Southeast European renewable financing is deepening, but August showed that lenders are becoming increasingly selective. Capital is flowing toward larger projects, experienced sponsors and assets with credible routes to market, rather than treating renewable capacity as interchangeable.
Romania provided the clearest evidence of this trend. BCR and Erste Group agreed approximately €132 million of construction financing for Scatec’s 77 MW Urleasca wind farm, with BCR contributing around €76 million.
The transaction forms part of a broader expansion in energy lending. BCR reported financing approximately €450 million of Romanian energy investments during the first half of 2026, including more than €362 million for renewable projects. Of that total, approximately €288 million was allocated to wind, €41 million to solar and €33 million to battery storage.
The strong allocation to wind is particularly notable after several years in which renewable development pipelines across Southeast Europe became increasingly dominated by solar. The shift reflects not necessarily a preference for wind, but growing attention to generation profiles and the relationship between output and realised power prices.
Solar production is increasingly concentrated in midday hours, when growing photovoltaic penetration can place downward pressure on market prices. Wind generation typically follows a different production pattern, creating potential diversification benefits for portfolios exposed to multiple renewable technologies.
That does not make wind inherently more attractive than solar. Instead, it makes the shape and timing of generation increasingly important to project economics. Two projects with similar annual output can have materially different revenue profiles depending on when they generate and the market prices captured during those hours.
As a result, lenders are moving beyond simple annual generation assumptions when assessing renewable assets. Curtailment risk, balancing costs, negative-price exposure, merchant periods and grid constraints are becoming increasingly important components of financial models and credit assessments.
The traditional renewable financing model was relatively straightforward when projects benefited from feed-in tariffs or long-term fixed-price PPAs that provided predictable revenues. Increasing merchant exposure introduces a much wider range of potential outcomes and places greater emphasis on the quality of a project’s commercial structure.
This environment favours larger and more experienced sponsors that can manage diversified portfolios, negotiate sophisticated PPAs, optimise market exposure and absorb periods of weaker pricing. It may also create a more challenging financing environment for smaller standalone projects that lack contractual revenue protection or sufficient scale to absorb market volatility.
The Southeast European lending market is therefore becoming more mature rather than simply more generous. Capital is available, but banks are increasingly distinguishing between projects based on sponsor quality, contractual structure, grid exposure and expected market performance.
The result is a more selective financing environment in which not all renewable megawatts are valued equally. As renewable penetration increases and merchant exposure grows, the projects most capable of demonstrating predictable cash flows and effective risk management are likely to capture an increasing share of available capital.
