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Spain logs 397 negative-price hours in Q1

3 min read

10:53UTC

Spain recorded 397 hours of negative day-ahead power prices in Q1 2026, eight times the 48 hours of Q1 2025, with the clean-spark squeeze now spreading north into the Continental midday stack.

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Key takeaway

Spain's 397 negative-price hours confirm Iberian solar penetration is structural, now spreading north into the Continental midday stack.

Euronews reported that Spain logged 397 hours of negative day-ahead power prices in Q1 2026, eight times the 48 hours of Q1 2025 ¹. The 8x jump is not a heatwave artefact: it is a first-quarter reading from a window with no exceptional heat, the structural maturation of Spanish solar into a grid where baseload and midday demand have not adjusted fast enough to absorb the output. The CNMC blackout proceedings running in parallel underline that Iberian grid management already faces stress beyond price dynamics. For gas-fired operators the consequence is direct: midday clean spark spreads in Spain are now deeply negative, so CCGTs cannot clear on their own economics and must lean on capacity mechanisms or simply not run, while the overnight and morning windows still hold positive spark spread.

France's 3 June collapse into single digits gives the northward spread its sharper forward edge. That print is the first time the same mechanism has reached a market large enough to set the FR-DE spread record , and the Italy-Spain compression events of early May trace the same arc. As Germany adds solar under the Energiewende trajectory, the dynamic eventually reaches its grid too, collapsing the gas-set marginal unit during peak solar hours and compressing the FR-DE spread from the German side rather than the French. For Iberian desks the Q1 data recalibrates the negative-price premium in day-ahead options; for Continental desks it is a leading indicator the French print has just confirmed as present, not theoretical.

Deep Analysis

In plain English

Spain's electricity price went negative for 397 hours in the first three months of 2026, meaning suppliers had to pay buyers to take power rather than receive payment. This happened because solar panels generated far more electricity than Spain needed during midday hours , eight times more frequently than in the same period of 2025. When supply cannot be switched off and demand cannot absorb it, prices go below zero. The same pattern is now appearing in France and other northern European countries as solar capacity grows, with France recording its own extreme low of EUR 8.96 per megawatt-hour on 3 June 2026.

What could happen next?

Consequence
Spanish gas-fired operators faced structurally uneconomic midday clean spark spreads for 18% of Q1 hours, accelerating dependence on capacity mechanism payments as a business-model backstop.
Short term · Reported
Risk
As solar penetration spreads north into France and Germany, Continental CCGT economics will face the same midday compression that Spanish operators encountered at scale in Q1 2026, undermining the investment case for new gas capacity across the EU.
Medium term · Assessed
Opportunity
Negative price hours create a structural commercial case for battery storage and demand-response aggregators in Spain; operators who can capture and discharge negative-price surplus during peak windows will capture the value that gas plants cannot.
Medium term · Suggested

Source Landscape

This story draws on centre-leaning sources from France

France

LeftRight

Primary parallel: Germany's Dunkelflaute-negative-price cycle of 2013-2015, when rapid solar build past 36 GW produced structurally negative midday prices on clear summer days, forcing the Bundesnetzagentur to redesign the capacity mechanism and prompting the 2016 EEG reform that introduced direct marketing obligations for large generators.

In Spain 2026, solar penetration exceeds instantaneous demand, prices go negative, baseload operators cannot recover fixed costs from midday hours alone, and the regulator is compelled to act. Germany resolved it by forcing generators to sell directly into the market rather than receive feed-in tariffs, eliminating the revenue guarantee that had incentivised generation regardless of price.

Counter-parallel: California's midday solar duck curve, which produced negative prices in 4,000-plus hours in 2023 without triggering a systemic grid failure , because California had pre-built battery storage capacity (26 GW installed by Q1 2024) that absorbed midday surplus and discharged into the early-evening ramp.

Spain's 397-hour reading in Q1 2026 places it where California was in 2021-22, before the storage build normalised the duck curve. The parallel is useful but not comforting: California's storage deployment took seven years and substantial subsidy; Spain's equivalent programme is in earlier stages.

The commercial arithmetic for Spanish CCGT operators during midday hours in Q1 2026 was structurally loss-making: a negative day-ahead price means the marginal unit pays to generate, not receives payment. CCGTs in negative-price hours must either shut down , losing capacity payments for those hours depending on contract structure , or run at minimum load to maintain grid stability, absorbing the loss as a system-service cost.

The 397 hours represent roughly 18% of Q1's 2,160 hours, up from 2% in Q1 2025. At that penetration, the midday CCGT business model depends entirely on the remaining 82% of hours providing sufficient positive spread to recover fixed costs including carbon and capacity payments.

At EUR 78 EUA and TTF near EUR 49, the positive-spread hours are themselves compressed to a narrow morning and evening peak window. Spanish gas operators are consequently running close to economic dispatch limits across the full daily cycle, including morning and evening hours, accelerating their dependence on capacity mechanism payments.

The northward spread to France , where the 3 June EUR 8.96 clearing is the first Continental-scale expression of the same solar-surplus mechanism , confirms the pattern is not Iberian geography but a European solar-penetration dynamic advancing north with the build-out trajectory.

Sources:Euronews

Mentions:Italy →Germany →California →Euronews →CNMC →Bundesnetzagentur →France →Spain →

First Reported In

Update #15 · France EUR 9, Germany EUR 103: heat splits

Euronews· 4 Jun 2026

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Causes and effects

This Event

Spain logs 397 negative-price hours in Q1

Spain's negative-price proliferation is the leading indicator of a solar-penetration squeeze spreading north: the midday surplus that collapsed French day-ahead into single digits on 3 June is the Continental expression of a phenomenon Spain hit at scale a quarter earlier.

Led to

France EUR 9, Germany EUR 103: record spread

Spain's structural negative-price phenomenon (397 hours Q1 2026) is the Iberian precursor of the Continental midday solar-surplus dynamic that collapsed French day-ahead to EUR 8.96 on 3 June, amplifying the FR-DE series-record spread.

Occurred 3 Jun 2026

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Different Perspectives

Cross-border power traders

The France-Germany day-ahead spread flipped from a EUR 17.20 German premium on 1 August to a EUR 4.15 French premium on 3 August, the same day French curtailment peaked. They cannot yet attribute the flip to curtailment alone, since a like-for-like overnight comparison shows French nuclear output rising while wind fell and demand returned on the weekday step.

EDF

River-cooling limits took 7.6 GW, 12 per cent of its fleet, offline on 3 August, the highest curtailment since the heatwave began, with an easing forecast to 4.3 GW on 4 August and 3 GW after. It manages the cut as a recurring seasonal constraint, expecting it to lift with river temperature, not repair.

Gasunie

TTF, the Dutch hub it operates, drifted to roughly EUR 55 to 58 per MWh across the window, staying inside its recent range through both the German spark reversal and the French curtailment. It reads a flat hub price as evidence that neither event this window carried enough weight to move the fuel leg on its own.

German gas-fired generators

Record German solar of 18,761 MW on 2 August pushed the clean spark spread to minus 18.48 EUR/MWh, a loss-making day, before it returned to plus 16.20 on 3 August. They now price dispatch against post-solar residual load rather than wind alone, since the sign flipped inside 48 hours on unchanged fuel and carbon costs.

European Commission (DG Energy)

Its implementing-measures register logged transposition notices from only Portugal and Slovakia against Wednesday's Article 94 deadline for Directive (EU) 2024/1788, with 25 states silent. It expects the register to fill only gradually, since filing routinely lags legislating and any infringement track against non-notifying states runs on a slower clock than the deadline itself.

Spain's LNG terminal operators

Spain's 9,145 GWh terminal inventory is the largest single stock in the EU LNG network, an option value that can reroute cargoes wherever the winter strip pays best rather than a cavern gas obligation tied to a fixed date. That flexibility matters more as Germany's cavern shortfall pushes more of the winter security question onto import infrastructure.