The European Union’s Carbon Border Adjustment Mechanism is starting to affect electricity flows in the Western Balkans before the region completes its shift away from coal. The mechanism is influencing how exported power is treated in relation to emissions characteristics associated with national grids. The transition is occurring while renewable investment accelerates.
North Macedonia illustrates the change most clearly, with developers advancing projects that could add 2.8 GW of low-carbon capacity. That figure is close to the country’s existing installed power capacity of roughly 3 GW. The pipeline includes Alcazar Energy’s 396 MW Štip wind project, a proposed 400 MW solar development by Akuo Energy, and a 414 MW wind project linked to WDP.
The stated objective for North Macedonia is to move from a long-standing net importer position to a net electricity exporter. The export strategy has economic relevance because about 77% of the country’s merchandise exports went to the EU in 2024. Low-carbon electricity availability is described as supporting industrial expansion, attracting foreign investment, and improving competitiveness for existing exporters.
North Macedonia export revenues and cross-border volume trends
CBAM adds constraints to that model by changing how exported electricity is valued when emissions are assessed through grid factors. Western Balkan cross-border electricity volumes reportedly fell by 19% in the first six months of 2026. In the same period, North Macedonia earned €36.8 million from electricity exports over the first five months.
If annualised mechanically, the figure would reach approximately €88.3 million. That level would be around 44.6% below the €159.3 million recorded in 2025. The reported decline aligns with reduced cross-border volumes during 2026.
Grid emission factors and evidence requirements for low-carbon claims
The central issue is how electricity is linked to national grid emission factors when it is exported. Even if a renewable plant produces low-carbon power physically, exported electricity can still be associated with the average emissions intensity of a coal-heavy system. Renewable generation can reduce national averages, but it may not eliminate commercial penalties while lignite generation remains in operation.
This creates a bankability challenge for projects seeking value from EU-bound exports. A wind or solar project developed partly for EU sales cannot depend only on a conventional power-purchase agreement. It requires credible evidence connecting generation, metering, scheduling, grid delivery, and the importing counterparty.
The commercial value increasingly depends on the quality of emissions and origin data attached to each delivery. The architecture needed goes beyond annual guarantees of origin. Exporters and industrial buyers require installation-level metering, time-correlated production and consumption data, transparent treatment of losses, validated contractual routes, and records showing that the same renewable attribute has not been allocated twice.
Without those controls, low-carbon claims may not pass importer review or third-party verification processes. The requirement increases the operational and documentation burden for projects intended to sell into CBAM-exposed industrial supply chains. It also affects how contractual arrangements are structured around measurement and allocation.
Regional coal mix influences how CBAM interacts with trading products
The implications extend beyond North Macedonia across multiple Western Balkan power systems. Serbia, Bosnia and Herzegovina, and Kosovo retain substantial coal generation. Montenegro has a lower-carbon mix but can still face periods when thermal output and imports influence grid intensity.
Albania benefits from hydropower but remains exposed to hydrological variation and imported electricity affecting grid conditions. Across the region, these differences shape how exported volumes may be treated under grid-linked emission factor approaches. As a result, trading arrangements are expected to separate into distinct categories.
Conventional wholesale electricity continues to be priced through market coupling, congestion conditions, and hourly supply patterns. In parallel, documented low-carbon electricity carries additional value tied to verified emissions characteristics and its relevance for CBAM-exposed industrial buyers. This separation reflects how documentation requirements interact with pricing.
Meters, data governance and contractual allocation as project infrastructure
The most competitive renewable developers are those that build the evidence chain alongside physical assets from the outset. Metering systems, data governance processes, and contractual allocation mechanisms are described as becoming part of project infrastructure rather than an afterthought. In Western Balkan electricity trade, a megawatt-hour is therefore defined not only by generation location and timing.
The definition also depends on what can be proven about emissions attributes through measurement and records. This shifts emphasis toward installation-level data handling and validated allocation procedures across cross-border deliveries into CBAM-relevant markets.