3AUG

German spark turns firmly positive now

3 min read

10:53UTC

Germany's clean spark spread reached roughly +EUR 30/MWh gross on 22 June, the widest positive reading of the cycle, as EDF nuclear ran unconstrained and let the thermal stack set the continental price.

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Key takeaway

Cheap gas plus a positive spark widens the winter deficit rather than closing it.

Germany's clean spark spread expanded to roughly +EUR 30/MWh gross on 22 June, the widest positive reading of the 2026 cycle. A combined-cycle gas turbine (CCGT) plant burning gas at TTF, paying EUR 78 per tonne for carbon and clearing power at EUR 124.09 is comfortably in merit ¹. The spark measures the margin a gas plant earns after fuel and carbon costs; when it turns positive, generators want to burn.

Two weeks earlier the same plant was losing EUR 44/MWh and shutting down . The reversal began on 17 June, when power jumped and the spark flipped from minus 44 to plus 15 , then extended further this week. What changed structurally is that EDF ran its French nuclear fleet without curtailment, letting Germany's thermal stack reset the continental clearing price .

The 22 June German day-ahead print of EUR 124.09/MWh jumped about 49% day-on-day, so one reading should not carry the structural case alone ². A low-wind, low-solar day lifts the gas stack up the merit order and flatters the spark; the figure needs a week of confirmation before anyone calls it a regime. The spread has nonetheless held positive on a multi-day basis since 17 June, reversing the minus 8 to minus 9 readings of early June .

Positive spark economics put commercial gas-for-power demand back into direct competition with the mandated injection operators. The injectors cannot out-bid a profitable generator for the same prompt molecules without widening their own losses, so cheap gas now drains the supply the November fill target depends on.

Deep Analysis

In plain English

When a gas power station can make money burning gas; when electricity prices are high enough to cover the cost of the gas plus a profit; it is called a "positive spark spread." Think of it as the power station's profit margin turning green. On 22 June, German gas power stations were making roughly EUR 30 for every unit of electricity they generated. That is the widest profit margin since this crisis began. The problem is that the same gas those stations are burning is the gas Europe needs to put into underground storage tanks before winter. Europe has a rule that it must fill its gas storage to 80% by November. Right now it is at 46%, about 9 percentage points behind where it was at this point last year. When power stations compete for the same gas that storage operators need to buy, it slows the fill rate. The headline gas price looks calm at around EUR 42 per unit, but that calm price is what makes burning gas profitable for power stations; and that profitability is pulling gas away from storage at exactly the wrong time.

Deep Analysis

Root Causes

Germany abolished its gas storage levy on 1 January 2026 with no replacement instrument. The levy had created a structural injection incentive independent of the summer-winter price strip. Without it, the only injection force is the mandated operators (EBN, CRE, ARERA) whose buying power is capped by their regulatory budgets, not by market economics.

EDF's decision to run without curtailment on 22 June reflects the commercial logic of the VNU mechanism: since French nuclear revenues sit below the EUR 78/MWh redistribution trigger, EDF captures the full power price margin and has no incentive to curtail. When EDF runs, it suppresses French clearing below Germany's thermal stack, making Germany's CCGT margin the continental clearing price and simultaneously removing the French nuclear buffer that would otherwise soften German day-ahead.

The combination; no storage levy, mandated-only injection, EDF running uncurtailed; means the market has no commercial mechanism to prefer injection over generation when the spark turns positive. The structural precondition for the summer 2021 crunch has been recreated under a different regulatory architecture.

What could happen next?

Consequence
Every week the spark spread stays positive above EUR 20/MWh, roughly 0.2 percentage points of weekly injection progress is displaced into generation, widening the November storage landing.
Short term · Assessed
Risk
If EDF announces curtailment risk for its summer nuclear fleet; cooling-water temperatures are a recurring July threat; the spark spread could reverse suddenly, removing the generation-competition dynamic but also signalling a French supply crunch.
Short term · Assessed
Precedent
Summer 2021's parallel; positive spark competing with injection, resulting in a 60% October storage level and EUR 180/MWh winter peak; sets the structural scenario the OIES 70% November floor is tracking.
Medium term · Assessed

Source Landscape

This story draws on neutral-leaning sources

Primary parallel: The summer 2021 European gas crunch showed an identical compression dynamic: positive spark spreads in June and July 2021 drew gas into power generation, leaving storage at 60% by October; 19 points below the prior-year level. The analogy is structurally direct: same mechanism (gas-for-power competing with injection), same consequence (widening deficit), and that year the winter peak reached EUR 180/MWh.

Counter-parallel: In summer 2023, a positive spark spread in Germany emerged in late June but reversed within three weeks as a renewable surplus from offshore wind pushed CCGTs off merit. Storage reached 97% by October. The 2023 episode shows that an initial positive spread is not necessarily self-sustaining; the EDF curtailment variable that generated the 2026 reading did not exist in 2023, so the structural comparison is weaker.

At EUR 42.59 TTF, EUR 78/tonne EUA and EUR 124.09 day-ahead, a 50%-efficient CCGT gross margin sits near +EUR 30/MWh. A plant running 16 hours per day at 400 MW extracts roughly EUR 192,000 of daily gross margin. For a 1 GW CCGT fleet running the same hours, margin is EUR 480,000/day. At that scale, gas-for-power demand runs at roughly 50-60 GWh/day per GW of capacity on merit.

Germany holds approximately 25-30 GW of installed CCGT capacity. Even at 40% utilisation across the on-merit portion, daily prompt gas consumption by the generation sector sits in the range of 350-450 GWh/day; directly competing with the EBN mandate of 400-420 GWh/day at Bergermeer alone. The mandated injectors and the on-merit CCGTs are bidding for the same prompt molecules, and the CCGTs have no budget constraint.

Consensus view: Timera Energy's David Stokes estimates that every EUR 10/MWh positive shift in the clean spark spread adds roughly 2.5 bcm of seasonal gas-for-power demand in Continental Europe, as on-merit CCGTs collectively accumulate run-hours.

The +EUR 30 print on 22 June, if sustained through July, would absorb enough prompt gas to widen the November storage landing by two to three percentage points on its own; compounding an injection deficit that began the week at 9 points year-on-year.

Counter-view: Rystad Energy's gas market team argues the attribution runs the wrong way: the spark spread widened because EDF withdrew nuclear capacity risk and the day-ahead market cleared on German CCGTs, not because CCGTs are running continuously. A single low-wind, high-load day inflates the gross spread reading; multi-day dispatch patterns (the actual injection drain) are flatter than the headline number implies.

Key tension: Whether the +EUR 30 print reflects a sustained merit-order shift that persistently out-bids mandated injectors for prompt molecules, or a weather-amplified spike that reverts once solar and wind normalise.

Sources:euenergy.live (ENTSO-E data)·euenergy.live (ENTSO-E data)·NUS Consulting

Mentions:Germany →TTF →EUA →EBN →CRE →ARERA →GIE AGSI+ →Rystad Energy →CCGT →Timera Energy →EDF →

First Reported In

Update #20 · Spark spread now feeds the winter deficit

euenergy.live (ENTSO-E data)· 22 Jun 2026

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Causes and effects

Caused by

German spark spread flips +EUR 15

Prior spark flip from -44 to +15 on 17 June extended into the +30 reading of 22 June.

Occurred 16 Jun 2026

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FR-DE day-ahead resets to Germany dearer

EDF running without curtailment let Germany's thermal CCGT stack set the continental clearing price, enabling the +EUR 30 spark.

Occurred 16 Jun 2026

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German CCGT shut-in is the demand depressant

The -EUR 44 CCGT shutdown on 15 June provides the structural baseline against which the 22 June +EUR 30 reversal is measured.

Occurred 15 Jun 2026

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This Event

German spark turns firmly positive now

A profitable spark pulls prompt gas into power generation at the exact moment the storage mandate needs every molecule, so the signal that looks bullish for power is bearish for winter supply.

Led to

French reactors curtail on river heat

German CCGT economics that had recovered to +EUR 30 gross margin on EDF nuclear restoration on 22 June were blown to +EUR 110 by Golfech and Nogent curtailment reversing the cheap-France supply leg

Occurred 23 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.