Greece is giving Southeast Europe a clear example of how rapid solar capacity growth can weaken renewable revenues while solar generation remains strategically valuable to the electricity system. The pressure comes not from solar production itself, but from the growing concentration of generation in the same hours.
Renewable curtailment in Greece reached 1,601.4 GWh in the first half of 2026, compared with 1,327.1 GWh in the same period of 2025 and 513.5 GWh two years earlier. Greece also recorded 788 hours of near-zero or negative wholesale prices in H1 2026, against 168 hours in H1 2025 and 135 hours in H1 2024.
The effect on photovoltaic economics was also evident in capture rates. Greece’s average solar capture rate fell from 71.9% in H1 2024 to 61.6% in H1 2025, then to 44.0% in H1 2026. In May 2026, solar generation was valued at just 28.3% of the average wholesale price.
Solar generation and market value
A photovoltaic plant can generate exactly as its technical model predicts and still deliver revenue well below its original assumptions. The underlying mechanism is that simultaneous output from many solar installations adds daytime supply and lowers the market price. As installed capacity grows, each new project can also reduce the value captured by existing plants.
Limited grid capacity can compound the effect when it cannot transport all available generation, leading to curtailment. By August, Greece had recorded 949 hours of near-zero or negative prices during the first eight months of 2026, around three times the level for the corresponding period of 2025.
The issue is therefore not limited to new development. Existing photovoltaic assets financed on older assumptions may also need reassessment as expected captured prices decline. Merchant projects can generate less cash even if annual wholesale prices remain relatively strong.
Each curtailed MWh is technically available production that cannot be monetised unless contractual or regulatory compensation applies. Asset valuations may also change when future revenue models account for stronger cannibalisation, particularly where acquisitions were based on historical capture rates.
Implications for operating assets and regional markets
Lower expected cash flows can reduce the debt an asset can support, even when the plant remains technically sound and operationally profitable. AleaSoft distinguishes between asset profitability and financing compliance: a project may still be able to service scheduled debt but fall below the coverage levels required by its financing agreements.
For operating Greek assets, the response is not necessarily to abandon solar, but to reconsider how the asset earns revenue. Potential measures include renegotiating route-to-market arrangements, changing hedging structures, refinancing debt, adding flexibility or modifying operating strategies. None of these removes the underlying market signal that the economic value of electricity increasingly depends on when it is generated.
Greece’s experience is relevant to investors in neighbouring markets, although Serbia, Bulgaria, Romania, Croatia, Montenegro and other regional systems will not necessarily follow the same path or timetable. Their generation mixes, interconnection capacity, support mechanisms and market structures differ.
The Greek case demonstrates the risk of assessing renewable deployment only in MW. Once solar reaches sufficient scale, investors also need to measure the share of the market’s headline electricity price that photovoltaic generators actually capture. In Southeast Europe, Greece has made this project-finance issue an observable market phenomenon.