Renewable projects evaluated using P50 and P90 generation forecasts face an additional valuation factor when their electricity is meant to support installation-specific emissions claims under the EU Carbon Border Adjustment Mechanism (CBAM). Forecast output indicates potential production, but it does not determine how much electricity will meet the requirements tied to electricity emissions values at the EU border.
For investors and lenders, the measure extends beyond annual generation figures. It focuses on the portion of electricity that can be contractually linked, properly nominated, imported, and supported by the evidence required for CBAM reporting. This distinction can influence revenue forecasts, premium assumptions, and the level of debt a project can support.
Eligible electricity volume versus forecast generation
A renewable project’s eligible electricity volume may be lower than its forecast generation. The difference arises because output must align with contract coverage, accepted nominations, imported quantities, and other legal conditions applicable to CBAM claims.
In some cases, replacement electricity can maintain the commercial firmness of a power purchase agreement while lowering the share attributable to the installation named in a CBAM claim. Valuation approaches can reflect this by introducing an eligible-MWh curve alongside conventional P50 and P90 generation forecasts.
The eligible-MWh curve enables investors to test how production levels interact with electricity-route availability, completeness of evidence, and the ability to capture a contractual premium. The model structure is intended to connect operational output with what is expected to qualify for installation-specific electricity emissions values.
Implications for industrial supply and financing
The eligible-versus-forecast distinction is described as especially relevant for renewable projects supplying steel and aluminium producers. Such projects may support industrial decarbonisation value even when a buyer’s CBAM calculation for goods is based on direct emissions.
Financial models are expected to separate premiums connected to qualifying electricity imports from premiums arising through industrial procurement arrangements. Lenders can also incorporate covenants related to material gaps in supporting evidence, reserve adequacy, and notification requirements tied to changes affecting the importer, electricity route, or access to relevant data.
Financing structures may further reflect operating history. A newly commissioned renewable project may receive limited or no debt-sizing credit for a premium dependent on regulatory eligibility and documentary evidence until the associated operating chain demonstrates a stable track record.
European Commission guidance and certificate timing
The European Commission published definitive-period sector guidance on 14 August 2026. Dedicated documents cover electricity as well as iron and steel, and aluminium, followed by updates to general CBAM questions and answers on 15 October 2026.
The guidance is described as implementation support rather than a replacement for the binding CBAM Regulation or applicable implementing acts. Project valuations are therefore expected to distinguish between explanatory materials and the legal requirements governing eligibility for installation-specific electricity emissions values.
Certificate timing is also relevant for cash-flow planning. For 2026 imports, CBAM certificate sales are scheduled to start on 1 February 2027, with the first annual declaration and certificate surrender deadline set for 30 September 2027.
From 2027, the general certificate-pricing mechanism moves to weekly auction-price averaging. Quarterly certificate-holding requirements are described as part of treasury planning from that point onward.
The valuation measure referenced in this context is not renewable electricity output alone. It is the volume reaching the intended customer under the contractual arrangements and supporting evidence assumed in the financial model.