For most of the liberalized electricity market era in Europe, wholesale electricity prices were largely determined by fossil fuel costs. Natural gas, in particular, served as the dominant marginal fuel in many markets. Combined-cycle gas turbines frequently provided the final increment of electricity required to balance supply and demand, meaning that electricity prices often tracked movements in gas benchmarks such as the Dutch TTF hub.
This structural relationship defined electricity market dynamics for more than two decades. When gas prices rose, electricity prices followed. When gas prices declined, electricity prices typically fell as well. The tight correlation between these two markets shaped trading strategies, hedging models and long-term power purchase agreements across Europe.
However, the rapid expansion of renewable generation is gradually weakening this relationship. Wind and solar energy have extremely low marginal costs because they require no fuel. When renewable output increases significantly, these sources displace gas-fired generation in the dispatch order. As a result, gas plants operate fewer hours and set electricity prices less frequently.
This shift can be observed in several European markets where renewable capacity has expanded rapidly over the past decade. Spain offers a clear illustration of this trend. At the start of 2026, strong wind generation and increased hydro output significantly reduced the amount of electricity produced by gas-fired power plants. Gas generation fell by roughly 2.4% compared with the same period in the previous year, reflecting the growing ability of renewable energy to meet electricity demand without relying on fossil generation.
Although this change appears relatively small in percentage terms, it signals a broader transformation in electricity price formation. Each hour in which renewable generation replaces gas generation represents a moment when electricity prices become less dependent on fuel costs.
Over time, this process gradually decouples electricity prices from gas prices.
The implications for electricity markets are profound. When gas plants set the marginal price less frequently, the traditional relationship between gas markets and power markets becomes weaker. Electricity prices increasingly depend on weather conditions and renewable availability rather than fuel costs.
This shift introduces new forms of volatility into electricity markets. Renewable generation fluctuates with weather conditions, meaning electricity supply can change rapidly. Strong wind conditions can push electricity prices downward, while sudden drops in renewable output can lead to rapid price increases as dispatchable generation becomes necessary.
For traders, this transformation requires a new analytical approach. Traditional models based primarily on fuel price correlations are no longer sufficient. Instead, electricity market analysis increasingly incorporates meteorological forecasting, renewable production modelling and grid constraint analysis.
Forward electricity markets are also adjusting to this evolving structure. Long-term power prices increasingly reflect expectations about renewable capacity growth rather than gas price trajectories. In markets with ambitious renewable expansion targets, traders anticipate that gas plants will play a diminishing role in price formation over time.
However, natural gas is unlikely to disappear entirely from electricity systems in the near future. Gas-fired plants remain essential for balancing electricity supply during periods of low renewable output. They provide flexibility that intermittent renewable sources cannot yet fully replace.
The role of gas in electricity systems is therefore evolving rather than disappearing. Instead of acting as baseload generation, gas plants are increasingly used as flexible backup capacity.
This shift has important implications for market design and energy policy. Electricity markets must ensure that sufficient dispatchable capacity remains available even as operating hours decline. Capacity markets, balancing mechanisms and ancillary service payments are increasingly used to compensate generators for maintaining availability rather than simply producing electricity.
For power traders and investors, the gradual decoupling of electricity prices from gas markets represents one of the most significant structural changes currently underway in Europe’s energy system. Understanding this transition is essential for interpreting price signals, forecasting market behaviour and identifying emerging trading opportunities.
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