Renewable investment across Southeast Europe was shaped for much of the past decade by rapid solar expansion, supported by falling equipment costs, simplified construction schedules and improving financing conditions. Photovoltaic projects became a preferred option for developers, infrastructure funds and banks. Across Romania, Bulgaria, Greece, Croatia, Serbia and increasingly Montenegro, solar pipelines expanded with gigawatts entering operation and additional capacity moving through permitting and financing stages.
An electricity market developing during 2026 points to a shift in how long-term value is assessed, according to Electricity.Trade. The renewable asset with the highest long-term strategic value may no longer be solar, with wind identified as an alternative. The change is described as reflecting how electricity markets price energy rather than a move driven by wind technology cost reductions or resource quality changes.
From levelized cost to capture-price timing
The renewable sector’s earlier focus centered on levelized cost of energy, under an assumption that the cheapest technology would eventually dominate. Solar remains among the lowest-cost options for new generation, but revenue is increasingly linked to when electricity is produced. As renewable penetration rises, electricity prices are no longer uniform throughout the day, making generation timing a key factor for earnings.
This pattern became more visible during May 2026. Across Southeast Europe, average solar generation reached 5,632 MW, while wind output was 2,833 MW. Solar accounted for approximately 22% of regional generation and remained one of the largest contributors to supply during the period.
While higher solar output can appear positive for investors, market pricing during the same periods can weaken returns. Thousands of megawatts of photovoltaic production enter simultaneously, increasing supply when demand is not sufficient. Prices decline precisely when solar plants generate at their maximum output.
This effect is described as capture-price erosion or solar cannibalisation. It has been observed beyond markets such as Spain, Germany and the Netherlands and is increasingly visible across Southeast Europe. The source highlights Greece as a clear example of how midday pricing weakens as solar capacity grows.
Greece’s solar growth and negative midday pricing
Greece has become one of Europe’s fastest-growing solar markets in recent years, with gigawatts of photovoltaic capacity entering operation. As a result, midday electricity prices have increasingly weakened and negative pricing events have become more frequent. Merchant revenues have faced growing pressure in parallel with these price moves.
The projects continue producing electricity as expected, but many generate lower revenues than originally projected because they operate during hours described as least valuable. In contrast, wind farms often produce significant volumes during evenings, nights and shoulder periods. Those are identified as hours when electricity prices remain strongest.
After sunset, solar generation fades while demand often stays elevated, requiring additional system supply. The source describes gas plants ramping upward and hydropower increasing production as balancing resources become more valuable. Electricity prices rise during these periods, and wind output increasingly captures higher-value hours.
This is characterized as a growing wind premium, where a megawatt-hour generated by wind at 8 p.m. may earn materially more than a megawatt-hour from solar at noon. The difference is becoming more important for investors as capture-price analysis gains weight alongside generation forecasts.
Capture-price analysis reshapes project evaluation and financing
Historically, project evaluations relied heavily on annual production forecasts. More recently, capture-price analysis has been described as becoming equally important for assessing returns. Under this approach, a solar facility can generate more electricity than a wind farm while still delivering lower financial returns due to price timing.
The shift is already influencing development activity across Southeast Europe. Romania is highlighted for its strong onshore wind resources, particularly in the Dobrogea region, which previously attracted major investment before solar development accelerated dramatically. Investors are now recognizing the complementary nature of wind generation within Romania’s future system needs.
Bulgaria is cited as another case where wind development may complement rapidly expanding solar portfolios despite attention on batteries. Wind generation is described as reducing dependence on imported balancing power while supporting system needs alongside solar additions. Serbia’s position within regional transmission networks is also referenced, with wind projects near major interconnection corridors able to access multiple markets simultaneously.
Montenegro’s export corridor and Italian market pricing
Montenegro’s export corridor and Italian market pricing
Montenegro is presented as offering long-term opportunity due to strong wind resources combined with access to the Adriatic export corridor and the Italian market. Future wind developments could benefit from domestic demand and from access to premium-priced export destinations. The Italian market remains particularly important in this context.
The source notes that average Italian prices during May remained substantially above those observed across much of Southeast Europe. This creates opportunities for renewable projects able to deliver electricity during high-demand periods where prices are stronger. Wind generation aligns with this requirement because it often produces during evenings, nights and shoulder periods.
Banks adjust underwriting to include capture prices
The growing wind premium is also described as affecting financing decisions. Banks increasingly evaluate capture prices alongside generation forecasts rather than focusing primarily on annual production estimates alone. The distinction between when output occurs versus how much it produces can affect debt sizing, cash-flow projections and project valuations.
The source states that wind projects frequently show stronger alignment with periods of higher market value compared with solar under these assumptions. It does not characterize solar as unattractive; instead it says standalone merchant solar economics are becoming more challenging as additional complementary technologies are increasingly needed.
Complementary assets for merchant solar portfolios
The report lists battery storage, flexible demand, industrial offtakers and hybrid project structures as complementary elements increasingly required for solar projects seeking merchant revenues. It also describes that wind often requires less support because its production profile naturally aligns with market needs under the evolving price pattern described earlier.
The implications extend beyond developers to utilities, traders and industrial consumers seeking diversified renewable portfolios. A system dominated by solar generation is described as experiencing substantial intraday volatility, while combining wind, solar, hydro and storage creates greater stability. This diversification becomes more valuable as renewable penetration rises across the region.
The article concludes that electricity markets are evolving beyond simple generation metrics in how value is assessed for renewables; projects producing electricity when the system needs it most are highlighted over those producing only the greatest number of megawatt-hours . In that environment, Electricity.Trade reports that wind power may emerge as Southeast Europe’s most strategically important renewable asset .
