Serbian electricity exporters are facing a potential carbon cost approaching €86 per megawatt-hour under the European Union’s Carbon Border Adjustment Mechanism (CBAM). The exposure is linked to how electricity is classified for CBAM purposes and how emissions are verified for cross-border deliveries. The change affects trading economics with Hungary and introduces financing considerations for renewable projects targeting European buyers.
Wholesale power prices, cross-border transmission capacity and generation costs are no longer the only determinants of export competitiveness. Under CBAM, the carbon classification of electricity, contractual delivery arrangements and independently verified emissions have become additional commercial factors. This shifts how market participants assess whether exports can sustain margins after carbon-related charges.
CBAM default factor and indicative carbon liability for Serbian electricity
Serbia’s national CBAM electricity default factor is set at 1.041 tonnes of CO2 per MWh. Using the EU’s third-quarter 2026 CBAM certificate price of €82.32/tCO2, the calculation yields an indicative gross carbon liability of €85.70/MWh for electricity imported into the EU under the default factor. The figure illustrates exposure at the third-quarter certificate price.
The calculation is presented as exposure at the third-quarter certificate price rather than as a charge for October deliveries. October deliveries will use the fourth-quarter certificate price. Eligible carbon costs already paid in the country of origin may also reduce the final liability.
Imported electricity does not receive a free-allocation adjustment under CBAM. This makes carbon exposure particularly significant during the initial implementation period compared with sectors that receive different treatment.
SEEPEX-HUPX price gap and implications for export margins
The immediate commercial effects are reflected in trading between Serbia’s SEEPEX exchange and Hungary’s HUPX market. For October 9 delivery, SEEPEX day-ahead prices rose to €239.96/MWh. Hungary’s comparable HUPX level was €269.43/MWh.
The resulting price difference was €29.47/MWh, which was substantially below the indicative Serbian CBAM charge calculated using the default factor and third-quarter certificate price. A conventional 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 lead to different outcomes than those implied by averages. Even so, regional market dynamics show that higher Hungarian wholesale prices do not automatically translate into profitable export opportunities for Serbian electricity once CBAM exposure is considered.
Regional trading pattern changes documented by Energy Community Secretariat
The Energy Community Secretariat has documented changes in regional trading patterns after CBAM entered implementation. Commercial electricity exchanges between Western Balkan markets and neighbouring EU countries declined in early 2026. Hydrological conditions, generation availability and changing demand also influenced flows during that period.
Serbia remains an important northern corridor for power flows into the EU region. Scheduled exports towards Hungary increased during the second quarter, indicating that cross-border trading continued while CBAM altered the economics and potential destinations of electricity deliveries.
Impact on EPS lignite generation and on independent renewables
For Elektroprivreda Srbije (EPS), CBAM implications extend beyond individual export transactions. Serbia’s reliance on lignite-fired generation exposes electricity sold under the national default methodology to high carbon costs. This increases the importance of domestic sales, generation flexibility and investment in lower-carbon capacity.
Independent producers face a different compliance challenge when seeking CBAM treatment based on actual emissions. A Serbian wind or solar installation may generate with minimal operational emissions, but an EU customer cannot claim those emissions automatically due to renewable origin alone.
Actual-emissions treatment requires a qualifying physical power purchase agreement involving an EU declarant and producer, evidence of a compliant transmission route, and cross-border capacity nominations aligned with generation within hourly intervals. Independent verification is also required, and the generating installation must meet the applicable emissions threshold.
Guarantees of Origin alone are insufficient to establish eligibility for actual-emissions treatment under CBAM electricity rules. As a result, two Serbian renewable projects with similar technology, costs and expected output could receive substantially different export values depending on whether their contractual terms and metering arrangements support CBAM-compliant deliveries.
Banks’ project-finance risk review for wind, solar and storage
The compliance requirements introduce additional considerations for banks financing wind, solar and battery storage projects in Serbia. Traditional project-finance assessments focus on construction costs, production forecasts, wholesale power prices, balancing exposure and buyer creditworthiness. Under CBAM, risks also include verified emissions, contractual eligibility, access to export markets and the durability of projected cross-border revenues.
Banks are expected to evaluate 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.
Electricity cost exposure for industrial sectors using purchased power
For Serbia’s steel, aluminium, cement and fertiliser manufacturers, electricity adds another layer of exposure through production costs when power prices rise. The CBAM framework does not currently treat purchased-electricity emissions identically across industrial sectors in how obligations are calculated.
Indirect electricity emissions are included in CBAM calculations for cement and fertilisers. By contrast, current iron, steel and aluminium obligations generally focus on direct embedded emissions rather than purchased-electricity emissions treated in the same way across all cases.
Renewable electricity procurement can improve manufacturing competitiveness and customer acceptance without necessarily reducing immediate CBAM certificate liability for 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 as proposed.
Requirements to document generation-to-border-to-importer claims
For Serbia’s exporters, a key operational challenge is linking generation data, trading infrastructure and verifiable carbon information into a commercially credible export product under CBAM rules. The ability to capture European market premiums depends on demonstrating which power plant produced each unit of electricity, when it was generated, how it crossed the border and which EU importer is entitled to claim its associated emissions.
Without that evidence, competitively priced Serbian renewable electricity risks being valued at the EU border as if it carried the carbon intensity of Serbia’s wider national power system under default assumptions.
