The European Commission’s technical work on indirect emissions under the Carbon Border Adjustment Mechanism points to a future in which electricity used by industrial producers must be proven and documented for use in EU importers’ CBAM declarations. The evidence must be credible enough for verification, including cases where producers claim actual low-carbon electricity rather than relying on a default grid factor. In that framework, supporting documentation may become as important as the physical electricity itself.
DG TAXUD published its technical study on indirect emissions in CBAM on 8 June 2026. The study is structured around three questions: how to determine operational default emission factors for indirect emissions; when declarants can claim actual indirect emissions, including requirements for direct technical links, power purchase agreements and verification; and whether indirect-emissions coverage could extend to additional CBAM sectors.
From green electricity claims to CBAM-verifiable evidence
A key distinction is between green electricity as a marketing claim and low-carbon electricity as a CBAM evidence file. A renewable PPA can support decarbonisation, cost hedging and ESG positioning, but under CBAM the technical question becomes whether the electricity claim can calculate actual indirect emissions for goods entering the EU. The framework also requires that the importer or authorised CBAM declarant can rely on the claim and that it can be checked by a verifier.
DG TAXUD’s emphasis on direct technical links, PPAs and verification indicates that different green electricity arrangements may carry different evidentiary value. A behind-the-meter renewable asset with clear metering and a direct technical link to an industrial installation may provide stronger evidence than an ordinary supply contract. A PPA with settlement data, certificate cancellation, production matching and verifier access may carry more value than a generic renewable certificate procured after the fact.
Traders as data and documentation managers
Under the emerging CBAM-linked electricity framework, traders are positioned beyond price execution as data and evidence managers. Industrial buyers are expected to require power products combining physical or financially settled supply, renewable or low-carbon attribution, metered consumption records, production-period alignment and certificate or guarantee-of-origin control. The package also needs balancing and residual supply treatment, audit access and documentation transferable into the importer’s CBAM file.
A trader assembling power from multiple producers, managing balancing, documenting certificate flows and reconciling metered consumption can become more valuable than a trader focused only on execution. The role is described as similar to a structured-products desk, packaging energy, certificates, shaping, balancing, traceability and verification support into one industrial supply solution. In Southeast Europe, this approach is tied to volatility in power markets where contracts need hourly shape and residual supply handling rather than annual averages.
Week 23 of 2026 showed regional volatility with SEE electricity demand up 8.2% week on week to 15.15 TWh. Variable renewables fell 8.9%, with wind down 15.5%, solar down 5.1%, hydro up 10.1%, while thermal generation rose 24.5%. Net imports increased 9.1% to 1.22 TWh, indicating continued reliance on cross-border balancing.
Default emission factors and contract design incentives
The first DG TAXUD study question on operational default emission factors is central for energy-market participants. A default factor is not only a technical fallback; it can become a commercial penalty if exporters cannot prove actual low-carbon electricity use. In that case, EU importers may have to rely on default emissions factors for goods produced using electricity from carbon-intensive grids.
This risk affects competitiveness of exported products including cement, fertiliser, steel derivatives and aluminium products where indirect emissions are relevant to CBAM reporting. It also changes supplier messaging from “renewable power” toward providing the data architecture needed to support an actual indirect-emissions claim. That architecture includes metering, settlement records, generation certificates, PPA documentation, grid connection evidence, time-matching logic and residual consumption treatment.
Direct technical links and storage in evidence strategies
A direct technical link is expected to become one of the strongest forms of evidence for industrial buyers seeking low-carbon electricity recognition under CBAM rules. For renewable developers, this supports a premium segment for dedicated solar, wind, hydro, biomass or hybrid plants serving CBAM-exposed industrial sites. The value of such projects extends beyond electricity price by potentially reducing embedded-emissions exposure and strengthening supply-chain credibility.
The market also highlights battery storage as part of an evidence strategy where solar output does not match industrial load curves. A battery can shift renewable output into more relevant consumption periods while reducing residual grid draw and improving delivery shape under a PPA structure. In this context, battery energy storage systems are described as flexibility assets that can support verification-oriented documentation.
PPA clauses tailored for verification
A standard PPA is described as insufficient for CBAM-ready evidence requirements. A CBAM-ready PPA should include clauses addressing data ownership and access rights, metering hierarchy, certificate transfer or cancellation and settlement-period matching. It should also define residual electricity treatment covering curtailment, outages and replacement power along with balancing responsibility and verifier access.
The contract needs to align with the plant’s electrical system and production process so that electricity consumption can be allocated to the specific CBAM good within reporting boundaries. It also depends on whether suppliers can provide an audit trail required for verification rather than only delivering power under commercial terms. Power producers and traders are expected to prepare standardised CBAM electricity data packs containing asset identity and location plus installed capacity and technology details.
The same data packs are expected to include grid connection status and direct-line or grid-supply structure information alongside PPA delivery period and settlement granularity. They should cover metered generation and consumption data plus certificate issuance and cancellation evidence, balancing and replacement power treatment and residual mix disclosure. Third-party verification rights are also part of the pack requirements together with monthly and annual reconciliation templates.
Definitive CBAM timing and indirect emissions scope
The Commission’s CBAM page states that the definitive regime started on 1 January 2026. It also notes that EU importers or indirect customs representatives importing more than the single mass-based threshold of 50 tonnes of CBAM goods must apply for authorised CBAM declarant status. The page further states that CBAM certificate prices are calculated from EU ETS allowance auction prices quarterly in 2026 and weekly from 2027.
The current definitive-period treatment of indirect emissions is narrower than transitional reporting experience described for Task 2 publications office materials. That summary indicates that during transition CBAM covered direct production emissions while indirect emissions were reported for all CBAM goods except electricity; during transition indirect emissions were linked to cement and fertiliser goods’ electricity consumption in the definitive period framing noted in the materials. DG TAXUD’s third study question addresses whether indirect-emissions coverage could extend to additional CBAM sectors beyond those currently covered.
Southeast Europe price fragmentation and gas risk
The source materials connect urgency to volatility in Southeast Europe power markets alongside gas risk affecting overall energy costs. Week 23 pricing comparisons show Italy averaging €128.09/MWh, Bulgaria €100.83/MWh, Hungary €103.15/MWh, Greece €89.25/MWh, Serbia €99.63/MWh, Croatia €99.29/MWh, while Türkiye averaged only €22.53/MWh. This indicates fragmentation across regional markets relevant to contract structuring.
The same materials report gas futures impacts with TTF gas futures averaging €48.56/MWh during the first week of June while one-month forward trading was near €49.335/MWh. They also warn European gas markets remain vulnerable to LNG disruption, storage risk and competition for cargoes.
What producers must prepare across technologies
The materials describe documentation expectations shifting toward buyer requests that match price demands with proof requirements under CBAM-linked electricity scrutiny . Renewable producers are expected to provide asset-level generation data including metering records plus certificate issuance and cancellation evidence together with curtailment logs and outage reports linked contractually to industrial buyers.
Where possible, renewable developers are expected to design direct technical link projects or behind-the-meter solutions for sites exposed through CBAM-related reporting boundaries . Hydro producers are expected to document generation origin, dispatch periods and certificate treatment because hydro can better match non-solar load profiles provided attributes remain traceable without double-counting.
Treatment expectations differ for thermal producers who may continue supplying reliability and balancing power while recognising that fossil-based residual supply could be treated as a liability unless separated, priced and disclosed explicitly within supply structures . Storage operators are described as positioning batteries as compliance-supporting flexibility assets where BESS can help match renewable supply with industrial demand reduce exposure during fossil-heavy evening periods improve delivery shape under PPAs .
Trader systems for reconciliation, certificates and audit trails
The materials state traders need systems able to reconcile generation, consumption, certificates schedules and imbalances while managing residual electricity transparently . They also need monthly evidence packs that industrial buyers can pass to EU importers along with controls designed to avoid double-counting renewable attributes across supply structures . The distinction between physical elements contractual elements and financial elements is highlighted as part of operational readiness.
A CBAM-ready trader offering includes structured renewable PPAs plus sleeving services covering balancing shaping storage optimisation certificate management residual mix disclosure . It also includes hourly or settlement-period reporting together with importer-facing documentation verifier cooperation and audit-ready data rooms . The materials describe this service as higher-margin than commodity trading but requiring stronger controls.
Industrial buyer questions tied to product-level allocation
The materials list five questions industrial buyers increasingly demand answers for when contracting electricity used in production of CBAM goods . These include what electricity was consumed during production what emissions factor was attached how claims are based on default factors actual factors PPAs direct technical links or blended methods whether evidence reconciles with production volumes product-level allocation . They also include whether EU importers or authorised CBAM declarants can use evidence safely in their CBAM declarations .
The materials state that any producer or trader unable to answer these questions would be selling a weaker product within this emerging framework . They further describe DG TAXUD’s technical study as signalling a new commercial category where electricity contracts function as embedded-emissions instruments rather than only supplying power .
Elevated by CBAM.Clarion.Engineer
