Serbia’s electricity exporters face a potential carbon cost approaching €86 per megawatt-hour under the European Union’s Carbon Border Adjustment Mechanism (CBAM), threatening traditional trading margins with Hungary and creating new financing risks for renewable energy projects seeking access to European markets.
The new regime is changing the economics of Serbia’s electricity industry. Wholesale power prices, cross-border transmission capacity and generation costs are no longer sufficient to determine export competitiveness. The carbon classification of electricity, its contractual delivery arrangements and independently verified emissions have become additional commercial factors.
Serbia’s national CBAM electricity default factor stands at 1.041 tonnes of CO₂ per MWh, reflecting the country’s carbon-intensive thermal generation system.
At the EU’s third-quarter 2026 CBAM certificate price of €82.32/tCO₂, this translates into an indicative gross carbon liability of €85.70/MWh for electricity imported into the EU using Serbia’s default factor.
The calculation illustrates the exposure at the third-quarter certificate price, rather than establishing the charge for October deliveries, which will use the fourth-quarter price. Eligible carbon costs already paid in the country of origin may also reduce the final liability.
Unlike steel and aluminium, imported electricity receives no free-allocation adjustment under CBAM, making its carbon exposure particularly significant during the initial implementation period.
The immediate commercial consequences are visible in the relationship between Serbia’s SEEPEX electricity exchange and Hungary’s HUPX market.
For October 9 delivery, SEEPEX day-ahead prices rose to €239.96/MWh, compared with €269.43/MWh in Hungary. The resulting €29.47/MWh price difference was substantially below the indicative Serbian CBAM charge.
A conventional electricity export from Serbia to Hungary assessed under national default emissions would therefore struggle to generate a positive trading margin at those average prices, even before transmission capacity, balancing and transaction costs.
Hourly price differences, contractual positions and verified actual emissions can produce different outcomes, but the broader market implication is increasingly clear: higher Hungarian wholesale prices no longer automatically create profitable export opportunities for Serbian electricity.
The Energy Community Secretariat has already documented changes in regional trading patterns following CBAM’s introduction. Commercial electricity exchanges between Western Balkan markets and neighbouring EU countries declined in early 2026, although hydrological conditions, generation availability and changing demand also influenced flows.
Serbia nevertheless remains an important northern trading corridor. Scheduled electricity exports towards Hungary increased during the second quarter, demonstrating that CBAM has not eliminated cross-border trading but has changed the economics and potential destinations of electricity flows.
For Elektroprivreda Srbije (EPS), the implications extend beyond individual export transactions.
Serbia’s dependence on lignite-fired generation exposes electricity sold under the national default methodology to high carbon costs. This weakens the attractiveness of exports into EU markets and increases the importance of domestic electricity sales, generation flexibility and low-carbon investment.
For independent electricity producers, however, CBAM creates a different challenge.
A Serbian wind or solar farm may generate electricity with minimal operational emissions, but its EU customer cannot automatically claim those emissions merely because the electricity originates from a renewable installation.
Using actual emissions requires a qualifying physical power purchase agreement involving the EU declarant and producer, evidence of a compliant transmission route, cross-border capacity nominations aligned with generation within hourly intervals, and independent verification. The generating installation must also satisfy the applicable emissions threshold.
Guarantees of Origin alone are insufficient to establish eligibility for actual-emissions treatment.
Consequently, two Serbian renewable projects with similar technology, generation costs and expected production could have substantially different export values depending on whether their contractual and metering arrangements support CBAM-compliant deliveries.
This introduces a new consideration for banks financing wind, solar and battery storage projects.
Traditional project-finance assessments concentrate on construction costs, production forecasts, wholesale power prices, balancing exposure and the creditworthiness of electricity buyers. CBAM adds risks involving verified emissions, contractual eligibility, export-market access and the durability of projected cross-border revenues.
Banks should therefore assess renewable projects under separate revenue scenarios: domestic market sales, conventional EU exports using applicable defaults, and qualifying exports supported by verified actual emissions.
Existing loans may also require reassessment where debt-service projections depend on electricity premiums available in Hungary or other EU markets.
For Serbia’s steel, aluminium, cement and fertiliser manufacturers, electricity creates another layer of exposure.
Expensive electricity increases production costs directly. However, CBAM does not currently treat purchased-electricity emissions identically across industrial sectors. Indirect electricity emissions are included in the CBAM calculations for cement and fertilisers, while current iron, steel and aluminium obligations generally focus on direct embedded emissions.
Renewable electricity procurement can therefore improve manufacturing competitiveness and customer acceptance without necessarily reducing the immediate CBAM certificate liability of every Serbian industrial exporter.
The European Commission is considering amendments to electricity CBAM methodology that could improve recognition of lower-carbon generation, but investment decisions cannot assume those changes will be adopted in their proposed form.
For Serbia, the emerging challenge is to connect electricity generation, trading infrastructure and verifiable carbon data into a commercially credible export product.
The country has the generation potential, regional interconnections and expanding renewable portfolio to remain an important electricity supplier. Whether its producers can capture European market premiums will increasingly depend on their ability to demonstrate precisely which power plant produced the electricity, when it was generated, how it crossed the border and which EU importer is entitled to claim its emissions.
Without that evidence, even competitively priced Serbian renewable electricity risks being valued at the EU border as if it carried the carbon intensity of the wider national power system.