Serbia’s planned 500 MW gas-fired power plant near Niš, developed in cooperation with Azerbaijan’s SOCAR, could strengthen the electricity system as renewable generation expands and ageing lignite plants face reliability challenges. The project is targeting operation around 2030 and could also provide approximately 150 MW of thermal energy to Niš.
The investment would help Serbia reduce exposure to electricity imports, but its competitiveness will depend on securing reliable gas supplies, predictable fuel prices and financing suited to Europe’s changing energy market.
Gas Supply and Pricing Determine Project Viability
A modern 500 MW combined-cycle gas turbine (CCGT) could consume approximately 0.5–0.7 billion cubic metres of gas annually, depending on efficiency and utilisation. At a 70% capacity factor, it could generate around 3.1 TWh of electricity per year, equivalent to more than 10% of Serbia’s current annual final electricity consumption.
Serbia and Azerbaijan have discussed increasing Azerbaijani gas deliveries to approximately 0.9 bcm annually before the plant begins operating, potentially rising to 1.4 bcm afterwards. Available national supply does not automatically guarantee fuel for the project. Financing would normally require long-term contracts specifying volumes, prices, transportation rights, supply interruptions and compensation arrangements. SOCAR’s involvement as a potential shareholder and gas supplier could link fuel procurement with the plant’s operating economics, but transparent contractual terms would remain essential.
Pipeline Access and Financing Challenges
The Serbia-Bulgaria gas interconnector, with annual capacity of approximately 1.8 bcm, provides access to Azerbaijani gas transported through the Southern Gas Corridor and potentially LNG supplied through Greece. Serbia is also developing or discussing additional connections with Romania and North Macedonia while expanding domestic transmission and storage infrastructure.
These connections improve supply options but do not guarantee sufficient gas during regional shortages, when electricity and heating demand may rise simultaneously. Financing presents another challenge. European public financial institutions have restricted support for unabated fossil-fuel generation, while commercial lenders increasingly assess carbon-transition risks and the possibility of declining plant utilisation.
The project could therefore rely on EPS, SOCAR and Srbijagas equity, commercial loans, export-credit financing or funding associated with equipment suppliers and Azerbaijani institutions. Long-term electricity revenues and contracted heat sales could strengthen the financing case, although proposed thermal output would require reliable infrastructure and offtake agreements.
Flexible Generation Could Support Renewable Integration
Serbia is targeting several gigawatts of additional wind and solar capacity by 2030. The resulting fluctuations in generation could increase demand for flexible plants capable of responding to evening peaks, renewable output changes, hydropower shortages and unplanned outages at EPS coal units.
A modern CCGT could also participate in balancing and reserve markets. Its economic value may therefore depend more on operating during high-demand periods than on generating continuously. This would require gas contracts that accommodate daily and seasonal variations in consumption, rather than arrangements designed exclusively for stable baseload production.
Electricity Security Comes With Greater Gas Price Exposure
Producing approximately 3 TWh annually could materially affect Serbia’s electricity balance, although the output would not translate directly into an equivalent reduction in imports. Depending on market conditions, the plant could displace imported electricity, reduce lignite generation or support exports. Additional dependable capacity could reduce exposure to extreme import prices during coal outages, low hydropower production and weak renewable generation.
Greater reliance on gas-fired generation would also expose Serbian wholesale electricity prices more directly to European gas markets and carbon costs. Gas produces less carbon dioxide per MWh than lignite but remains a fossil-fuel source subject to tightening climate policies.
The plant’s investment case will therefore need to account for higher carbon prices, potentially lower operating hours and competition from batteries, pumped storage and demand-side flexibility. Before making a final investment decision, EPS and SOCAR will need to demonstrate secure long-term gas volumes, competitive pricing, guaranteed transportation capacity and a financing structure capable of withstanding tighter fossil-fuel lending conditions.
