Independent power producers (IPPs) supplying renewable electricity under contracts that include emissions evidence may receive a premium, while also accepting contractual liabilities that can exceed the additional revenue. The exposure can increase when an installation-specific actual emissions claim does not meet the applicable requirements. In that scenario, fallback carbon exposure linked to the project may outweigh the premium earned on eligible electricity deliveries.
The mismatch can occur when extra payment is limited to megawatt-hours accepted under eligibility conditions, while an indemnity extends to a broader volume or a larger share of the buyer’s incremental CBAM liability. Contract terms such as weak liability caps, inadequate cure provisions and unclear causation tests can amplify the financial impact. The commercial review therefore needs to separate the revenue associated with qualifying deliveries from the quantity and financial exposure covered by indemnity language.
Electricity CBAM conditions and fallback default emissions
Under the current EU Carbon Border Adjustment Mechanism framework, imported electricity relies on default emissions values unless conditions for installation-specific actual emissions are satisfied. Those conditions include a qualifying physical power purchase agreement (PPA), the relevant network condition, and a generating installation below a threshold of 550 g CO2/kWh fossil-fuel-origin emissions. The framework also requires firm nominations matched with production in periods of no more than one hour.
Independent verification must be supported by at least monthly interim evidence. If an actual-emissions claim cannot meet the requirements, contractual consequences may extend beyond losing the premium tied to eligible electricity. Depending on the indemnity wording, the producer may face claims connected to the buyer’s additional carbon costs under CBAM.
Contractual liability provisions are therefore expected to define how producer breach relates to buyer loss and what amount is recoverable. The structure should distinguish revenue earned on qualifying megawatt-hours from the indemnity-covered financial exposure. This separation is central to assessing whether the contract’s downside is aligned with any premium received.
Reconciling title, payments, evidence and scheduling
Contract structures are described as requiring separate mapping of title transfer, payment flows and emissions evidence, followed by consistency checks. A structure may appear coherent on paper but fail in practice if the entity performing scheduling, importing or data custody differs from what is assumed in the PPA. Operational alignment is therefore treated as part of contract feasibility.
For projects supplying industrial customers in steel or aluminium, allocation of contractual benefits requires additional attention. Different agreements may cover renewable electricity attributes, CBAM evidence and electricity availability. The same megawatt-hour or financial benefit should not be promised more than once where obligations and remedies are incompatible.
Where multiple generating installations operate under one framework, each plant should have its own controlled schedule and allocation limits. Portfolio flexibility can support procurement activities, but substitutions must trigger a defined review process. This is intended to prevent replacement electricity from being automatically attributed to the original generating installation.
Indemnity exposure in project finance assessments
Lenders assessing project-finance structures are expected to examine maximum indemnity exposure alongside available security, insurance exclusions and claim timing. These elements determine whether a contractual liability can be absorbed within the project’s financial structure. The assessment also considers how quickly claims could arise relative to financing arrangements.
Lenders and counterparties are also expected to distinguish verified losses actually incurred by the buyer from theoretical avoided-cost calculations that did not materialise as real expenses. Contractual damages calculations should identify relevant loss, specify required evidence and set limits on recovery. These details affect how indemnities translate into measurable claims.
Contract managers are described as approving arrangements only when parties, title transfers, cash flows, data rights and fallback settlement formulas can be reconciled without relying on informal assumptions. This approach links operational documentation with legal enforceability under fallback scenarios.
EU reform proposal affecting electricity treatment under CBAM
A separate reform proposal identified as COM(2025) 989 would change electricity treatment under CBAM. The proposal includes adjustments to methodology for default values and parts of conditions governing actual emissions values. It would also broaden the concept of physical PPAs involving intermediaries and modify congestion and nomination aspects of eligibility.
The Council adopted its negotiating position on 12 June 2026, followed by the European Parliament’s position on 15 September 2026. The proposal remains under interinstitutional negotiation and is not treated as enacted legislation for current pricing or project-finance assumptions.
The European Commission published definitive-period sector guidance on 14 August 2026, including dedicated guidance for electricity, iron and steel, and aluminium. Its general CBAM questions and answers were updated on 15 October 2026. These materials explain implementation but do not replace binding regulations and implementing acts.
For an IPP, bankability of a premium-backed PPA is described as depending on whether downside tied to that premium is clearly defined, appropriately capped and recoverable within project financing arrangements. The extent of premium-related downside therefore becomes a key factor in evaluating contract risk under CBAM-linked structures.