Domestic industrial demand can support renewable investment and improve electricity cost predictability, but the carbon value of a power purchase agreement depends on the products being exported and the emissions rules governing them.
Renewable developers in Serbia and Montenegro have an opportunity to connect with European industrial demand without relying exclusively on cross-border electricity exports. By supplying local factories that manufacture goods for European markets, developers can secure long-term offtake agreements, establish a more predictable revenue base and reduce exposure to some of the costs associated with international electricity delivery.
For a renewable project seeking financing, a domestic industrial power purchase agreement (PPA) can provide a valuable anchor customer. However, its investment value must be assessed against the manufacturer’s creditworthiness, electricity consumption profile and willingness to pay. A general promise of lower Carbon Border Adjustment Mechanism (CBAM) costs is not a reliable substitute for a detailed commercial assessment. The effect of renewable electricity procurement on a product’s carbon-border calculation varies significantly across industrial sectors.
Steel and aluminium manufacturers may have compelling reasons to secure renewable electricity even when changing their power supplier does not reduce their current CBAM certificate obligations. The business case must therefore distinguish the value of electricity procurement from any carbon-related benefit that can actually be recognised under the applicable rules.
The exported product determines the value of carbon savings
An electricity sale within Serbia or Montenegro does not, by itself, constitute an import of electricity into the EU. If a local factory subsequently exports goods covered by CBAM, the relevant assessment concerns the embedded emissions of those products. Their customs classification and applicable emissions methodology determine whether the electricity purchase can affect the emissions reported by the EU declarant.
Under the definitive CBAM regime, covered iron, steel and aluminium products listed in Annex II are subject to a direct-emissions approach. Switching between external electricity suppliers does not automatically reduce the associated CBAM certificate requirement. Electricity-related emissions may still matter for corporate sustainability reporting and customer requirements, but those broader carbon-footprint calculations cannot replace the statutory CBAM methodology.
For steelmakers and aluminium processors, the immediate priority is to understand production boundaries, relevant direct emissions and the treatment of precursor materials. A renewable PPA does not eliminate emissions embedded in purchased feedstock. Changes to furnaces, fuels or production processes may have different effects and must be evaluated separately.
Covered cement and fertiliser products include indirect emissions in their CBAM calculations, making electricity sourcing potentially more relevant. However, recognition depends on the applicable rules, evidence requirements and allocation methodology. The provisions governing indirect electricity emissions must be assessed in the context of the individual factory; requirements for electricity imported directly across an EU border should not automatically be transferred to a domestic industrial PPA.
Even where an indirect-emissions reduction can be recognised, cement and fertiliser producers must still account for process emissions and other relevant sources. The financial value of the improvement depends on the electricity consumed, the emissions attributable to that consumption and the overall CBAM obligation.
Separate electricity savings from carbon-related claims
The strongest case for a domestic industrial PPA may begin with the fundamentals of electricity procurement. A manufacturer can use a long-term agreement to improve budget visibility, diversify purchasing arrangements and secure an agreed share of renewable generation. A generator, in turn, gains an identifiable customer whose demand can support investment decisions.
These benefits depend primarily on the agreed price formula, delivery profile and allocation of risk, rather than on whether the contract carries a renewable label.
A fixed-price agreement can protect a manufacturer against rising electricity prices, but it may become more expensive than spot-market procurement when wholesale prices fall. Indexed pricing, price floors and collars distribute that exposure differently. The appropriate structure depends on the operating cash flows and risk tolerance of both parties.
The manufacturer’s electricity savings should be calculated separately from any potential carbon benefit. For example, a €5/MWh reduction in procurement costs across 80 GWh of annual consumption would produce an illustrative saving of €400,000 per year, before associated fees. This establishes an energy-cost benefit; it does not, by itself, demonstrate a reduction in the CBAM certificates required for the manufacturer’s exports.
Renewable attributes can create additional value where customers recognise the relevant reporting arrangements. Guarantees of origin and other certificates may support specified disclosure claims under the applicable framework, but they do not automatically establish CBAM eligibility. Contracts should clearly identify which attributes are transferred, which claims the buyer intends to make and how those attributes are accounted for alongside the physical electricity supply.
This creates an opportunity for utilities such as EPS and EPCG, as well as independent suppliers, to develop more clearly differentiated industrial offers. Electricity supply, balancing services, certificate delivery and product-specific emissions information serve different purposes. Transparent pricing allows manufacturers to select the elements they need without relying on an unsubstantiated promise of regulatory savings.
Credit quality and consumption patterns determine financing value
A domestic industrial buyer can remove some of the costs associated with cross-border electricity delivery, but it introduces other risks. Factory demand may decline because of maintenance, weaker orders or reduced production. A renewable project, meanwhile, continues to face financing and operating costs even when its customer consumes less electricity.
Lenders will therefore examine minimum purchase commitments, credit support and the contractual consequences of a production shutdown. A PPA backed by a financially strong manufacturer with predictable consumption may provide a more dependable revenue stream than an agreement with a weaker counterparty whose demand fluctuates sharply.
Generation and consumption profiles are equally important. Solar production may align well with a factory’s daytime operations but provide limited support for processes that require a constant electricity supply overnight. Wind can diversify the generation profile, although its output does not necessarily correspond to industrial demand.
The PPA must specify who purchases replacement electricity, sells surplus generation and bears imbalance costs. If these responsibilities remain unclear, a seemingly competitive tariff may conceal significant additional expenses for the generator or manufacturer.
Contract duration requires a similar balance. Renewable developers often seek long-term revenue commitments to support borrowing, while manufacturers must retain flexibility as their sales markets, production requirements and technologies change. Credit support, volume tolerances and agreed termination payments can help reconcile these competing objectives.
However, excessively demanding obligations imposed on a financially weak customer may offer little practical protection. Contractual security is valuable only to the extent that it can be enforced and recovered when required.
For lenders, the appropriate comparison is between risk-adjusted domestic revenue and risk-adjusted export income. An Italian or Hungarian buyer may offer a higher benchmark while requiring additional delivery commitments, trading services and carbon documentation. A local industrial customer may offer a lower price but provide a simpler delivery structure and a better-matched consumption profile.
Neither route is inherently superior. The investment decision depends on the actual counterparties, contractual terms, generation profile and costs of fulfilling each agreement.
Reliable evidence protects the value of the agreement
Where a manufacturer seeks recognition of reduced indirect emissions, its production records must connect the relevant electricity information to the goods covered by CBAM. This requires a defined flow of information between the generator, electricity supplier, manufacturer and verifier. The EU buyer or authorised declarant must also receive the necessary verified information in time to meet its own obligations.
Site engineers can support this process by maintaining metering systems, reconciling consumption data and organising documentation ahead of verification. Their work improves the reliability of the evidence chain, while the accredited verifier retains responsibility for the independent verification conclusion.
Documentation should be built into the operating process rather than assembled only when a buyer or verifier requests it. Clear responsibilities for data collection, corrections, access rights and reporting deadlines can reduce disputes and prevent a potentially valuable commercial arrangement from being undermined by incomplete records.
Developers supplying both domestic factories and EU electricity importers must also maintain clear allocation controls. Contracts should identify committed volumes, transferred attributes and the treatment of surplus or shortfall production. The same electricity volume cannot support conflicting delivery commitments or incompatible emissions claims.
The ability to redirect output towards a more attractive market can be commercially valuable, but only where the producer retains the contractual right to sell that electricity and can meet the relevant delivery obligations.
Industrial PPAs can strengthen renewable investment across the region
For Serbia and Montenegro, domestic industrial PPAs can broaden demand for new renewable generation while helping manufacturers manage electricity costs and respond to customer requirements. Their strongest contribution to project financing comes from measurable energy savings, credible counterparties and contractual structures that match actual consumption and production.
Carbon-related benefits can strengthen that proposition where the relevant emissions methodology recognises them and the supporting evidence is available. Where an immediate CBAM saving cannot be demonstrated, the investment case must rest on other tangible advantages, including price predictability, supply diversification and long-term commercial stability.
For developers and lenders, the priority is to establish how much dependable revenue the agreement generates, which risks can reduce that revenue and whether any claimed carbon benefit is legally supportable. A well-structured domestic PPA can provide a meaningful foundation for renewable investment without relying on carbon savings that the applicable rules may not recognise.
