iberian pricing from broader European moves.
Early rebound signals continued volatility risk for project economics
At the start of the following week, wholesale prices began to rebound as Day-Ahead levels rose again toward €125–146/MWh in several SEE markets, signaling a return of tightening fundamentals despite the Week 15 easing phase. The market remains sensitive to shifts in weather-driven renewable output and cross-border flows—conditions that can rapidly change revenue profiles for new solar, wind and hybrid assets.
For investors assessing CAPEX planning and execution readiness for renewables build-outs—alongside potential battery energy storage integration aimed at smoothing variability—the Week 15-to-early-week rebound sequence highlights why developers typically stress-test dispatch assumptions against both holiday demand shocks and fast-changing generation mixes.
Broader implications: Week 15 demonstrated how Orthodox Easter timing reduced demand across SEE while solar surged as wind weakened, pulling thermal generation down and easing cross-border constraints; however, early signs of price recovery toward €125–146/MWh suggest volatility can return quickly when fundamentals tighten again.