Serbia has demonstrated that large-scale wind projects can be built, financed and connected to the electricity system. The next challenge is managing what happens after those turbines begin participating in the market.
The inauguration of Čibuk 2 in September 2026 added 154 MW to the existing 158 MW Čibuk 1, creating a combined 312 MW wind complex in South Banat. Together, the two projects represent more than €500 million in investment.
Serbia’s wider renewable-energy auction programme has also attracted significant capital. According to the EBRD, the first two competitive auctions allocated nearly 1,300 MW of wind and solar capacity, including the Pupin and Čibuk 2 wind projects.
This marks an important shift in the market.
During the first generation of Serbian wind development, the central questions were whether projects could overcome permitting, financing and grid-connection barriers. As the installed fleet grows, however, the focus is moving increasingly towards operational performance and market exposure.
Wind generation must be forecast before electricity is delivered. The balancing responsible party then carries the difference between the nominated position and actual production under the applicable market rules.
EMS reports an average upward balancing-energy price used for specified risk and settlement calculations of €154.174/MWh for 2026, compared with €136.523/MWh in 2025. The figure should not be interpreted as the automatic imbalance cost faced by every wind project, but it illustrates why deviations between forecast and actual generation can have meaningful financial consequences.
A wind farm can therefore meet its annual production forecast and still underperform financially.
If hourly output repeatedly differs from the nominated schedule, the resulting balancing exposure can reduce project cash flow even when total annual generation is exactly in line with the original financing case.
This makes forecasting a commercial function, rather than simply a technical exercise.
Weather forecasting, turbine-level production models, real-time SCADA data and intraday trading capabilities can all influence the final revenue captured by a project. The closer a trader can bring the nominated position to expected actual production before gate closure, the lower the remaining imbalance exposure is likely to be.
Portfolio management can provide another layer of protection.
Combining several renewable assets can reduce forecast errors when deviations from individual projects offset one another. However, that benefit depends heavily on the physical correlation between the assets.
Wind farms operating within the same meteorological region can experience similar deviations at the same time, limiting the diversification benefit. Serbia’s concentration of significant wind capacity in Vojvodina makes this issue particularly relevant as the country’s wind fleet expands.
Balancing responsibility therefore needs to be examined carefully at the contract level.
Project owners need to know who submits nominations, who controls the forecasting model, who has authority to trade in the intraday market, who pays when actual production differs from the nominated position and how balancing costs are ultimately divided between the generator and the trader.
Those provisions can materially change the economics of apparently similar PPAs.
Transparency becomes particularly important when a third-party trader or balancing responsible party manages market settlement. A wind project owner should be able to reconstruct the complete chain from the initial forecast and nomination through measured production and final balancing settlement.
Without that visibility, imbalance can become a significant commercial cost that is difficult for the asset owner to monitor or audit.
At the same time, the increasing sophistication of Serbia’s electricity market could create new opportunities.
EMS procures ancillary services and operates balancing arrangements that include frequency-related reserves and balancing activation. For wind projects combined with storage, flexible generation or capable aggregators, this creates the possibility of moving beyond simply creating balancing requirements and towards providing some of the flexibility needed to manage them.
Realising that opportunity will require technical qualification, appropriate control systems and clear market rules.
It will also require a different approach to project financing.
Balancing costs can no longer necessarily be treated as a small and generic operating assumption. Lenders may increasingly need to examine historical forecast-error distributions, trading arrangements, the quality of the forecasting provider and the contractual allocation of imbalance costs.
Stress testing should also consider periods when several adverse factors occur simultaneously.
A wind farm could experience lower-than-forecast production at the same time that upward balancing energy becomes expensive. Conversely, unexpectedly high generation could occur during a period of regional oversupply, when wholesale electricity prices are weak.
This creates an asymmetric market risk for wind projects.
The importance of market integration will therefore increase alongside installed capacity.
Serbia has already demonstrated that wind projects can attract international investors, substantial capital and non-recourse financing. The next competitive advantage will come from operating those assets efficiently within a more liquid, volatile and increasingly interconnected regional electricity market.
The challenge is no longer simply to make the turbines turn.
It is to turn variable electricity generation into predictable and resilient cash flow.
