The bankability of renewable energy projects in Southeast Europe is changing, with Week 23 highlighting limits in relying on average day-ahead prices. During the week, the region saw higher electricity demand alongside weaker variable renewables. At the same time, thermal dispatch increased, net imports rose and prices diverged across markets.
Variable renewable output fell 8.9% week on week, including wind down 15.5% and solar down 5.1%. Regional electricity demand increased 8.2% to 15.15 TWh. Thermal generation rose 24.5%, while net imports climbed 9.1%. Prices moved differently by country, with Bulgaria and Italy rising while Serbia, Hungary, Croatia and Romania softened.
Week 23 market moves and implications for revenue assumptions
The Week 23 pattern points to revenue modelling challenges in a market with shifting generation and price dynamics. Solar output can coincide with periods of low midday prices even when weekly averages remain elevated. Wind generation may deliver strong annual output but still face high imbalance costs during volatile weeks.
Merchant exposure can also change depending on how generation profiles align with higher-price hours. Under average market prices, a merchant project may appear attractive, but value can decline if its production timing does not match price peaks. This requires project-level assessment beyond a single averaged price input.
Layered revenue stacks for bankable RES projects
Bankable RES projects increasingly require layered revenue stacks rather than day-ahead income alone. Developers are expected to consider intraday optimisation and participation in balancing markets alongside day-ahead revenues. Additional components cited include ancillary services, corporate PPAs and guarantees of origin.
Battery co-location and curtailment management are also part of the revenue and risk picture described for new projects. The overall strength of the revenue stack is linked to resilience under changing market conditions. In practice, lenders are expected to evaluate more than total energy output.
Contract structures and risk allocation in Greece and neighbouring markets
The approach is described as especially relevant for Greece, Romania, Bulgaria, Croatia, Serbia and Hungary as renewable pipelines expand and grid constraints become more visible. In these markets, lenders are expected to examine when energy is produced, where generation is connected and who bears imbalance risk. They are also expected to assess how curtailment is allocated.
Corporate PPAs are highlighted as a potential support for bankability when structured appropriately. Fixed-price PPAs can reduce merchant exposure but may shift shape and balancing risk to the generator. Indexed PPAs can preserve market upside while leaving offtakers exposed to volatility.
Hybrid PPAs combining storage with guarantees of origin and delivery-shape clauses are described as becoming more common in this context. These contract features are presented as mechanisms that can affect both delivery profiles and risk distribution between parties.
Batteries as part of firmness and imbalance management
Batteries are increasingly referenced as part of the bankability solution for renewables in Southeast Europe. They can shift output, reduce imbalance costs and capture evening spreads while improving firmness of delivery.
For solar projects, BESS is described as a way to protect against price cannibalisation during periods when solar output coincides with lower prices. For wind projects, batteries are described as supporting smoother forecast deviations and enabling balancing strategies during periods of volatility.
Week 23 is cited as evidence that SEE renewables are no longer operating in a simple growth environment where returns depend on volatility, flexibility and grid access . The next bankable renewable projects are described as those designed from the start for this complexity .
