Proposed amendments to the European Union’s Carbon Border Adjustment Mechanism (CBAM) could expand the pathways available to renewable electricity exporters seeking recognition of actual emissions. The changes would aim to make multi-trader transactions easier to structure and reduce some evidence requirements, while leaving electricity producers and importers exposed to uncertainty about timing and final conditions.
As of October 2026, the definitive CBAM regime has been operating since January. At the same time, electricity-related amendments remain subject to the legislative process, meaning businesses must separate obligations currently in force from potential future benefits.
European Commission proposal on electricity methodology and trading arrangements
The European Commission’s proposal COM(2025) 989, presented in December 2025, combines measures covering downstream CBAM goods with anti-circumvention provisions. It also includes proposed changes focused on the electricity methodology used for CBAM-related calculations.
Under the electricity component, the proposal would broaden access to actual-emissions treatment. It would do so through adjustments covering contractual intermediaries and the physical-network congestion requirement, alongside a revision of the default emissions methodology.
The revised default approach would reflect a broader electricity generation mix rather than relying on fossil-fuel generation in the same way as the existing method described in the proposal. These elements are still proposals and do not yet give electricity exporters automatic eligibility for more favourable treatment.
Default emissions factors and potential effects on neighbouring markets
The proposed methodology could affect export economics for countries with significant hydropower, wind and solar generation. A default factor based on fossil-fuel generation may yield a relatively high emissions value compared with a country’s overall electricity output mix.
If adopted, a methodology based on a broader generation mix could narrow that gap and change carbon-cost assumptions used by electricity importers. It could also influence the relative commercial positions of independent power producers (IPPs), traders, and projects seeking installation-specific power purchase agreements.
The extent of any impact would depend on the final legislative wording and the official emissions factors set under the applicable rules. The share of renewables alone would not determine the size of any reduction in default emissions treatment.
Contractual intermediary rules and evidence for actual-emissions claims
The current implementing framework recognises a direct power purchase agreement (PPA) and a limited tripartite contractual structure. The Commission’s proposed changes could allow a wider range of verifiable contractual chains to support actual-emissions claims.
This flexibility could reduce the need to restructure transactions around a single three-party contract when multiple intermediaries participate in a sale. However, expanded recognition would not remove the requirement to substantiate claimed electricity volumes.
An EU importer would still need evidence that electricity was generated, nominated, and imported in line with the final applicable regulation. Reliable allocation controls would remain necessary to prevent unsupported or duplicated claims.
Congestion evidence proposal and compliance implications
The physical-network congestion condition is identified as another focus for reform under the proposal. Market participants may struggle to obtain evidence covering relevant transmission routes for individual import hours.
This can add documentation burdens for renewable generators and EU buyers. The Commission has proposed removing this condition as part of its reform package, which—if adopted and made applicable—could reduce evidence requirements for qualifying electricity imports.
Until any amendment enters into force and applies to relevant transactions, exporters cannot assume that current congestion-evidence requirements have been waived.
Timing for 2026 application, declarations, and recordkeeping
The Commission’s proposal envisages applying certain electricity-methodology changes to imports from 1 January 2026. If adopted in that form, the revised rules could be used for the first annual declarations due in September 2027.
This approach would apply retrospectively to covered imports. Businesses are therefore expected to retain their 2026 records even if they anticipate later simplification, while final legislation may differ from the draft or set specific conditions for recalculating historical imports and declarations.
The legislative timetable adds further uncertainty: on 15 September 2026, the European Parliament adopted amendments at first reading, after which negotiations moved into interinstitutional discussions. As of 17 October 2026, the final text and implementation timetable were still uncertain.
PPA clauses for future amendments and historical transaction handling
Electricity offtake agreements can address uncertainty through conditional provisions linked to when specified legal changes become applicable. For example, a PPA could expand an eligible volume pool or permit additional contractual intermediaries once relevant requirements are satisfied.
Contracts are also expected to address how historical 2026 transactions are treated. This includes whether previous settlements can be reopened, whether corrected information must be submitted by the buyer, and how realised carbon-cost savings would be allocated between parties.
Without clear contractual provisions, disputes could arise over financial values tied to earlier imports and responsibilities across participants in the contractual chain. For regional electricity markets, proposed changes may offer routes toward broader access and more flexible trading structures, but commercial value remains uncertain until enforceable rules are established.
Exporters, traders, and importers are therefore expected to preserve current evidence, negotiate contracts able to accommodate legal changes, and avoid pricing anticipated regulatory benefits before amendments take effect.