Week 23 underscored the need for Southeast Europe wind projects to be financed and operated differently from solar. Regional wind generation fell 15.5% week on week, contributing to most of the decline in variable renewable output across the region. The same period also showed how electricity prices, balancing requirements and thermal dispatch can respond when wind conditions weaken across multiple markets at once.
Largest variable renewable declines across regional markets
The steepest renewable-output reductions were recorded in Romania, Croatia and Serbia, attributed largely to weaker wind generation. Greece also saw a clear drop, with wind output falling 16.5%. That decline more than offset a modest 1.8% rise in solar generation.
Wind’s system impact differs from solar due to its distinct hourly pattern and seasonal profile. When wind is available, it can support evening and night-time supply. When wind output drops, the system often replaces it with hydro, imports, lignite or gas.
Project finance assumptions for wind versus solar
In Southeast Europe project finance, wind projects are expected to be modelled separately from solar. Wind can deliver higher capacity factors and stronger system value during non-solar hours, while its week-to-week volatility increases imbalance exposure. Lenders and investors are therefore expected not to rely only on annual P50 generation.
Instead, the assessment needs P90 downside cases, imbalance-cost assumptions and curtailment sensitivity. Capture-price modelling and realistic balancing-market exposure are also required for evaluating returns under weaker wind conditions.
Week 23 system response: demand, thermal output and imports
The system effect was visible in Week 23 data. Regional demand increased 8.2% to 15.15 TWh, while variable renewable output fell 8.9%. Thermal generation then rose 24.5% to 4.22 TWh.
Net imports also increased by 9.1%, reaching 1.22 TWh. Weaker wind coincided with higher demand, shifting reliance toward dispatchable generation sources during the same week.
Bankability factors for wind developers in constrained grids
The commercial implications extend to developers operating in Serbia, Romania, Croatia, Greece and Bulgaria. Wind projects can remain attractive where production occurs outside solar-heavy hours. However, bankability depends on managing volatility rather than assuming stable annual output.
Measures referenced include better forecasting, portfolio aggregation and hybridisation with batteries. Flexible PPAs and access to balancing services are also identified as factors that can influence project returns as volatility affects imbalance outcomes.
The issue is also linked to grid constraints as transmission systems face pressure from new renewable connections. A wind farm in a constrained node may face both imbalance risk and curtailment risk at the same time.
Projects with strong wind resources but weak grid access can see revenue quality deteriorate quickly when constraints limit delivery or when output variability increases imbalance costs.
Wind value tied to timing and flexibility rather than annual energy alone
The role of wind in Southeast Europe is described as not suitable for treatment as a simple annual-energy product. Its value is tied to timing, flexibility and system contribution rather than only total annual generation.
The next generation of Southeast Europe wind projects is therefore expected to require stronger revenue models alongside turbine performance metrics.
