Wind power is gaining strategic importance in Southeast Europe—not because development has become easier, but because the rapid expansion of solar is increasing the value of renewable generation outside the midday photovoltaic window. July’s price movements highlighted the commercial advantage of a more diversified generation profile, while project announcements across Romania, Bulgaria, Greece and Türkiye showed that investors are responding to the changing market dynamics. The main constraint is no longer investor interest in wind. It is the speed at which projects can secure permits, grid access and bankable revenue support.
July’s power curve is rewarding renewable diversity. A regional market monitor estimated solar generation at 8,518 MW for July 20 delivery, compared with just 1,467 MW of wind, with wind output down by 290 MW from the previous day. Solar generation pushed prices lower around midday, but weaker wind output and the disappearance of photovoltaic generation after sunset contributed to evening prices of approximately €190/MWh in Romania, Bulgaria and Greece and €210/MWh in Serbia.
The preceding weekly balance pointed in the same direction. During Week 27, monitored Southeast European wind generation fell by 5.1%, while solar declined by 1.8% and hydropower by 3.4%. Net imports increased by 28.2%, with thermal generation filling part of the shortfall. These figures are operational snapshots rather than proof of a permanent premium for wind, but they demonstrate why low-wind periods can become particularly expensive once solar output disappears in the evening.
Wind does not always generate during peak-price hours, and increasing installed capacity can eventually lead to wind-price cannibalization as well. For now, however, Southeast Europe has a much greater concentration of solar generation during daytime hours than wind generation across the same period. The marginal wind project therefore offers a production profile that is less correlated with the region’s most oversupplied hours, giving it increasing strategic value in a market dominated by photovoltaic growth.
Wind is currently capturing materially more market value than solar. ENTSO-E’s market-value indicators provide a structural benchmark. For the period from June 1, 2025, to June 1, 2026, the calculated wind capture price reached €108/MWh in Croatia, €107/MWh in Bulgaria, €105/MWh in Romania and €88/MWh in Greece. The equivalent photovoltaic values were €69/MWh, €57/MWh, €58/MWh and €43/MWh, respectively.
Wind’s profile value was therefore between €39/MWh and €50/MWh higher than solar’s across the four markets. ENTSO-E concluded that wind experienced less price cannibalization than photovoltaics during the measurement period. The indicators do not account for annual wind yields, capital costs or site-specific resource quality and should not be interpreted as project-level returns. They nevertheless demonstrate that the regional market is currently placing a higher value on the timing of wind generation.
This is changing the investment conversation. Solar may remain faster and, in many cases, simpler to develop, but wind can provide a stronger capture profile, seasonal diversification and a natural hedge against portfolios dominated by daytime photovoltaic output. As solar penetration increases, the value of complementary generation profiles is becoming increasingly important for developers, corporate buyers and power traders.
Romania is providing the clearest evidence of capital shifting toward wind. Rapid improvements in solar permitting have shortened development timelines and contributed to a growing supply of photovoltaic projects. Industry participants increasingly describe the solar market as becoming more favorable to buyers, while competition for wind assets is intensifying. The Romanian government has also adjusted renewable auction allocations to direct more support toward wind projects.
That shift does not mean Romanian wind development is straightforward. Wind projects generally face longer environmental, planning and grid-connection processes than solar facilities. Grid congestion remains a major obstacle, while the transition toward auction-based grid-capacity allocation is expected to increase the importance of financial guarantees, project maturity and deliverable connection rights.
Corporate procurement is nevertheless creating new routes to market. In March, Rezolv Energy signed a ten-year virtual power purchase agreement under which a Bulgarian industrial consumer will procure power associated with the 461 MW Vifor wind farm in Romania. The buyer already had a Bulgarian solar PPA and added wind to improve the balance of its renewable electricity supply. The transaction was described as Bulgaria’s first publicly announced cross-border wind PPA.
One contract does not create a liquid regional market. It does, however, validate a potentially important model: companies in solar-heavy markets can contract wind generation across national borders to reduce hourly concentration and improve the overall coverage of their renewable electricity procurement. The growing appeal of this model reflects the increasing value of portfolio diversification rather than single-technology procurement.
Bulgaria illustrates the gap between wind development potential and deliverable capacity. The country’s wind industry reports a development pipeline of approximately 4 GW, with some projects already at advanced stages of development and financing. The industry expects around 200 MW to become operational by the end of 2027 and believes that at least half of the current pipeline could be completed by 2030.
The conversion process remains slow. Bulgarian wind projects typically require four to five years to reach ready-to-build status. Industry representatives have cited slow permitting reforms and limited institutional support and have called for contracts for difference to provide a more predictable route to market.
The pipeline should therefore not be treated as imminent supply. The slow conversion of announced projects into operating wind farms is itself part of the reason why wind retains scarcity value. The assets likely to attract the strongest investor demand are those that already have environmental approvals, secure land rights, grid capacity and a credible PPA or support mechanism.
Greece is advancing offshore wind while leaving curtailment risk with investors. The country delivered the region’s most important offshore-wind policy development in July when a ministerial decree increased planned offshore capacity to 2.35 GW, compared with 1.9–2 GW in the national energy plan, and assigned capacity to individual zones.
The plan includes 600 MW of pilot projects off Thrace, 250 MW near Crete, 500 MW around the Dodecanese, 500 MW around the Cyclades and the Gulf of Euboea, and 200 MW in the Gulf of Patras. Grid-connection points were also identified, providing greater clarity for future development.
Most projects are expected to compete for contracts for difference, while the 600 MW pilot tranche would receive feed-in tariffs. However, the government did not grant offshore projects specific protection against curtailment. They will be subject to the same general curtailment framework as other renewable generators.
The decree is therefore primarily a policy and market-design signal, rather than a near-term addition to supply. Surveys, auction preparation, permitting, grid investment and construction remain ahead. The absence of specific curtailment protection is particularly important for capital-intensive offshore projects, as bidders will need to incorporate that risk into required returns, financing structures and auction offers.
Türkiye provides the region’s scale and financing benchmark. In July, the government announced a 2.4 GW renewable-energy auction round, of which 1.5 GW is reserved for seven wind projects. Bids are scheduled for October 13. As of May, Türkiye had 15.1 GW of wind and 26.9 GW of photovoltaic capacity connected to the grid.
Financing activity shows that auction-backed wind projects can still move from award to construction. FMO and Germany’s DEG agreed to provide Enerjisa Üretim with a $180 million financing package for three wind farms totaling 250 MW in Muğla. The projects are already under construction and are scheduled to begin operating during 2026. The financing has an eight-year tenor and supports projects awarded under the YEKA state-support mechanism.
Türkiye’s model cannot be directly transferred to every Southeast European market. It nevertheless illustrates what smaller markets often lack: recurring auction volumes, predefined grid locations, an industrial-scale development pipeline and financing structures capable of moving awarded capacity into construction. These factors help explain why market design and execution capacity can be just as important as the underlying wind resource.
Western Balkan grid constraints are reinforcing the premium for mature projects. In the Western Balkans, wind growth remains closely linked to transmission policy and grid availability. Serbia’s decision not to process connection-study applications for large new wind and solar projects until 2029 materially slows the next development cycle.
Because wind projects already have longer lead times than photovoltaic facilities, such delays are particularly significant. The likely commercial result is a widening valuation gap between early-stage development pipelines and projects that already hold advanced permits or grid rights.
Acquiring a nominal megawatt of planned wind capacity is therefore becoming increasingly different from acquiring a project capable of entering construction. In a constrained grid environment, maturity, permitting status and connection rights can become more valuable than headline pipeline size.
Wind will continue to command strategic value, but capacity additions will remain uneven. Southeast European wind is well positioned to retain a profile advantage as long as solar capacity continues to expand faster than wind and storage. Corporate buyers are likely to increasingly combine the two technologies rather than choose between them, using solar for low-cost daytime electricity and wind to broaden hourly and seasonal renewable coverage.
A strong capture price, however, does not eliminate development risk. The near-term market is likely to favor permitted and grid-secured onshore projects, assets supported by contracts for difference or long-term PPAs, and cross-border structures connecting wind-rich markets with industrial demand elsewhere in the region.
Offshore wind offers significant strategic potential, but remains a longer-duration opportunity requiring policy stability, extensive survey work and major network investment. Its development timeline means that it is unlikely to solve Southeast Europe’s immediate flexibility challenge, but it could become an important part of the region’s longer-term renewable generation mix.
July’s central message for Southeast Europe’s wind market is therefore not that wind is replacing solar. It is that a solar-heavy electricity system is placing an increasing premium on renewable generation that arrives at a different time. Across the region, the commercial value of technological diversity is beginning to appear directly in capture prices, contracting strategies, project valuations and investor demand.
