South East Europe is in the middle of a renewable-energy acceleration. Solar projects are being announced across Greece, Romania, Bulgaria, Serbia, Montenegro, North Macedonia, Albania and beyond. Wind pipelines are expanding. Developers, utilities, banks and governments are all positioning for a cleaner power system.
But the region’s renewable boom has a problem: generation capacity is moving faster than grid capacity, flexibility and market design.
The clearest example is solar. ACER reports that solar PV capacity in selected South East European EU markets reached about 29 GW in 2025, transforming the region’s electricity supply structure. The same analysis notes that the power system has become increasingly reliant on variable renewable generation while dispatchable capacity has not increased at the same pace.
That imbalance is already changing prices. Solar reduces prices during the central hours of the day. But in the evening, when solar output falls and demand remains high, the system requires flexible generation, storage, imports or demand response. Without enough flexibility, prices can spike and balancing costs can rise.
The Western Balkans show the scale of the opportunity — and the execution gap. Global Energy Monitor, REScoop.eu and CEE Bankwatch found that the Western Balkans had more than 23 GW of prospective utility-scale solar and wind projects in 2024, almost 70% more than a year earlier. But the operating utility-scale solar and wind fleet was only about 1.5 GW, with another 1.3 GW under construction.
That difference between announced capacity and buildable capacity is crucial. A project pipeline is not the same as an investable market. Many projects still need permits, land agreements, grid-connection rights, financing, offtake structures and bankable curtailment assumptions. In several SEE markets, the bottleneck is no longer developer appetite. It is whether projects can actually connect and operate profitably.
Serbia is a good example. The GEM-led report found that Serbia accounted for the largest share of prospective utility-scale solar and wind capacity in the Western Balkans, with 47% of the regional prospective pipeline. But a large pipeline also means sharper competition for grid access, stronger pressure on permitting authorities and higher risk that not every announced project will be built.
This is why the next phase of the renewable market will not be only about megawatts. It will be about quality of megawatts. A solar project with poor grid access, high curtailment exposure and no hedge may be less valuable than a smaller hybrid project with storage, a corporate PPA and access to balancing revenues.
Storage is therefore moving from optional extra to strategic necessity. Batteries can absorb excess solar generation, discharge during evening peaks, reduce imbalance exposure and provide ancillary services. Pumped hydro, where available, can play a similar system role at larger scale. Demand response can also become more valuable, particularly for industrial consumers able to shift load away from evening scarcity periods.
Wind has a complementary role. In markets becoming saturated with daytime solar output, wind projects with stronger winter, evening or night production profiles may achieve better capture prices than standalone solar. The best portfolios will combine technologies rather than simply maximise installed capacity.
For lenders and investors, the renewable question in South East Europe is changing. It is no longer: “Is there enough sun or wind?” There is. The better question is: “Can the project secure grid access, manage curtailment, control imbalance costs, hedge revenue and monetise flexibility?”
The region’s renewable buildout is real. But the winners will be developers that understand the difference between a renewable-energy boom and a bankable renewable-energy system.
