Electricity traders importing power into the European Union are increasingly separating conventional deliveries priced using applicable default emissions factors from shipments supported by evidence that satisfies the EU Carbon Border Adjustment Mechanism (CBAM) actual-emissions requirements. The split is affecting how long-term power purchase agreements (PPAs), spot-market positions, and cross-border transmission capacity are valued.
Standard import pricing tied to default emissions factors
Conventional wholesale electricity remains the first pricing category, but delivered costs must reflect prospective CBAM certificate obligations. For imports of 1 MWh at an exchange hub, traders account for the electricity price, losses, transmission capacity, balancing charges, credit costs, and expected carbon liability.
When the applicable default emissions factor is high, the carbon component can remove an otherwise positive wholesale price spread across the EU border. The Energy Community Secretariat reported in its Q1 2026 market monitoring that this effect was among challenges affecting regional electricity exchanges.
Verified deliveries require eligibility evidence and separate identification
A second pricing category covers electricity physically sourced from an eligible installation and backed by a traceable contractual arrangement. Deliveries may qualify for actual-emissions treatment, but establishing eligibility requires additional costs linked to PPA structuring, evidence collection, nomination allocation, metering reconciliation, and verification.
Traders cannot treat an entire generation portfolio as eligible when only some delivery hours meet the relevant requirements. Volumes that qualify must be separately identified and ring-fenced within trading and settlement systems.
Commercial structures for CBAM exposure in quotations
Two approaches are used to structure electricity quotations that reflect CBAM exposure. A cost-plus import model combines the electricity price and ordinary trading expenses with the applicable verified or default carbon component for each megawatt-hour.
A carbon-differential sharing model assigns a conditional share of the difference between fallback treatment and the actual-emissions outcome to the producer. The model can create incentives for generators, scheduling agents, and importers to improve delivery records and emissions evidence quality.
Neither structure changes the importing declarant’s legal responsibilities under CBAM. Contracting arrangements therefore need to align commercial terms with compliance obligations at the EU border.
CBAM certificate reference prices influence contract terms
CBAM certificate reference prices add a variable into long-term electricity contracts. For 2026 imports, published quarterly references were €75.36/tCO₂e for Q1, €75.28/tCO₂e for Q2, and €82.32/tCO₂e for Q3.
From 2027, the reference price calculation moves to a weekly basis. A fixed premium agreed in October 2026 can expose either producer or buyer to larger subsequent carbon-price movements than initially anticipated, depending on how contract provisions such as floors, caps, reopening clauses, and indexation mechanisms allocate that exposure.
Pricing documentation also needs to distinguish the applicable CBAM certificate reference price from EU Emissions Trading System (EU ETS) allowance futures, which are separate market instruments.
Hours without qualification require distinct settlement handling
Traders must determine how to price individual hours within a product marketed as qualifying for actual-emissions treatment when supporting requirements are not met. One option is immediate reclassification of affected electricity and invoicing under standard import pricing methods including applicable carbon exposure.
A second option allows provisional qualification followed by later financial reconciliation. While it provides more flexibility, it introduces additional collateral requirements and counterparty risk.
The provisional approach should be supported by contractual rights to inspect original generation, metering, and nomination records rather than relying only on summary declarations from the producer.
Contract product taxonomy affects transparency of rights and evidence
As market participants gain experience with CBAM-related electricity transactions, quotations may increasingly reflect the likelihood that specific volumes will qualify for actual-emissions treatment. Pricing can become less transparent when sellers offer a combined package of renewable electricity and a CBAM benefit without specifying included rights and evidence.
A clear contractual product taxonomy should separate physical electricity delivery, CBAM eligibility status, renewable certificate attributes, and balancing services. These elements may be bundled commercially, but their obligations and settlement mechanisms should remain identifiable.
Electricity trading desks able to quote and settle conventional versus verified deliveries separately are positioned to reflect different costs and risks associated with each product category. The commercial value of renewable electricity depends not only on its generation source but also on what claims an importer can substantiate under applicable rules at the EU border.