European electricity markets are increasingly defined by a hybrid price structure in which renewable generation dominates many hours of the day while fossil fuels continue to determine electricity prices during periods of system stress. This coexistence of low-cost renewable generation and flexible thermal generation represents one of the defining characteristics of the modern European power market. The electricity trading data observed in 2026 illustrates how this hybrid market structure operates across the Central and South-East European corridor, where renewable expansion, fuel prices, and cross-border trading flows interact to determine electricity price formation.
Electricity markets in Europe operate under a marginal pricing system in which the price for each hour is determined by the most expensive generation unit required to meet demand. Renewable technologies such as solar and wind typically enter the market first because their marginal operating costs are extremely low. Hydropower and nuclear plants follow due to their relatively low fuel costs and stable generation profiles. Thermal power plants, particularly those fueled by coal and natural gas, generally occupy the upper end of the merit order because their operating costs depend heavily on fuel prices and carbon costs.
The generation structure across the Central Europe–South-East Europe corridor in 2026 reflects this layered hierarchy of electricity supply. Regional electricity production consists of approximately 31 percent hydropower, 19 percent coal-fired generation, 19 percent natural gas, 14 percent nuclear energy, 12 percent solar generation, and about 3 percent wind power. Each of these technologies contributes differently to electricity price formation depending on demand levels, renewable generation conditions, and fuel price movements.
Renewable generation has become increasingly influential in shaping electricity prices during daylight hours. Solar generation, in particular, has expanded rapidly across countries such as Hungary, Romania, Greece, and Bulgaria. Photovoltaic installations can produce large volumes of electricity during sunny afternoons, often exceeding several gigawatts across the region. When solar generation peaks during midday hours, electricity supply increases dramatically, pushing more expensive thermal generators out of the merit order. This surge of low-cost electricity frequently causes wholesale power prices to fall significantly during these hours.
These midday price declines have become a recurring feature of European electricity markets. In some markets, electricity prices during sunny afternoons may fall close to zero or even become negative when renewable generation exceeds demand. Such price patterns illustrate the fundamental impact of renewable energy on electricity price formation. By providing large volumes of electricity at minimal operating cost, solar and wind generation effectively compress wholesale electricity prices during periods of strong renewable output.
However, renewable generation does not eliminate the need for dispatchable power plants capable of responding to fluctuations in supply and demand. Solar generation declines rapidly after sunset, while wind output can fluctuate unpredictably depending on weather conditions. When renewable output falls, electricity systems must rely on other generation technologies to maintain supply. This is where natural gas plants frequently become the marginal generators that determine electricity prices.
Natural gas power plants possess several characteristics that make them particularly suitable for balancing renewable generation. Gas turbines can start and stop relatively quickly compared with coal or nuclear plants, allowing them to respond rapidly to changes in electricity demand or renewable output. This flexibility allows gas plants to increase generation during evening hours when solar production disappears or during periods when wind generation declines unexpectedly.
The influence of gas-fired power plants on electricity prices becomes especially visible during periods of elevated fuel prices. In 2026, natural gas prices experienced a sharp increase as geopolitical tensions disrupted global liquefied natural gas supply routes. European gas benchmarks rose from approximately €31.95 per megawatt-hour to around €65.5 per megawatt-hour, doubling within a short period. Because gas plants frequently operate as marginal generators, this fuel price shock quickly propagated into electricity markets across Central and South-East Europe.
The effect of rising gas prices on electricity markets was visible in day-ahead electricity prices across the region. During the same period, electricity prices reached approximately €142.6 per megawatt-hour in Hungary, €137.9 per megawatt-hour in Slovenia, and around €134.6 per megawatt-hour in Croatia. Prices in Romania and Bulgaria approached €126.6 per megawatt-hour, while the Serbian market recorded prices near €99.6 per megawatt-hour. These price levels demonstrate how gas price fluctuations can influence electricity markets even when gas generation represents a relatively modest share of total electricity production.
This interaction between renewable generation and gas marginality creates a distinctive price pattern across European electricity markets. During daylight hours with strong solar generation, electricity prices may remain relatively low because renewable supply dominates the merit order. However, as renewable output declines during the evening, gas plants frequently become the marginal generators required to meet demand. At that point, electricity prices rise sharply to reflect the cost of operating gas-fired power plants.
The resulting price pattern produces what traders often describe as the “duck curve,” in which electricity prices remain low during midday hours before rising rapidly during evening demand peaks. This phenomenon has become increasingly common across electricity markets with high solar penetration. The duck curve reflects the combination of abundant solar generation during daylight hours and the sudden disappearance of that generation after sunset.
Hydropower plays an important role in moderating these price fluctuations. Reservoir-based hydroelectric plants can increase output during evening hours when electricity prices rise, partially offsetting the decline in solar generation. Because hydropower accounts for approximately 31 percent of electricity generation across the Central and South-East European region, it provides significant flexibility within the electricity system. By shifting generation across hours, hydro operators can help stabilize electricity prices while capturing higher revenues during peak demand periods.
Cross-border electricity trading further influences the hybrid price structure observed in European electricity markets. When electricity prices rise sharply in one market due to reduced renewable generation or high fuel costs, electricity imports from neighbouring markets can help moderate the price increase. Interconnectors linking national electricity systems allow electricity to flow toward higher-priced markets until prices converge or transmission capacity becomes fully utilized.
Hungary plays a particularly important role in transmitting these price signals across the Central Europe–South-East Europe corridor. Positioned at the intersection of several major transmission routes, Hungary connects electricity markets in Austria, Slovakia, Romania, Serbia, Croatia, and Slovenia. As a result, price movements in the Hungarian electricity market often reflect broader regional supply and demand conditions. When electricity prices rise in Central Europe due to higher gas costs or reduced renewable generation, these price signals frequently propagate through Hungary into neighbouring markets.
The coexistence of renewable generation and gas marginality therefore creates a complex electricity price structure in which different generation technologies dominate price formation at different times of the day. Renewable energy frequently determines prices during hours of abundant solar or wind output, while gas plants set prices during periods when flexible generation becomes necessary to maintain system balance.
This hybrid structure is likely to persist for several years as Europe continues its energy transition. Renewable generation will continue to expand across the continent as countries pursue decarbonization goals and invest in solar and wind capacity. However, the variability of renewable generation means that flexible power plants will remain essential for maintaining system reliability. Natural gas plants currently provide much of this flexibility, ensuring that gas markets remain closely linked to electricity price formation.
Battery storage technologies may gradually alter this relationship by providing additional flexibility within electricity systems. Large battery installations can store electricity during periods of low prices and release it when demand rises. As storage capacity expands, batteries may reduce the reliance on gas plants for short-term balancing. However, large-scale deployment of storage technologies remains in its early stages relative to the size of European electricity demand.
The electricity trading environment observed in 2026 therefore reflects a transitional phase in the evolution of European power markets. Renewable generation has become a dominant force shaping electricity prices during many hours of the day, but fossil fuels—particularly natural gas—continue to exert strong influence during periods of system stress. This hybrid market structure creates both challenges and opportunities for electricity traders, who must navigate a complex landscape of fuel prices, renewable generation patterns, and cross-border electricity flows.
As Europe continues its transition toward a lower-carbon electricity system, the interaction between renewable generation and flexible thermal generation will remain a central determinant of electricity price formation. Traders, utilities, and system operators will increasingly rely on sophisticated forecasting models to anticipate changes in renewable output, fuel prices, and demand conditions. In this evolving environment, understanding the hybrid price structure of European electricity markets will remain essential for interpreting the dynamics of power trading across the continent.