Renewable electricity producers outside the European Union must align their power purchase agreements with CBAM requirements if they want imported electricity to receive actual-emissions treatment. The contractual relationship connecting the generating installation, any intermediary, and the authorised EU importing declarant is described as central to establishing electricity origin. It is also tied to substantiating the evidence needed for cross-border delivery.
Direct physical PPAs and single tripartite arrangements
A direct physical PPA between a renewable producer and an authorised EU CBAM declarant is presented as a straightforward contractual structure. The agreement is expected to identify the generating installation, contracted volumes, delivery periods, pricing, the buyer, and how responsibility is allocated for obtaining records used in the EU import declaration. Separate traders or balancing service providers may support scheduling and market access if their role does not conflict with the supply relationship used to claim actual emissions.
An alternative structure described is a single tripartite PPA involving the producer, an intermediary, and the EU declarant. Commission Implementing Regulation (EU) 2025/2547 states that when a PPA is concluded through an intermediary, the contractual evidence must show that only one contract was concluded between all three parties. The requirement is intended to distinguish qualifying tripartite arrangements from wholesale trading chains involving successive agreements.
In a conventional wholesale chain, an independent power producer sells electricity to one trader under one agreement, and that trader resells it to an EU importer under another. While such successive transactions can be valid wholesale trades, they cannot be classified as a qualifying tripartite PPA under the described approach. The distinction hinges on whether the evidence demonstrates a single contract linking all three parties.
Physical delivery conditions for actual-emissions eligibility
Both contractual models are required to meet wider conditions set out in Annex IV(5) of Regulation (EU) 2023/956, which governs the EU Carbon Border Adjustment Mechanism. The generating installation must be directly linked to the EU transmission system. Alternatively, the claimant must demonstrate that there was no physical network congestion along the relevant route at the time of export.
The installation must also remain below a threshold of 550 grams of fossil-origin CO₂ per kWh. Electricity must be firmly nominated against allocated interconnection capacity by responsible transmission system operators. The nomination and actual electricity production must correspond to the same period, which cannot exceed one hour.
An accredited verifier must certify compliance with these conditions and receive interim evidence at least monthly. The described requirements indicate that signing a PPA alone cannot establish eligibility. Eligibility depends on supporting evidence covering generation, nominations, transmission arrangements, and verification.
Nominations, balancing responsibilities and contract alignment
For direct PPAs, cross-border delivery can require additional arrangements for operational roles. A wind project selling to an EU trader may need a separate entity acting as the local balancing-responsible party, managing grid deviations and securing cross-border transmission rights. Agreements are expected to identify who submits nominations and how imbalance charges are allocated.
The relevant agreements should also specify operational instructions that the importing buyer may issue. Where a trader acquires full title to electricity under a separate resale arrangement, parties are expected to reassess whether the direct PPA still reflects the transaction relied upon for actual-emissions treatment. This reassessment is tied to whether the contractual basis remains consistent with what is claimed for eligibility.
A tripartite agreement can include an intermediary with broader contractual responsibilities, but its provisions need to separate qualifying physical supply from supporting commercial services. The main agreement should establish the single qualifying PPA and set out each party’s commitments. Separate schedules may cover pricing and invoicing, dispatch instructions, cross-border capacity, balancing settlements, meter access, document retention, and transfer of data to the EU declarant.
Hourly reconciliation and allocation of qualification premiums
The eligible quantity of electricity cannot be established using annual invoices alone. Contracting parties are expected to reconcile for each hour: PPA-covered volume, metered eligible generation, accepted firm nominations, and the volume recorded in customs-import documentation. This hourly reconciliation is described as necessary for determining what can be supported for eligibility purposes.
As an operational control, eligible quantity can be limited to the smallest hourly volume supported by available evidence when other regulatory conditions are met. This limitation is described as a practical reconciliation safeguard rather than a substitute for statutory eligibility tests. It relies on matching nomination timing and metered generation with customs-import records.
Pricing provisions are also expected to distinguish payment for delivered electricity from any premium linked to successful emissions qualification. A producer may receive payment for all delivered megawatt-hours while receiving an additional qualification premium only for volumes supported by a satisfactory verifier’s conclusion. Contracts should specify how financial differences are handled when eligibility is lost due to inaccurate metering, late nominations, network congestion, curtailed generation, or an error attributable to the importer.
The described contract terms should also address whether an adverse verification result triggers repricing, indemnification, alternative delivery arrangements, or application of a default emissions factor. These elements are presented as part of ensuring that carbon-cost allocation aligns with verification outcomes and eligibility determinations.
Commission proposal on flexibility and timing of rule changes
The European Commission’s December 2025 proposal COM(2025) 989 would introduce greater flexibility in aspects of the actual-emissions test. The proposed changes include treatment of intermediary arrangements and physical-network conditions within that test framework.
As of 17 October 2026, these proposed changes were still subject to the EU legislative process. Contracting parties may include provisions allowing adaptation if rules change; however, the proposed regime should not be treated as legislation already in force. Any attempt to qualify earlier imports retrospectively would require awaiting enacted legal text and relevant implementation provisions.
Considerations for lenders assessing PPAs
Lenders assessing direct and tripartite PPAs face different contractual and operational considerations. A direct agreement is described as generally providing a more straightforward legal chain for tracing purposes. Additional arrangements may still be required for balancing, scheduling and cross-border services.
A tripartite structure can allow an importing buyer to benefit from a trading intermediary’s infrastructure while combining contractual, operational and evidentiary responsibilities into a multi-party instrument. For both structures, the described test focuses on whether each claimed electricity import can be traced from the generating installation through contractual and physical delivery arrangements into the EU import declaration.
The traceability requirement also depends on required evidence being available for independent verification. This includes evidence supporting generation details, nominated interconnection capacity use within defined time limits, transmission-related conditions at export time where applicable, verifier certification processes including interim evidence at least monthly, and reconciliation against customs-import documentation.