Ten renewable-energy projects totalling 645 MW were selected in Serbia’s second renewable-energy auction round, while the government has reported more than 1 GW of battery storage capacity in development. As these projects move toward operation, forecasting, settlement data and the allocation of electricity by source and delivery period are becoming more important. Their arrival coincides with changes in wholesale pricing and the rules affecting electricity exports to the European Union.
Serbia’s power trading market is entering a more volatile, increasingly investment-oriented phase as renewable expansion, negative prices, storage and the EU Carbon Border Adjustment Mechanism (CBAM) interact. Project economics increasingly depend on flexibility, market access and verifiable electricity-delivery data. Without more granular systems, larger volumes of intermittent generation could intensify price volatility and make it harder for participants to realise the full value of their output.
Trading changes alter renewable revenue profiles
In May 2026, SEEPEX introduced negative electricity prices by aligning its minimum price limits with European market practice. The change gives generators, suppliers and storage developers clearer signals during periods of excess supply. SEEPEX also reported record monthly day-ahead trading volumes in May and June, while preparations for a common ADEX intraday continuous trading environment covering Serbia, Hungary and Slovenia continued through the autumn.
Average wholesale prices alone are no longer enough to assess renewable-project revenue. Solar plants can encounter low or negative prices during strong midday production, whereas evening scarcity raises the value of flexible generation and storage. Wind projects face similar difficulties when output coincides with grid congestion or weaker market prices.
Flexible demand, batteries and controlled curtailment can help generators respond to oversupply. Intraday trading can also bring electricity sales closer to updated generation forecasts and actual market conditions. These options increase the importance of trading and financing strategies that account for prices in individual hours.
Market optimisation and export evidence require separate treatment
Renewable projects face two parallel tasks: improving commercial returns through forecasting, balancing, intraday trading and storage, and retaining the documentation needed for an installation-specific emissions claim on EU exports. The two objectives may not coincide. An hour that offers the best wholesale arbitrage return may be unsuitable for a low-carbon export transaction if its contract, nomination or network evidence does not support the intended delivery route.
CBAM distinguishes electricity sold within Serbia from electricity imported into the EU under the mechanism. A Serbian generator can sell electricity domestically and monetise balancing services and environmental attributes under the applicable contracts and market arrangements. For EU import value, it must also address the authorised CBAM declarant, the physical power purchase agreement, evidence of cross-border delivery and the treatment of volumes that do not qualify for actual emissions data.
A favourable wholesale price and a strong generation profile therefore do not, by themselves, establish the additional value of an installation-specific emissions claim. Commercial planning has to address both the electricity market and the rules governing the intended export product. This makes delivery documentation a separate consideration from the price achieved for generation.
Storage financing depends on demonstrable revenue
Battery storage can shift the hour in which renewable electricity is sold, but that shift does not automatically make the discharged electricity renewable generation in the later hour under current CBAM rules. This distinction matters when a project seeks both wholesale-market returns and value from low-carbon electricity exports. The emissions treatment of a storage discharge must be assessed under the applicable legal and methodological framework.
The initial financing case for storage should rest on revenue streams that can already be demonstrated. These may include wholesale-price arbitrage, lower imbalance costs, reserve and flexibility services where available, and better shaping of contracted electricity deliveries. Lenders and investors should assess any additional CBAM-related value separately rather than treating a renewable source of charging electricity as proof of fixed carbon-related revenue.
That separation is especially relevant for batteries serving domestic trading and EU-facing exports. Their ability to earn revenue from price differences should be evaluated independently of the evidence available for the emissions characteristics of electricity delivered across the border. The same asset may support both activities without the two revenue cases having identical requirements.
Hourly prices call for hourly delivery records
Negative prices also reduce the usefulness of annual renewable-energy balances as a measure of value in a particular delivery period. A project may produce enough renewable electricity over a year while selling, buying or delivering different amounts during the hours relevant to a cross-border transaction. Hourly market signals therefore require comparably robust hourly evidence when an EU import depends on the characteristics of the electricity delivered.
As renewable capacity increases, market participants will need to forecast generation, manage nominations and reconcile settlements against delivery records. More granular data is needed to distinguish electricity by source and delivery period. Those records underpin both responses to domestic price volatility and claims associated with low-carbon EU imports.
Electricity products carry different documentation requirements
For Elektroprivreda Srbije (EPS), independent power producers, aggregators and traders, these developments point to a more segmented market. One product is conventional electricity priced against the relevant wholesale market and delivered through standard trading arrangements. Another combines electricity with Guarantees of Origin (GoOs) or other environmental attributes, subject to the applicable contractual and regulatory requirements.
A third product is an installation-specific export transaction structured around a particular CBAM emissions methodology. One generator may participate in all three markets, but the products do not amount to a single, loosely defined promise of green electricity. They have different commercial features, documentation requirements and potential risks.
Keeping the products distinct helps investors and lenders identify revenue backed by established contracts and market mechanisms, revenue dependent on environmental-attribute arrangements, and revenue conditional on substantiating a particular emissions treatment. Serbia’s renewable-energy development consequently involves investment not only in wind, solar and batteries, but also in trading, operational and data infrastructure. Projects able to forecast output, manage nominations, reconcile settlements and verify the path from production to final delivery will be better placed to capture value from domestic volatility and EU demand for low-carbon electricity.
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