Serbia’s state power utility Elektroprivreda Srbije — EPS is trying to reposition itself from a lignite-heavy incumbent into a utility with a visible renewable, hydro and storage investment pipeline. The announcements are large: 1 GW of solar with 200 MW / 400 MWh of batteries, a possible 500 MW wind programme, more than €3 billion of green-energy investments by 2030, hydro revitalisation, the completion of Kostolac B3, and a formal decarbonisation pathway under which renewables would gradually overtake fossil generation in EPS’s production mix after 2035. The issue is not whether the announcements matter. They do. The sharper question is what they have changed in the Serbian power system so far.
The answer is: not yet enough at system level.
EPS remains fundamentally a thermal-and-hydro utility. Serbia’s electricity production in 2024 was still dominated by coal-fired plants, which accounted for 60.49% of total national output, while hydropower contributed 29.74%, wind 3.8%, solar only 0.25%, and biomass/biogas 0.86%. That production structure shows the actual position of the Serbian system more clearly than investment announcements do: solar and wind are growing, but EPS’s real operational backbone is still lignite, large hydro and legacy baseload assets.
EPS’s own recent performance confirms the point. In 2025, the company’s total electricity output was reported at 30,556 GWh, down 4% from the previous year. Thermal power plants generated 71.4% of EPS output, hydropower plants 27.3%, and the Pannonian combined heat-and-power plant 1.3%. EPS also said total investments in 2025 amounted to RSD 52.7 billion, lower than RSD 65.6 billion in 2024. That means EPS improved its financial result, but not because it had already transformed its generation mix.
The most important new investment is the 1 GW solar-plus-storage programme with Hyundai Engineering and UGT Renewables. The project covers solar power plants with total connection capacity of 1,000 MW, or around 1,200 MW nameplate capacity, supported by batteries of up to 200 MW / 400 MWh. The plants are planned across six locations, with major sites in the territories of Negotin and Zaječar at 460 MW and Bošnjace in Lebane at 302 MW. They are expected to produce around 1,600 GWh annually and to be delivered around 2028, after which they should be transferred to EPS following an initial operating period by the strategic partner.
This project is strategically important because it is not just solar. It is branded as a self-balancing solar programme, meaning the storage component is designed to reduce the system problems that pure solar would otherwise create: midday oversupply, imbalance exposure, curtailment and evening deficit. For Serbia, the 200 MW / 400 MWh battery package is therefore as important as the 1 GW solar number. It gives EPS a first institutional storage platform and creates a practical template for how future solar should be integrated into the grid.
But the actual effect is still mostly forward-looking. Until the plants are built and connected, EPS’s generation mix remains dominated by coal and hydro. The 1,600 GWh expected annual output would be meaningful once operational, but it would still equal roughly 5% of EPS’s 2025 production. It will help diversify EPS, reduce import exposure in sunny periods and improve Serbia’s renewable share, but it will not by itself replace the thermal fleet or remove the need for lignite flexibility, hydro dispatch and cross-border trading.
The second major announcement is EPS’s wind ambition. EPS and the Serbian government have discussed developing up to 500 MW of wind farms with a strategic partner, while the 1 GW solar project has been described as expected online around 2029 in public sector planning discussions. This matters because EPS historically lagged private investors in wind and solar, despite owning land, grid knowledge, hydro-balancing assets and a dominant retail position. A serious EPS wind programme would change the market by adding a state-backed competitor to private renewable developers.
The actual effect, again, depends on execution. Wind is more valuable to Serbia’s system than solar in some respects because wind generation can be more seasonal and less concentrated in midday hours. It can complement hydro and reduce winter import pressure. But a 500 MW EPS wind programme remains an investment plan, not an operating asset. Until procurement, permitting, grid connection, EPC selection and financing are resolved, private projects will remain the real source of new wind capacity in Serbia.
The third pillar is hydro and legacy asset renewal. The Serbian government has highlighted the revitalisation of HPP Đerdap 1, which added 114 MW of hydro capacity, and the completion of Kostolac B3, a 350 MW thermal unit. These are not greenfield renewable breakthroughs, but they have immediate system value. Hydro revitalisation improves flexibility and reserve capability. Kostolac B3 strengthens dispatchable capacity, even though it also deepens the carbon and lignite dependence of EPS’s portfolio.
This is the central tension in EPS strategy. The company is announcing renewables and decarbonisation, but its near-term security-of-supply logic still relies on coal. That is not unusual for a lignite-based utility in a region with volatile hydrology and rising imports. But it means EPS’s transition will be gradual, asset-by-asset, not a rapid pivot. Investors and industrial electricity buyers should therefore read EPS announcements as a portfolio-rebalancing strategy, not as evidence that Serbia’s power mix has already turned.
Financially, EPS has stabilised compared with the crisis years, but the quality of that recovery needs careful interpretation. EPS reported RSD 27.4 billion, or around €233.8 million, of profit in the first half of 2025, lower than the RSD 32.8 billion reported in the same period of 2024. For the full year 2025, EPS’s net profit reportedly rose sharply, while production still declined. That suggests the financial result was helped by tariff conditions, trading, cost control, hydrology, market prices or one-off factors, rather than by a completed investment transformation.
The actual market effects are therefore mixed.
For Serbian consumers, EPS investment announcements are positive because they point to future supply diversification and a lower need for emergency imports. But the immediate effect on retail prices is limited. New solar and storage will not materially lower consumer bills until assets are operational, financing costs are absorbed and generation is reflected in the portfolio. Serbia’s regulated and politically sensitive tariff structure means investment costs may also feed into future allowed revenues, not simply lower prices.
For industrial buyers, the EPS investment pipeline matters more. Large exporters exposed to EU carbon rules, CBAM-related documentation and supply-chain decarbonisation will increasingly need traceable lower-carbon electricity. EPS’s solar-plus-storage programme could eventually support cleaner supply products, especially if matched with metering, guarantees of origin, hourly data and credible allocation methodology. But today, EPS electricity is still overwhelmingly linked to Serbia’s coal-heavy residual system. The future commercial value will depend on whether EPS can turn new renewable production into documented, contractable, product-level electricity supply for industry.
For private developers, EPS’s move into renewables is both a validation and a threat. It validates the market because the state utility is now committing to the same technologies private developers have promoted for years. But it also creates a powerful competitor with better access to institutions, land, grid planning and political support. In a constrained grid environment, EPS-backed projects may receive higher strategic priority than speculative private pipelines. That could make Serbia’s renewable market more bankable at the top end but harder for smaller developers without advanced grid status.
For banks, EPS’s investment programme creates two opposite signals. On the positive side, utility-backed renewables are easier to finance than fragmented merchant projects, especially if the state supports offtake, grid integration and strategic-partner structures. On the negative side, EPS still carries legacy operational risk, coal-exposure risk, capex discipline risk and political-tariff risk. Banks will not assess EPS solar and wind projects only through technology cost; they will look at procurement transparency, EPC guarantees, battery degradation, grid-code compliance, revenue model, state support and the balance between regulated and merchant exposure.
For traders, EPS’s new assets could eventually change liquidity and volatility patterns. The 1 GW solar project would increase midday generation and may lower spot prices during sunny hours, especially in spring and summer. The 200 MW / 400 MWh BESS component can soften that effect by shifting part of the output into higher-value evening periods. But the battery is not large enough to neutralise all solar cannibalisation. It is a system tool, not a full hedge. Serbia will still need intraday trading, balancing capacity, hydro flexibility, imports, exports and demand-side response.
For OEMs and EPCs, EPS is becoming one of the most important buyers in the Serbian market. The Hyundai–UGT structure shows that Serbia is willing to use strategic-partner models for large renewable programmes. That opens space for international EPCs, solar suppliers, battery manufacturers, inverter providers, SCADA vendors and grid-integration companies. But it also raises the standard: EPS projects will require bankable warranties, grid compliance, long-term O&M, cybersecurity, Serbian permitting alignment and integration with EMS requirements.
The wider effect on Serbia’s energy transition is significant but not yet transformational. EPS’s decarbonisation action plan projects a future in which RES production from wind, solar and hydro grows enough for renewables to overtake fossil-fuel generation after 2035. In one long-term scenario, EPS would still supply 88% of national demand by 2050; in a more decentralised scenario, EPS would cover 63%, with independent producers supplying the rest. That shows the strategic ambition: EPS wants to remain Serbia’s dominant energy anchor even as the generation base changes.
The difficulty is timing. Serbia’s system needs flexibility before the full renewable pipeline arrives. EMS has already slowed connection procedures for many new renewable projects, showing that grid capacity and balancing resources are now the binding constraints. EPS’s own BESS programme is useful, but Serbia will need much more storage, demand flexibility, hydro optimisation, transmission upgrades and balancing-market reform if solar and wind are to scale without creating curtailment and negative-price risk.
The real test for EPS is therefore not whether it can announce investment volumes. It is whether it can convert announcements into measurable effects: lower import dependence, reduced coal intensity, stronger reserve margins, bankable renewable output, better trading performance, documented low-carbon electricity for industry, and lower system-cost volatility.
At the moment, the evidence points to a company in transition but not yet transformed. EPS has stabilised financially, kept its strategic role in the Serbian system, launched a major solar-storage programme and prepared a broader green-investment narrative. But actual production remains coal-heavy, solar remains negligible in the national mix, large projects are still several years from operation, and the system remains exposed to hydrology, lignite reliability, grid congestion and regional market volatility.
The most credible reading is that EPS is building the infrastructure for its next business model, while still operating with the asset base of the old one. The announcements are important because they set the direction of capital allocation. The actual effects will only become visible when the 1 GW solar-plus-BESS programme, future wind projects, hydro upgrades and grid-support investments begin to alter dispatch, trading positions and industrial electricity products in real time. Until then, EPS remains Serbia’s dominant power utility with a transition pipeline — not yet a transitioned utility.
