IN Brief:
- SolarPower Europe estimates EU solar generation avoided €20 billion of gas imports over 137 days.
- The calculated saving averages approximately €146 million for each day covered by the analysis.
- Solar supplied around one-quarter of EU electricity during June, increasing demand for storage and flexible consumption.
SolarPower Europe estimates that electricity generated by the European Union’s photovoltaic fleet avoided €20 billion of gas imports between 1 March and 15 July 2026.
Covering 137 days, the calculation equates to average avoided expenditure of approximately €146 million per day. It models the volume of gas-fired generation that might otherwise have been required without the recorded solar output and applies fuel-market values across the period.
The result represents an estimate of avoided fuel costs rather than a direct financial saving recorded by individual utilities, businesses, or consumers. Actual effects differ between countries according to generation mix, interconnector flows, gas-plant efficiency, fuel contracts, wholesale prices, curtailment, and local network constraints.
SolarPower Europe also records that photovoltaic generation became the EU’s largest single source of electricity during June, supplying approximately one-quarter of total output. Rapid capacity additions, combined with strong seasonal production and long daylight hours, have raised solar’s contribution to a level that can materially alter conventional generation schedules.
When photovoltaic output is available, gas-fired stations can reduce their generation and consume less imported fuel. Gas plants nevertheless remain important for balancing, reserve, evening demand, prolonged low-renewable periods, and locations where network congestion prevents surplus solar output from reaching consumers.
Solar production is concentrated during daylight hours, with its highest output commonly arriving around midday. Demand peaks often occur later, particularly during the evening, while overnight requirements must be met by other generation, stored energy, demand response, or imports.
The expanding solar fleet is therefore changing both the quantity and timing of conventional generation. It is also increasing the value of batteries, interconnection, industrial load shifting, thermal storage, electrolysis, and other technologies capable of absorbing electricity during periods of high renewable output.
Those requirements become more pronounced as additional capacity connects below the transmission network. Rooftop and commercial installations can create reverse power flow and voltage rise on local circuits that were originally designed to carry electricity in one direction from the substation to the consumer.
Fuel savings reshape system operation
High solar penetration can suppress wholesale prices during the middle of the day, occasionally producing zero or negative prices when output exceeds demand and export capability. Record photovoltaic generation has already intensified European price volatility and curtailment pressure.
Although those conditions do not remove the value of displaced gas, they change the way that value is captured. Curtailment discards available low-marginal-cost generation, while network reinforcement, storage, interconnection, and flexible demand allow a larger share of the output to be used.
Battery storage can transfer part of the midday surplus into the evening, but commercial performance depends on price spreads, degradation, charging and discharge losses, connection limits, network charges, and participation in balancing markets. Pumped storage, thermal systems, hydrogen production, and rescheduled industrial processes can provide different combinations of duration, power, and flexibility.
Distribution networks can also use smart inverters, voltage-control equipment, revised transformer settings, flexible export agreements, and local storage to defer reinforcement. Each intervention has an operating limit, however, and planners must assess the combined behaviour of many installations rather than treating every photovoltaic system in isolation.
The avoided-import calculation carries an energy-security dimension because gas prices can react rapidly to geopolitical events, supply interruptions, storage levels, pipeline availability, and global liquefied natural gas demand. Domestic renewable generation reduces the quantity that must be purchased but cannot remove exposure while gas remains part of the marginal generation mix.
Firm capacity must remain available even when gas plants run for fewer hours. Generators that operate less frequently may require capacity payments, reserve contracts, or other market arrangements to remain financially viable while continuing to support peak demand and extended periods of weak renewable output.
Solar’s seasonal profile creates a further distinction between annual energy and winter security. Strong summer generation can reduce gas burn and support storage inventories, whereas winter adequacy depends more heavily on wind, firm generation, interconnection, storage duration, and demand management.
The €20 billion estimate demonstrates the scale that photovoltaic generation has reached within Europe’s power system. Continued expansion will rely increasingly on the coordination of panels with networks, markets, storage, forecasting, flexible consumption, and generation capable of supporting the system when solar output falls.
Further details of the calculation are available through SolarPower Europe’s published analysis.
