Renewable developers in Serbia and Montenegro are pursuing a second route to European industrial demand alongside cross-border electricity exports. Instead of selling power only across the EU border, projects can also sell electricity to local factories that supply customers in Europe. For long-term revenue, a domestic industrial PPA can provide an anchor buyer and reduce exposure to cross-border delivery costs.
The investment case depends on the manufacturer’s credit quality, electricity consumption levels and willingness to pay. A general expectation of lower CBAM costs is not a substitute for project economics. How purchased renewable electricity affects border-carbon calculations varies by industrial sector and by the emissions rules applied to the exported product.
Industrial buyers, CBAM exposure and the role of renewable electricity
Steel and aluminium buyers may seek renewable power even when switching electricity does not change their current CBAM certificate obligation. In those cases, the PPA revenue argument needs to specify the benefit that the contract actually delivers. The value proposition therefore hinges on what changes in reporting or compliance outcomes, rather than on a broad claim about CBAM.
An electricity sale within Serbia or Montenegro does not automatically amount to an import of electricity into the EU. If a factory later exports covered goods, the relevant assessment focuses on embedded emissions in those goods. Customs classification and production methodology determine whether the electricity purchase alters emissions that an EU declarant must report and finance.
Under the current definitive regime, covered iron, steel and aluminium goods listed in Annex II are assessed using direct emissions. Changing from one external electricity supplier to another does not automatically reduce the CBAM certificate requirement for those products. Electricity-related emissions may still be reflected in corporate or customer reporting, but that broader footprint cannot replace the statutory calculation.
For steelmakers and aluminium processors, CBAM-related work includes defining production boundaries, identifying relevant direct emissions and addressing precursor inputs. A renewable PPA does not remove emissions embedded in purchased feedstock. Changes to furnaces, fuels or production routes can have different effects and require separate assessment.
Indirect-emissions products: cement and fertiliser
Cement and fertiliser products covered under CBAM include indirect emissions. That means electricity sourcing can be more relevant to their CBAM calculation than it is for direct-emissions categories. Recognition depends on applicable actual-value criteria, records and the allocation method used for calculations.
The rules for indirect electricity emissions should be applied based on the factory’s circumstances. The border-delivery requirements for electricity exported as a good should not be treated as transferable to a domestic contract arrangement. For cement and fertiliser producers, any recognised indirect-emissions saving still leaves process and other relevant emissions within the product calculation.
The remaining product-level value depends on both the electricity consumed and the overall CBAM obligation tied to exports. This links domestic power procurement directly to how exported goods are calculated under CBAM rather than to whether electricity is sourced locally.
Separating energy procurement economics from carbon claims
A domestic industrial PPA case can start with electricity procurement terms. A manufacturer may use a long-term agreement to improve budget visibility, diversify purchasing and secure an agreed share of renewable output. A generator can secure an identifiable customer whose demand supports investment.
These benefits depend on the price formula and delivery profile rather than on use of a green label. A fixed price limits exposure to rising prices but can exceed spot market levels when prices fall. Indexation, floors and collars shift these risks differently, so contract design needs alignment with operating cash flows.
The manufacturer’s electricity invoice should be modelled separately from any claimed carbon benefit tied to exports. For example, a €5/MWh procurement saving on 80 GWh of consumption would improve annual energy costs by €400,000, before associated fees. That figure reflects an energy-cost benefit only and does not determine CBAM certificates linked to exported products.
Renewable attributes may add value where customers recognise specific reporting arrangements. Guarantees of origin and other certificates may support disclosure claims subject to applicable frameworks, but they do not automatically establish CBAM eligibility . Contracts should describe which attributes are transferred and what claim is intended so buyers can assess that value alongside the physical electricity price.
This structure can help utilities such as EPS and EPCG, along with independent suppliers, develop more precise industrial offers . Energy supply, balancing responsibilities, certificate delivery and product-specific emissions information each serve different functions. Transparent pricing supports manufacturers in identifying which elements they need without allowing an assumed regulatory saving to carry the entire transaction.
Financing considerations: credit risk, load profiles and contract terms
A domestic industrial buyer can remove some border-related costs while introducing counterparty risks for generators. Factory demand may decline with production changes, maintenance schedules or weaker order books. During those periods, a renewable project continues to incur financing and operating expenses.
Lenders therefore focus on minimum purchase commitments, security arrangements and scenarios if the customer closes a production line . Output profiles also matter for matching generation patterns with industrial consumption needs. A solar installation may fit daytime factory demand but be poorly matched where steady overnight power is required.
Wind can diversify supply but does not automatically follow industrial demand patterns either . The PPA needs clear terms on who buys shortfalls, who sells surplus output and who carries imbalance costs rather than leaving these services embedded in a headline tariff.
Contract duration requires similar balancing between generator financing needs and manufacturer sales cycles. Generators may seek revenue over a period long enough to support borrowing while manufacturers face shorter sales cycles and uncertain technology requirements . Credit support, volume flexibility and agreed termination payments can align interests where obligations otherwise fall heavily on weaker counterparties.
Lender comparisons: domestic versus export-linked income
For lenders evaluating project viability, comparisons should be made between risk-adjusted domestic income streams and export-linked income streams . An Italian or Hungarian buyer may offer higher benchmark returns but require additional delivery commitments and carbon documentation. A local industrial customer may pay less while providing a simpler route and a load profile better suited to generation characteristics.
No commercial structure is inherently superior without reviewing actual counterparties and contract terms . The same applies when assessing how credit risk interacts with delivery obligations under domestic PPAs tied to manufacturing demand.
Evidence flows for indirect-emissions improvements
If a factory seeks a recognised indirect-emissions improvement, its production records must connect eligible electricity information to relevant goods . That requires an agreed data flow between generator, supplier, manufacturer and verifier so that calculations remain auditable. The EU buyer or declarant also needs access to verified information in time to meet its own obligations.
Site engineers can maintain meters, reconcile consumption figures and organise records before verification . Their role supports evidence preparation while an accredited verifier retains responsibility for independent conclusions.
A generator serving both domestic factories and EU electricity importers needs controlled allocation between channels . Contracts should identify committed quantities alongside associated attributes with agreed treatment for surplus output and shortfalls. Flexibility to choose which market performs better is limited to volumes the producer remains entitled to sell; those volumes cannot simultaneously support conflicting delivery or emissions claims .
Implications for Serbia and Montenegro’s industrial PPA market
In Serbia and Montenegro, industrial PPAs can broaden demand for new renewable plants while helping local manufacturers manage electricity exposure alongside customer requirements . Financing contributions depend on measurable energy value, credible buyers and evidence appropriate to exported products rather than assumptions about immediate CBAM savings . Where no immediate CBAM saving is available, investment cases rely on those other benefits within contract economics.
