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Renewables pass fossil fuels, gas bill rises

3 min read

22:33UTC

Wind and solar generated more EU electricity than fossil fuels for the first time in 2025, yet the power sector's gas bill still climbed 16%.

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Key takeaway

Wind and solar hit 30% of EU generation in 2025, but the gas bill still rose 16% on hydro shortfalls.

Ember published its European Electricity Review showing wind and solar exceeded fossil fuels in EU electricity generation for the first time in 2025: renewables at thirty percent against fossil fuels' share. The milestone marks a structural shift in the generation mix. But the EU power sector's gas import bill still reached EUR 32 billion in 2025, up 16% year-on-year, because gas generation itself rose 8% to compensate for reduced hydro output.

The transition insulates unevenly. Spain is largely protected from TTF pass-through; Italy, the Netherlands, and Belgium are fully exposed. Ember's data confirms that the merit order mechanism, where the most expensive fuel needed to meet demand sets the price for all generation, means gas retains pricing power far beyond its share of actual generation. In markets where gas sets the marginal price most hours (Italy being the clearest case), the rising renewables share delivers environmental benefit but limited consumer price relief.

The structural implication for traders: EU-wide renewables statistics overstate the degree to which the bloc is insulated from gas price shocks. Market-by-market merit order composition, not aggregate generation share, determines price exposure.

Deep Analysis

In plain English

In 2025, for the first time ever, European wind turbines and solar panels produced more electricity than all fossil fuels combined. This sounds like a major milestone for clean energy, and in generation terms it is. But here is the complication: Europe's gas import bill for electricity still went up by 16%, to EUR 32 billion. This is because wind and solar do not blow and shine all the time. When they stop, something else needs to fill in quickly, and right now gas stations are the primary backup. Gas is now used less for routine power but more for emergency top-ups, which happen to be at the most expensive market hours.

Deep Analysis

Root Causes

The simultaneous achievement of renewable majority and rising gas bills reflects the merit order's structural mechanics: wind and solar push gas out of baseload hours but increase gas's role in marginal hours, where gas must provide rapid ramping to cover renewable generation shortfalls.

Gas-fired plants running fewer hours but at higher marginal prices can generate the same or higher revenue, and their fuel costs per unit of production are higher because they operate less efficiently at low capacity factors.

The hydro shortfall is the second structural factor. European reservoir hydro output fell 8% in 2025 due to below-average Alpine snowpack and drought in Iberia's river basins. Gas compensated for this on an essentially unplanned basis, at spot prices, because the hydro shortfall was not foreseeable six months in advance when storage injection contracts were placed.

What could happen next?

Consequence
The EUR 32 billion gas bill for power generation creates a permanent structural argument for accelerating battery storage and interconnection investment, as each alternative capacity unit reduces the volume of spot gas purchased at peak prices.
Risk
If Alpine hydro output continues below long-run averages due to climate-related snowpack decline, gas compensation demand will remain a structural feature of EU electricity markets regardless of renewable capacity growth.

Source Landscape

This story draws on mixed-leaning sources from Belgium

Belgium

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Primary parallel: Germany's Energiewende faced the same paradox in 2013-16: renewable capacity exceeded coal and nuclear in installed capacity, but gas and coal consumption still grew as hydro output fell and solar/wind variability required flexible backup generation. German industrial gas consumption peaked in 2016, not 2013 as originally modelled, because the transition created demand for flexible gas backup that the original planning had not fully accounted for.

Counter-parallel: Denmark reached over 50% wind generation share in 2015 without a corresponding gas demand rise, because Danish interconnectors with Norway and Sweden provided hydro balancing at marginal cost. The EU-wide position lacks this balancing capacity: Norwegian hydro is insufficient to backstop the whole continental grid.

The EUR 32 billion gas bill on top of significant EU wind and solar subsidies (estimated at EUR 50-60 billion annually in feed-in tariff and contract-for-difference obligations) suggests the EU is paying for two energy systems simultaneously. The renewable subsidy cost supports low-carbon capacity; the gas bill pays for the flexibility that makes renewables-heavy grids operational.

The critical policy implication: EUR 32 billion in annual gas purchases is the economic incentive for accelerating battery storage, demand response, and cross-border interconnection. Each percentage point reduction in gas-at-the-margin hours reduces the gas bill by approximately EUR 640 million at current prices, providing a precise investment return metric for flexibility alternatives.

Consensus view: Ember lead analyst Dave Jones assessed that the 2025 result is an efficiency paradox: wind and solar achieved generation majority, yet gas demand rose because the energy transition has not yet replaced gas in its two remaining dominant roles (heating load following and hydro backup). The EUR 32 billion gas bill reflects that these residual uses involve purchasing gas on spot at peak prices, not baseload contract prices.

Counter-view: The Institute for Energy Economics and Financial Analysis (IEEFA) argued that the EUR 32 billion figure overstates the structural problem: a significant portion reflects strategic storage injection at elevated prices, which is a deliberate choice rather than unavoidable demand. If the EU had maintained pre-crisis storage norms, the actual operational gas bill would be approximately EUR 18 billion, with the premium attributable to forced emergency injection.

Key tension: Whether the rising gas bill despite renewables majority reflects an unavoidable structural transition gap (requiring a decade of further investment in seasonal storage alternatives) or a policy failure in gas demand management (solvable through accelerated heat pump deployment and demand flexibility mechanisms).

Sources:Bruegel·Ember

Mentions:Russia →Ember →European Union →Netherlands →Denmark →Belgium →Prima →Italy →Sweden →Norway →Germany →TTF →

First Reported In

Update #1 · Europe's thinnest gas cushion since 2018

Bruegel· 13 Apr 2026

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Causes and effects

This Event

Renewables pass fossil fuels, gas bill rises

The paradox of rising renewables share alongside a rising gas bill exposes the merit order's structural flaw: even a minority fuel can set prices for the majority of hours.

Led to

Spain power jumps 148% in two days on low wind

The Ember renewable generation thesis (wind/solar exceeding fossil in 2025) is tested in real time as low-wind conditions push Spanish gas peakers into the merit order.

Occurred 15 Apr 2026

Read story →

Different Perspectives

EU carbon and storage regulators

EUA carbon broke EUR 81/tonne on 13 July as the ETS Market Stability Reserve's scheduled withdrawals met fresh fuel-switching demand from France's nuclear curtailment. Brussels' mandatory storage-fill rule kept German and French injection running regardless of the TTF swings, the mechanism working as designed four years after the 2022 shock.

Equinor

Equinor returned its Asgard field from maintenance on 11 July, lifting Gassco's exit nominations to 319.8 mcm/day just as TTF round-tripped on Hormuz risk. The restart gave Norway spare pipeline capacity to help Europe absorb the gas rally without drawing down storage, reinforcing its role as the post-2022 swing supplier.

Germany

Germany briefly became the cheaper leg of the FR-DE spread on 12 July as French reactors went offline, while its own storage injection tripled to 723 GWh on 11 July under the EU's mandatory fill rule. Berlin's CCGT fleet absorbed the extra load at a time when EUA's climb past EUR 81 is raising its own marginal cost too.

EDF

EDF took Chooz, Golfech and Bugey fully offline on 12 July under river-cooling discharge limits, then secured a temperature exemption for Bugey to 20 July rather than wait for the rivers to cool. The government's willingness to relax the environmental ceiling shows French grid security now outweighs the permit breach when reactor hardware itself is undamaged.

Storage and injection-pace desk

EU storage sat at 51.1% on 8 July, still running below the pace needed for an 80% November target, and the JKM-TTF Asia premium of roughly USD 1.4-2.4/MMBtu was already pulling marginal cargoes east before Qatar's withdrawal compounded the gap. October's top-up remains the binding constraint, not this week's price level.

EDF / France

EDF added Chooz to its heat-curtailment watch list as a precaution against the second heat dome peaking 9-14 July, alongside standing warnings at Blayais, Bugey, Golfech and Saint-Alban. No output cut has been confirmed at any site as of 10 July.