The evolution of electricity markets in Europe is increasingly characterized by a hybrid pricing structure, where renewable energy sources dominate generation during many hours, while fossil fuels, particularly natural gas, play a critical role during periods of high demand and system stress. This duality is shaping the landscape of power trading across the Central and South-East European corridor, where the interplay of renewable expansion, fluctuating fuel prices, and cross-border electricity flows significantly influences price formation.
In 2026, the structure of electricity generation in the Central Europe–South-East Europe corridor reveals a diverse mix: approximately 31% hydropower, 19% coal-fired generation, 19% natural gas, 14% nuclear energy, 12% solar generation, and about 3% wind power. This layered hierarchy dictates how different technologies contribute to electricity pricing based on demand levels and renewable output conditions. Renewable sources like solar and wind typically have low marginal operating costs, allowing them to enter the market first and displace more expensive thermal generation during peak production hours.
Solar energy has seen rapid growth in countries such as Hungary, Romania, Greece, and Bulgaria. During sunny afternoons, photovoltaic systems can generate significant amounts of electricity, often exceeding several gigawatts. This surge in supply can lead to substantial drops in wholesale power prices during these hours, sometimes even approaching zero or becoming negative when demand is insufficient to absorb the excess generation.
Despite the increasing influence of renewables on pricing during daylight hours, the necessity for dispatchable power remains critical. As solar production declines after sunset and wind output becomes less predictable, natural gas plants frequently emerge as the marginal generators that set electricity prices. Their ability to quickly adjust output makes them well-suited for balancing fluctuations in supply and demand.
The impact of rising natural gas prices has been particularly pronounced in recent years. In 2026, geopolitical tensions disrupted global liquefied natural gas supplies, causing European gas benchmarks to double from approximately €31.95 per megawatt-hour to around €65.5 per megawatt-hour. This spike in gas prices reverberated through electricity markets across Central and South-East Europe, with day-ahead prices reaching €142.6 per megawatt-hour in Hungary and around €137.9 per megawatt-hour in Slovenia.
This interaction between renewable generation and gas marginality creates a distinctive price pattern known as the “duck curve,” where prices remain low during midday but rise sharply during evening demand peaks as reliance shifts to gas-fired plants. Hydropower plays a crucial role in moderating these fluctuations; its capacity to ramp up generation during high-price periods helps stabilize the market while taking advantage of peak revenues.
Cross-border electricity trading also significantly influences this hybrid price structure. When one market experiences rising prices due to reduced renewable output or increased fuel costs, imports from neighboring markets can alleviate some of that pressure. Hungary serves as a key hub for these transactions due to its strategic location at the intersection of several major transmission routes connecting Austria, Slovakia, Romania, Serbia, Croatia, and Slovenia.
As Europe progresses through its energy transition towards greater reliance on renewables for decarbonization goals, this hybrid market structure is expected to persist. The ongoing expansion of renewable capacity will continue to shape price dynamics; however, the variability inherent in these sources necessitates that flexible thermal plants remain integral to maintaining system reliability.
Emerging battery storage technologies may eventually alter this balance by providing additional flexibility within electricity systems. As storage capabilities grow, they could reduce dependence on gas plants for short-term adjustments. Nevertheless, large-scale deployment of such technologies is still nascent compared to overall European electricity demand.
The current trading environment reflects a transitional phase for European power markets where renewable generation increasingly dictates prices during many hours while fossil fuels retain significant influence during peak demand scenarios. Understanding these complex interactions will be essential for market participants navigating the evolving landscape of power trading across Europe.
