13APR

Spain power jumps 148% in two days on low wind

3 min read

22:33UTC

Spanish day-ahead cleared at EUR 71.91/MWh, up from EUR 29 on 13 April, as a generation-side shortfall pushed gas peakers into the stack.

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Key takeaway

Iberian insulation is real over a year and fragile over a day.

Spain cleared at EUR 71.91/MWh in day-ahead power on 15 April, up 148% from EUR 29/MWh on 13 April and compressing the Italy-Spain spread from EUR 104 on Monday to EUR 70 on Wednesday, a 33% narrowing in two sessions ¹. Italy cleared at EUR 141.90/MWh, France at EUR 72.41, Germany at EUR 117.53; the ENTSO-E feed shows the Italy-Germany gap widening while the Franco-Iberian pair moved to near-parity.

The prior briefing had positioned the Italy-Spain gap as the canonical case of merit-order divergence, with gas setting Italy's price the majority of hours and wind plus solar setting Spain's . A 148% one-way move over two sessions is the mechanism in reverse: a low-wind day compounded by hydro de-rating pushed Spanish gas-fired peakers up the merit order, clearing into a gas-set stack. Iberian insulation is a probability-weighted advantage across a year, not a constant across a day.

France printing EUR 45 beneath Germany on the same day points to the setup through Q2: French nuclear surplus behaves like a southern-European asset, and the Franco-Iberian interconnector becomes the arbitrage of the week on any repeat low-wind print.

The implication for industrial relocation arguments that lean on Iberian power-cost structure is that those arguments survive only if the user can tolerate the dispersion around the mean. On a low-wind day Spain prices into the gas stack; on a high-wind day it prices off the renewables stack. The day-ahead print, not the monthly average, is what settles P&L.

Deep Analysis

In plain English

Spain's electricity system runs mainly on wind and solar power, which in a normal week means Spanish electricity is among the cheapest in Europe. On 15 April, the wind effectively stopped. In the European electricity market, the price is set by the most expensive generator needed to meet demand at any given hour. When wind generation drops, Spain needs to fire up gas power stations instead, and those stations charge what the gas costs them to run. At current gas prices, that is roughly EUR 70/MWh. Two days earlier, Spain was running almost entirely on renewables and paying EUR 29/MWh. The 148% jump is entirely the result of weather, not any policy or supply disruption. It will reverse once wind picks up.

Deep Analysis

Root Causes

Spain's power price architecture creates an inherent volatility asymmetry. On high-renewables days, Spain is largely insulated from gas prices (gas sets the clearing price only 15% of hours per year per Ember/). On low-renewables days, the transition to gas-clearing is total and abrupt because no intermediate generation stack exists between renewables and peakers.

The Iberian peninsula's limited interconnection with France (approximately 2.8 GW southbound capacity) means French nuclear surplus cannot fully absorb demand during merit-order switches, so gas peakers are forced into merit rather than imports covering the gap.

What could happen next?

Consequence
The Italy-Spain spread compression from EUR 104 to EUR 70 on 15 April demonstrates that weather volatility can narrow the insulation benefit Spain's renewable buildout provides, temporarily making Spain's price profile resemble gas-heavy markets.

Source Landscape

This story draws on neutral-leaning sources

Primary parallel: Spain experienced a structurally identical spike on 2 January 2021, when day-ahead prices hit EUR 89/MWh after Storm Filomena cut wind output and froze several hydro plants simultaneously. The mechanism is the same: a weather-driven removal of cheap generation forces gas into merit at gas-cost-derived prices. The 2021 spike provoked the Iberian exception mechanism negotiated in 2022, which temporarily capped gas prices in Spain's power market until July 2023.

Counter-parallel: Germany on 15 April cleared at EUR 117.53/MWh without any weather event, purely on gas-cost pass-through through coal and gas plants. Spain's EUR 71.91/MWh is structurally lower because wind re-enters merit once weather normalises; Germany's elevated clearing price is stickier because it reflects a higher gas-exposed generation mix with less renewable variance.

Consensus view: Ember Energy's EU electricity analyst Dave Jones documents that Spain's merit order has two distinct regimes: when wind and solar generation exceeds roughly 55% of instantaneous demand, gas-fired peakers are entirely out of merit and Spain clears at near-zero or very low prices.

When wind drops below that threshold, the same gas peakers re-enter at their gas-cost-derived marginal price, which at EUR 42/MWh TTF is approximately EUR 65-70/MWh all-in including carbon costs. The 148% price spike is the result of a mechanical merit order switch, not a supply shock.

Counter-view: Red Eléctrica de España analysts note that Spain's hydro reservoir levels in April 2026 were running 12% below seasonal norms after a dry winter in the Pyrenees and Cantabrian catchments, meaning hydro was already partially de-rated before the low-wind day. The interaction of both deficit variables simultaneously is unusual and amplified the spike beyond what either factor alone would have produced.

Key tension: Whether Spain's grid architecture can absorb these merit-order switches through interconnection with France and Portugal, or whether the inter-connector capacity is the binding constraint that forces gas peakers into merit rather than importing French nuclear surplus.

Sources:euenergy.live (ENTSO-E feed)·euenergy.live (ENTSO-E feed)

Mentions:Russia →Italy →France →Day-ahead market →Portugal →Prima →Germany →TTF →Ember →

First Reported In

Update #2 · TTF EUR 42 as Russian LNG ban enters range

euenergy.live (ENTSO-E feed)· 15 Apr 2026

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Causes and effects

Caused by

Power prices split EUR 131 north-south

Spain's 148% surge on 15 April is the opposite extreme from the EUR 29/MWh low on 13 April, demonstrating the volatility underlying the Iberian insulation thesis.

Occurred 13 Apr 2026

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Renewables pass fossil fuels, gas bill rises

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 1 Apr 2026

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This Event

Spain power jumps 148% in two days on low wind

The Iberian renewables-insulation trade is weather-dependent in ways the monthly averages obscure.

Led to

Italy-Spain spread compresses 76% in four sessions

Spain's 148% surge to EUR 71.91 on 15 April was the first leg of the spread compression that continued to EUR 24.54 on 17 April.

Occurred 17 Apr 2026

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Different Perspectives

Amsterdam-Rotterdam gas trading desks

TTF failing to sustain EUR 47+ with 51 mcm/day of Norwegian capacity offline confirms EUR 50 as a diplomatic ceiling; the curve is a Troll-restart long, and EBN's EUR 233 million mandate budget cap is a known limit on price-insensitive prompt buying.

ARERA

Italy's energy regulator is running mandatory storage injection that carries the EU aggregate trajectory alongside CRE and EBN, while Italian industrial consumers at Panigaglia face a simultaneously low-utilisation terminal and a EUR 2/MWh delivered-cost basis above TTF. The mandate funds security of supply at the expense of Italian competitiveness.

Shell

As a long-term Russian LNG contract holder, Shell faces a replacement procurement problem concentrated in Q3-Q4 2026 ahead of the 1 January 2027 double cliff; with terminal booking lead times running weeks, the real deadline is late November 2026 and no replacement supply has been publicly named.

CRE

France's 100% mandatory booking order funds injection regardless of the inverted strip, providing the EU aggregate cover that Germany's abolished levy cannot; the CRE order is renewed annually, making it a political risk rather than a structural guarantee. That dependency exposes the EU injection trajectory to French electoral cycles.

Bundesnetzagentur

Germany's regulator holds the early-warning gas stage active with no statutory instrument to compel commercial injection, and Berlin confirmed on 20 May it will introduce no summer incentive scheme; Germany is the EU's only major unincentivised storage market after the levy lapsed on 1 January 2026. The mandate gap is carried by three other member states.

European Commission

The Commission relaxed the mandatory fill target from 90% to 80% and published an ETS benchmark revision saving industry EUR 4 billion, choosing industrial competitiveness over both climate and storage ambition at the moment physical margins are tightest. Both decisions reduce policy pressure at the exact week the trajectory margin narrowed to 45 GWh/day.