The European Commission has set the third-quarter 2026 CBAM certificate price at €82.32 per tonne of CO₂, up from €75.28 in the second quarter. The change represents a 9.4% increase quarter-on-quarter. For Serbia, the calculation uses a default electricity emissions factor of 1.041 tCO₂/MWh.
Using that default factor, the new certificate price implies an indicative CBAM burden of about €85.70/MWh for each imported megawatt-hour where the default value applies. In the second quarter, the same approach produced roughly €78.37/MWh. The difference is more than €7/MWh over three months.
The higher Q3 price affects how Serbian renewable electricity may qualify under the EU’s actual-emissions methodology. It also sharpens a commercial distinction between electricity exported under default assumptions and electricity supported by a verifier-ready chain linking a renewable installation to an EU buyer.
Default CBAM cost added to cross-border electricity pricing
For Serbian electricity traders, CBAM is increasingly treated as part of cross-border pricing rather than as a separate compliance item. An export deal that appears profitable when comparing Serbian and EU wholesale prices can become uneconomic once the default carbon cost is included. At the Q3 certificate level, relying on the national default starts from an indicative disadvantage of around €85.70/MWh.
The size of that indicative burden is described as large relative to typical wholesale-market spreads. The figures do not indicate that all Serbian electricity physically carries those emissions values. Serbia’s generation mix includes hydro, wind and solar alongside lignite-fired production.
The issue for individual renewable generators is methodological: unless conditions for using actual emissions are satisfied, CBAM applies the prescribed default value instead of recognising plant-specific emissions from a wind or solar asset. As EU carbon prices rise, this difference between default use and actual-emissions qualification becomes more commercially significant.
Actual-emissions claims require a qualifying evidence chain
A Serbian wind farm cannot replace the national default simply by demonstrating that it produces renewable electricity. Under the EU framework, claiming actual emissions requires a stronger evidence chain than renewable origin alone. 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 threshold and physical network conditions. The electricity also has to 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 sequence increasingly depends on maintaining records across multiple steps: named installation; meter and SCADA; hourly generation; PPA allocation; accepted nomination; cross-border evidence; EU declarant; and accredited verifier. For renewable generators, maintaining this evidence is described as important not only for producing low-carbon electricity but for proving that specific claimed megawatt-hours came through a qualifying transaction.
Verification failures can expose buyers to higher default charges
The pre-verification process is described as turning into a commercial exercise for market participants. If a wind or solar producer does not preserve required hourly meter records, nominations, or contractual allocation, it could lose access to actual emissions qualification. In that case, its EU buyer could face exposure to the higher Serbian default.
The Q3 certificate price increase raises the economic consequences of such failures. Meter hierarchy, SCADA-to-settlement reconciliation, calibration records, and hourly production data are therefore positioned as revenue-supporting information rather than purely technical documentation. Trading records are also relevant to demonstrating that nominated quantities correspond to output from the named installation during required hourly intervals.
Reconstructing missing evidence months later may be difficult, particularly for projects aiming to use actual emissions for 2026 imports. Preserving the complete evidence chain during 2026 is therefore presented as increasingly important for those transactions.
CBAM-focused PPAs and guarantees of origin treated separately
The carbon-price increase also strengthens the case for changes in how renewable PPAs are drafted for CBAM purposes. A conventional PPA typically covers price, volume, profile, balancing, settlement and guarantees of origin, while CBAM-oriented agreements require additional controls. These can include 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.
An agreement also needs provisions on 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 this fallback risk.
The rising CBAM price also reinforces separation between guarantees of origin and actual-emissions verification under CBAM rules. A Serbian wind or solar generator may issue renewable certificates associated with production that can carry commercial value. However, guarantees of origin do not replace physical-electricity evidence needed under CBAM.
Industrial buyers seek evidence-backed renewables for EU reporting
The same evidence requirements affect 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.
Buyers are described as seeking 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 supply electricity together with controlled evidence could command a different commercial position from suppliers selling only power and certificates. Higher carbon prices are also linked in financing discussions to improved bankability where projects can deliver verifier-ready electricity to an EU buyer.
Carbon-price volatility embedded in cross-border electricity economics
The European Commission calculates CBAM certificate prices from EU ETS auction prices: they are set quarterly for 2026 and move to weekly calculation from 2027. This schedule means carbon-price volatility will become increasingly embedded in cross-border electricity economics over time.
For exports relying on default emissions values, higher EU ETS prices directly increase effective costs of reaching the EU market. For wind and solar plants able to satisfy actual-emissions methodology conditions, rising carbon prices can increase relative value of verified low-emission electricity.
The Q3 increase is described as sending a broader market signal by dividing Serbian electricity exports according to evidence quality behind them. With Q3 certificates at €82.32/tCO₂, that distinction already corresponds to an indicative default burden of around €85.70/MWh. Verifying origin and physical trading-chain details for each megawatt-hour becomes almost as important as generation itself.
The Commission confirms Q3’s €82.32/tCO₂, compared with €75.28 in Q2. Serbia’s applicable default remains 1.041 tCO₂/MWh, with Q2 comparisons supported by Energy Community CBAM monitoring data. Current EU regulation retains requirements covering physical PPA arrangements, network conditions, nomination timing and hourly matching, alongside accredited-verifier certification for actual-electricity emissions claims.