The European Commission set the third-quarter 2026 CBAM certificate price at €82.32 per tonne of CO₂, up 9.4% from €75.28 in the second quarter. The change affects how costs are calculated when EU importers rely on default embedded-emissions values for electricity.
Using Serbia’s applicable electricity default factor of 1.041 tCO₂/MWh, the new certificate price implies an indicative CBAM burden of about €85.70 per MWh where the default value is applied. In the second quarter, the same approach resulted in roughly €78.37/MWh, a rise of more than €7/MWh over three months.
Default CBAM cost enters cross-border electricity pricing
For Serbian electricity traders, CBAM is increasingly treated as part of the cross-border price calculation rather than a separate compliance item. An export deal that appears profitable when comparing Serbian and EU wholesale prices can become uneconomic after adding the default carbon cost.
At the Q3 certificate price, an exporter or EU buyer using the national default starts from an indicative carbon disadvantage of around €85.70/MWh. The figure is described as large relative to normal wholesale-market spreads.
The higher implied cost does not mean all Serbian electricity physically carries emissions at that level. Serbia’s generation mix includes hydro, wind and solar alongside lignite-fired production.
Actual-emissions claims depend on a qualifying evidence chain
The key issue for renewable generators is methodological: unless conditions for using actual emissions are met, CBAM applies the prescribed default value rather than automatically recognising plant-specific emissions for wind or solar assets. As EU carbon prices rise, the ability to qualify for actual-emissions treatment becomes more commercially significant.
A wind farm cannot replace the national default simply by demonstrating it produces renewable electricity. The EU framework requires a stronger evidence chain tied to the specific transaction and installation.
Electricity claimed under actual emissions must be supported by a qualifying power purchase agreement between the authorised CBAM declarant and the third-country producer. The generating installation must meet relevant emissions thresholds and physical network conditions, while electricity must be firmly nominated to allocated cross-border capacity with nomination and production matched within no more than one hour.
Compliance must be certified by an accredited verifier, supported by interim evidence during the reporting period. The operational chain increasingly involves named installation, meter and SCADA data, hourly generation, PPA allocation, accepted nomination, cross-border evidence, EU declarant submission and accredited verification.
Hourly records and trading documentation affect access to actual emissions
The commercial value for renewable producers depends not only on low-carbon generation but also on preserving evidence needed to show that claimed electricity came through a qualifying transaction. Verification is therefore described as becoming a revenue issue for wind and solar projects.
If a producer fails to preserve necessary hourly meter records, nominations or contractual allocation, it could lose access to actual emissions and expose its EU buyer to the higher Serbian default. The higher Q3 certificate price increases the economic consequences of such failures.
Meter hierarchy, SCADA-to-settlement reconciliation, calibration records and hourly production data are therefore treated as revenue-supporting information rather than only technical documentation. Trading records face similar requirements, including demonstrating that nominated cross-border quantities correspond with output from the named installation during the required hourly interval.
Reconstructing that evidence months later may be difficult. For projects aiming to use actual emissions for 2026 imports, preserving the complete evidence chain during 2026 is increasingly important.
CBAM-oriented power purchase agreements and risk allocation
The carbon-price increase also strengthens the case for changing how renewable PPAs are drafted. A conventional PPA typically focuses on price, volume, profile, balancing, settlement and guarantees of origin.
A CBAM-oriented agreement needs additional controls covering plant identification, allocation of qualifying volumes, EU declarant identification, access to meter and nomination information, verifier cooperation, data-retention requirements and provisions preventing double counting. The agreement should also specify what happens if electricity fails the actual-emissions test.
If contract pricing assumes low or near-zero plant-specific emissions but verification fails and the importer must use Serbia’s default, carbon exposure could become material. The parties therefore need to determine contractually who carries fallback risk when actual-emissions conditions are not met.
Guarantees of origin are separate from CBAM verification
The rising CBAM price reinforces a distinction between guarantees of origin and actual-emissions verification under CBAM rules. A Serbian wind or solar generator may issue renewable certificates linked to its production.
The certificates can carry commercial value and could become more valuable if EU recognition of Energy Community guarantees of origin expands. However, a guarantee of origin does not replace physical electricity evidence required under CBAM for claiming actual emissions.
A guarantee establishes a renewable attribute but does not by itself establish the PPA terms, transmission conditions, cross-border nomination or hourly matching needed for actual-emissions claims for imported electricity. Projects may therefore sell two distinct environmental products: a renewable attribute and a CBAM-verifiable electricity transaction.
Industrial buyers seek evidence for downstream carbon reporting
The same compliance-driven incentive applies to Serbian industrial companies purchasing renewable electricity while exporting CBAM-covered goods into the EU. Industrial buyers increasingly want PPAs that reduce both electricity-price exposure and production-related carbon footprint.
A generic green-electricity contract may not provide evidence needed for regulatory actual-emissions claims under CBAM methodology. Buyers are expected to seek access to meter data, production allocation and verification documentation when renewable procurement is intended to support downstream carbon reporting.
This could support a domestic market for CBAM-ready renewable electricity supply among steel, aluminium and other energy-intensive exporters. Generators able to provide electricity together with controlled evidence could hold a different commercial position from suppliers selling only power and certificates.
Carbon-price volatility links ETS auctions to cross-border economics
The change also matters for project financing because developers have traditionally modelled revenue around wholesale prices, PPA prices, balancing costs, curtailment and guarantees of origin. CBAM adds another possible source of value through potential avoidance of default carbon charges approaching €86/MWh.
The value would be divided among producers, traders, transmission capacity holders and buyers while verification and compliance carry costs. For lenders, support for actual-emissions claims can become part of route-to-market due diligence where project revenue assumptions depend on EU electricity exports.
The Commission calculates CBAM certificate prices from EU ETS auction prices. For 2026 they are set quarterly; from 2027 the calculation moves to a weekly basis.
This means carbon-price volatility will increasingly be embedded in cross-border electricity economics. For exports relying on default emissions it directly increases effective costs reaching the EU market; for wind and solar plants capable of satisfying actual-emissions methodology it can increase relative value of verified low-emission electricity.
The Commission confirms Q3’s €82.32/tCO₂ price versus €75.28 in Q2. Serbia’s applicable default factor remains 1.041 tCO₂/MWh, with Q2 comparisons supported by Energy Community CBAM monitoring while current EU regulation retains physical PPA requirements, network conditions, nomination rules, hourly-matching obligations and accredited-verifier certification for actual electricity emissions.
