Serbia’s planned coupling with the European Union electricity market is now more likely to occur in the first quarter of 2029 rather than the early 2028 timetable. SEEPEX executive director Miloš Mladenović said the first quarter of 2029 is a more realistic schedule for the process. He described the change as pushing coupling back by about a year from the earlier 2028 target.
The delay affects how cross-border capacity is used and how prices align with neighbouring EU markets. It also shapes whether electricity flows across borders rely on separate auction arrangements instead of a coupled approach. For Serbia, the timing has become more relevant as wind, solar and battery projects move forward.
Renewables and storage pipeline increases demand for wider market access
Serbia has around 11 GW of wind and solar projects in the transmission connection process. EMS has signed connection contracts covering roughly 2 GW of battery storage. This pipeline increases the need for access to a larger regional market that can absorb surplus generation and balance intermittent output.
As coupling timing shifts, the period before full EU market integration extends for Serbian generators and traders. That longer interval coincides with growing renewable and storage development connected to transmission upgrades. The interaction between project build-out and market integration becomes a key operational factor for cross-border electricity activity.
CBAM implications for electricity trade and compliance timelines
The timetable also carries implications for the EU’s Carbon Border Adjustment Mechanism (CBAM). Electricity imported into the EU from non-member countries is covered by CBAM, with only limited routes toward exemption for markets that achieve deep integration with the EU electricity system and meet regulatory conditions. Market coupling is identified as one core element in that integration process.
Serbia has transposed significant parts of the EU electricity package and is moving through Energy Community verification and market-reform procedures. However, moving from 2028 into 2029 reduces time before the 2030 CBAM review horizon. During this extended period, Serbian exporters are expected to manage carbon-related evidence, importer obligations and cross-border commercial risk without full benefits from market integration.
The CBAM-related effects differ across generation types. For lignite-heavy production, CBAM creates a carbon-cost disadvantage. For renewable power, lower actual emissions treatment depends on contractual, metering and verification evidence rather than physical low-carbon output alone.
Higher trading risk under delayed coupling
Delayed coupling keeps Serbia’s power market structure more fragmented for traders. Serbia remains exposed to separate cross-border capacity allocation, basis risk between SEEPEX and neighbouring exchanges, and periods when congestion prevents price convergence. While such conditions can create trading opportunities, they also increase hedging and scheduling risk.
As Serbia expands interconnection capacity and develops new transmission corridors, the commercial value of those investments depends on whether regulatory alignment and market-coupling arrangements keep pace. A stronger grid can improve physical security but may leave part of the economic value of integration unrealised if coupling does not arrive on schedule.
The same pattern applies to storage projects. Batteries are described as becoming more valuable when they can respond to regional price differences and balancing needs across a deeper market. Delayed integration limits that optionality and keeps project revenues more dependent on Serbia’s domestic market structure.
Execution speed becomes central as CBAM obligations already affect trade
The main risk highlighted is no longer a lack of legal framework or political intent to integrate. Instead, execution speed is presented as the key issue as transmission upgrades, regulatory alignment, verification procedures and market-coupling arrangements need to progress in parallel. CBAM obligations are already affecting electricity trade during this transition period.
This narrows the margin for further delay beyond 2029. The sector is adding renewable capacity and storage faster than it is integrating with the export-relevant market structure. If coupling slips further beyond 2029, costs are expected to appear through wider basis risk, more complex CBAM compliance requirements, and a weaker commercial route for generation Serbia is building for exports.