Renewable electricity producers outside the European Union need to align their power purchase agreements with CBAM requirements if they want imported electricity to receive actual-emissions treatment. Eligibility depends on how contractual roles link the generating installation, any intermediary, and the authorised EU importing declarant. The same contractual relationship is also used to support the evidence needed for cross-border delivery.
Direct physical PPAs and single tripartite agreements
A direct physical PPA between a renewable electricity producer and an authorised EU CBAM declarant creates a direct contractual structure. Such agreements 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 involvement does not conflict with the supply relationship used for actual-emissions claims.
Commission Implementing Regulation (EU) 2025/2547 sets out an alternative through a single tripartite PPA involving the producer, an intermediary, and the EU declarant. Where a PPA is concluded via an intermediary, the contractual evidence must show that only one contract was concluded between all three parties. This requirement is intended to distinguish qualifying tripartite arrangements from conventional wholesale trading chains.
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. Even if successive transactions are valid wholesale trades, they cannot automatically be treated as a qualifying tripartite PPA. The distinction turns on whether the evidence demonstrates a single contract connecting all three parties.
Physical delivery conditions under Regulation (EU) 2023/956
Both direct and tripartite contractual models must meet conditions set out in Annex IV(5) of Regulation (EU) 2023/956. 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 exports must be firmly nominated against allocated interconnection capacity by responsible transmission system operators. The nomination and actual 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. A signed PPA alone does not establish eligibility. Contractual documentation must be supported by evidence covering generation, nominations, transmission arrangements, and verification.
Balancing responsibilities and contract alignment
For direct PPAs, cross-border delivery can require additional operational arrangements. A wind project selling to an EU trader may need a separate entity to act as the local balancing-responsible party, manage grid deviations, and secure cross-border transmission rights. Agreements should identify who submits nominations, how imbalance charges are allocated, and what operational instructions the importing buyer may issue.
If a trader acquires full title to electricity under a separate resale arrangement, parties must reassess whether the direct PPA still reflects the transaction relied upon for actual-emissions treatment. Tripartite agreements can accommodate intermediaries with broader contractual responsibilities. However, their provisions need to separate qualifying physical supply from supporting commercial services.
The main tripartite agreement should establish the single qualifying PPA and specify each party’s commitments. Separate schedules can cover pricing and invoicing, dispatch instructions, cross-border capacity, balancing settlements, meter access, document retention, and transfer of data to the EU declarant. Unclear contractual relationships can affect whether electricity receives anticipated treatment under actual-emissions rules.
Hourly reconciliation and allocation of qualification premiums
Annual invoices are not sufficient to determine eligible electricity quantities. 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 links contractual volumes with operational delivery records used for import documentation.
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 is described as a reconciliation safeguard rather than a replacement for statutory eligibility tests. Pricing provisions also need to distinguish payment for delivered electricity from any premium tied 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. They should also state whether adverse verification results trigger repricing, indemnification, alternative delivery arrangements, or application of a default emissions factor.
Status of proposed changes under EU legislation
The European Commission’s December 2025 proposal COM(2025) 989 would introduce greater flexibility in aspects of the actual-emissions test. The areas mentioned include treatment of intermediary arrangements and physical-network conditions. As of 17 October 2026, these changes remained subject to the EU legislative process.
Contracting parties may include provisions allowing adjustments if rules change after adoption. However, proposed measures 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.
Relevance for renewable project financing
Lenders assessing direct and tripartite PPAs face different contractual and operational considerations. Direct agreements are generally described as providing a more straightforward legal chain for tracing imports but may still require additional arrangements for balancing, scheduling and cross-border services. Tripartite structures can enable importing buyers to use infrastructure held by trading intermediaries while consolidating contractual, operational and evidentiary responsibilities into one multi-party instrument.
For both structures, the core test is whether each claimed electricity import can be traced from the generating installation through contractual and physical delivery arrangements to the EU import declaration. Required evidence must be available for independent verification. The traceability requirement applies across both direct physical PPAs and single tripartite agreements involving intermediaries.