The energy landscape in South-East Europe is undergoing a significant transformation, driven by the emergence of large-load demand from data centres, AI infrastructure, and electrified industrial sectors. This shift is altering traditional demand growth assumptions and reshaping the regional power market, which has historically been influenced predominantly by supply-side factors such as renewable energy capacity and cross-border electricity trade. The International Energy Agency (IEA) forecasts that global electricity demand from data centres will more than double to approximately 945 TWh by 2030, with an annual growth rate of around 15% from 2024 to 2030. Moreover, data centres are projected to contribute to 10% of the EU’s electricity demand growth by 2030 under current policies.
South-East Europe is entering this new demand cycle from a unique position compared to established data centre markets in Western Europe. Factors such as lower land costs and strategic geographical advantages make the region increasingly attractive for cloud computing and telecom applications. According to CBRE’s 2025 global data centre assessment, power availability varies significantly across emerging markets, with some projects being redirected to regions where demand is less saturated. Concurrently, rising around-the-clock electricity demand from new data centres is expected to contribute to ongoing power price volatility across Europe.
Greece stands out as a leader in this evolving market, with projections indicating that its data centre capacity will more than double by 2030. This growth is supported by strategic submarine cable landings and a variety of large-scale digital infrastructure projects. A notable development includes the joint venture between IPTO and Serverfarm, aimed at constructing hyperscale data centre infrastructure in Greece, integrating power-grid capabilities with digital load development.
Romania is also making strides in accommodating large-load demands, exemplified by a partnership between Accelerated Infrastructure Capital and ClusterPower, which plans an 800 MW data centre build-out in southwestern Romania. This facility could consume between 5.5–7.0 TWh annually, representing a significant portion of national electricity demand growth and altering local generation economics, transmission reinforcement, and storage deployment strategies.
Serbia is still in the early stages of this transition but shows promising signs of growth. Plans for a new data centre in Niš, set to begin construction in 2026, indicate a shift towards broader digital infrastructure beyond public-sector compute capacity. As Serbia grapples with connection queues and transmission bottlenecks, the introduction of consistent digital loads could reshape pricing dynamics within the power market.
The financial implications of this evolving landscape are substantial. Traditional power markets in South-East Europe have been characterized by supply-side volatility stemming from hydrological conditions, gas pricing fluctuations, and renewable intermittency. In contrast, data centre demand typically features high load factors and stringent reliability requirements, leading to concentrated growth patterns that can justify significant investments in transmission upgrades and grid reinforcement.
This changing dynamic impacts local pricing structures as well. The integration of large digital loads introduces relatively inelastic demand during off-peak hours, effectively raising local price floors. While midday solar oversupply persists, areas with concentrated data centre activity may absorb this surplus more effectively, leading to tighter spreads between surplus hours and moderate-demand periods.
The implications for renewable energy developers are profound. Projects located near growing digital-load clusters may achieve higher effective capture prices compared to those situated in weaker demand zones. This trend underscores the necessity for project models that account for localized effects rather than relying solely on national price averages.
The potential for Romania’s 800 MW data-centre initiative illustrates how large-load clusters can alter regional dispatch assumptions and absorb significant portions of renewable output that might otherwise depress local prices. Such developments necessitate layered power strategies that include firm grid connections, backup generation, and storage solutions to ensure resilience.
A numerical analysis highlights the scale of these developments: an 800 MW facility could consume up to 6.3 TWh per year, sufficient to support multiple gigawatts of renewable Power Purchase Agreements (PPAs) and substantial battery storage capacities while necessitating major transmission enhancements.
The evolving energy landscape also positions Greece advantageously within international connectivity frameworks for cloud services. Greek power prices remain volatile yet offer opportunities for battery arbitrage, while the increasing digital demand strengthens the case for long-term renewable procurement strategies.
The trend toward long-duration power contracting is gaining traction among regional telecom operators, as evidenced by Orange Romania’s ten-year virtual PPA with Engie Romania for 40 GWh per year. This shift reflects a broader move away from reliance on spot markets toward stable procurement methods suitable for continuous loads.
This emerging demand shock has direct implications for renewable project financing models. Previously reliant on optimistic price forecasts and moderate leverage ratios, projects now benefit from nearby digital-load off-takers acting as credit anchors that enhance bankability through contracted cash flows.
The capital expenditure (CAPEX) considerations are equally critical; large digital loads often necessitate grid reinforcements while simultaneously justifying them through increased capacity for renewables and storage solutions. Data-centre demand acts as a catalyst for grid investments akin to major industrial plants historically justifying transmission upgrades.
The energy planning framework in Serbia anticipates rising electricity demands through 2030, influenced by various factors including industrial electrification and expanding data centre operations. Even without immediate hyperscale developments, Serbia could experience meaningful incremental load increases if current projects progress successfully.
The trajectory suggests that Serbia might not see an immediate hyperscale cluster but could witness cumulative increases in digital loads reaching low terawatt-hour levels by 2030. This shift would bolster baseload demands while alleviating midday softness in well-connected nodes, enhancing the viability of storage solutions and industrial-style PPAs.
The Romanian market appears poised for scalable investment first with its substantial data-centre initiative driving dedicated power strategies that extend beyond traditional wholesale competition into structured supply arrangements tailored for digital infrastructure needs.
This evolving scenario emphasizes the need for platforms like Electricity.Trade that facilitate visibility into node-level pricing dynamics and congestion patterns essential for aligning generation capacities with emerging round-the-clock buyers. Understanding these trends will be crucial as South-East Europe transitions towards a dual narrative of flexible supply coupled with anchored demand.
The future power landscape will likely reflect not only regional disparities but also the increasing importance of digital load as a key asset within the electricity system—an evolution that stakeholders must navigate carefully as they adapt their strategies accordingly.
