30JUN

EUA carbon breaks EUR 80 as gas sags

4 min read

17:15UTC

EUA settled EUR 80.73 on 25 June, its first clean break above EUR 80, while TTF sagged to EUR 40.75. Carbon now floors a German gas plant's marginal cost near EUR 98/MWh whatever gas does.

← Back to Germany refills as the autumn cliff nears Jump to analysis ↓

EconomicDeveloping

Key takeaway

Carbon sets a EUR 98/MWh floor under German gas plants regardless of how soft gas gets.

EUA carbon settled EUR 80.73/tonne on 25 June, its first clean break above EUR 80 ¹. An EUA is one permit to emit a tonne of CO2 under the EU Emissions Trading System, and every gas plant must buy them: a combined-cycle turbine pays for gas plus roughly 0.2 tonnes of carbon for each MWh it generates. The same day, the Dutch gas benchmark TTF sagged to EUR 40.75/MWh ², so the two legs of generation cost pulled apart, carbon up and gas down.

Carbon now sets a hard floor under gas-fired power. At EUR 80.73 the carbon leg alone lifts a German plant's marginal cost to roughly EUR 98/MWh even with gas this soft. That EUR 98 floor is the carbon component of the spark spread the heatwave blew out in the lead: when German day-ahead ran to its peak it was the gap above EUR 98 that made the margin, and it is the same floor plants will defend once the weather premium drains.

EUA had already clawed back to EUR 78.22 on 4 June , reversing the sell-off that followed The Commission's May ETS-benchmark revision, and the 25 June break extended that recovery on supply grounds. The annual cap falls about 180 Mt this year and CBAM keeps withdrawing free allocation, so the bid is structural rather than gas-driven. Optimism on US-Iran de-escalation and the UK-EU summit added risk appetite on top.

Deep Analysis

In plain English

The EU carbon market works by issuing a fixed number of permits to emit carbon dioxide. Every year, the total number of permits falls, making them scarcer and more expensive to buy. On 25 June, the price of one permit to emit one tonne of CO2 broke above EUR 80 for the first time in 2026. At the same time, European gas prices fell to EUR 40.75 per megawatt-hour because Middle East supply risks looked less severe than two weeks earlier. Carbon permits at EUR 80.73 per tonne contributed more to gas-plant running costs than the gas fuel itself did on 25 June. Electricity from gas plants therefore stayed expensive regardless of the gas price. Steel, cement, and aluminium manufacturers also face higher compliance costs above EUR 80 EUA, since they must buy permits for their own industrial emissions.

Deep Analysis

Root Causes

The Phase IV ETS reform package imposes a 4.4% annual cap reduction from 2023 onward, compared with 2.2% in Phase III. At 2025 verified emissions of approximately 1.33 Gt, the 2026 cap covers supply by roughly 180 Mt less than the prior year's cap, compressing banked allowance reserves that previously acted as a soft price ceiling.

CBAM's 2026 implementation removes 2.5% of free allowances for steel, cement, and aluminium sectors. These sectors previously received full allocation for their 2025 output; the 2.5% cut requires them to purchase marginal allowances at market rates, adding approximately 12-15 Mt of demand at current activity levels.

This demand is independent of power-sector or gas-price dynamics, creating a structural bid floor that TTF weakness cannot erode and that diverges from the carbon-gas correlation most spread models assume.

What could happen next?

Consequence
EUR 80.73 EUA sets a carbon-only CCGT floor near EUR 98/MWh that persists regardless of TTF direction; any TTF weakness that historically softened CCGT marginal cost is now more than offset by carbon strength, removing the gas-power correlation that most spread models price at this level.
Immediate · Assessed
Opportunity
Clean dark spreads turn structurally negative above EUR 75 EUA, removing hard-coal capacity from the German merit order and increasing gas-fired generation's share of residual load; desks holding long gas generation positions benefit from coal-to-gas switching before any TTF recovery.
Short term · Assessed
Risk
CBAM's 5% free-allocation removal in 2027 adds a further 25-30 Mt of structural demand to the EUA market; if the 2026 break above EUR 80 reflects only the 2026 2.5% CBAM tranche, the 2027 step produces a second structural bid and current Q4 2027 EUA forwards may understate the trajectory.
Medium term · Reported

Source Landscape

This story draws on neutral-leaning sources

Primary parallel: The Fit for 55 EUA rally of July to December 2021 saw carbon move from EUR 28 to EUR 90 in five months, driven entirely by structural supply announcements (the ETS revision proposal reducing the cap path) rather than any power-sector demand signal.

That rally demonstrated the ETS market's ability to price future scarcity years ahead of the physical cap tightening; the 2026 Phase IV mechanism repeats the same structural logic with a narrower allowance supply path and a harder CBAM enforcement instrument than 2021's consultative proposals.

Counter-parallel: The 2023 EUA correction from EUR 100 to EUR 45 after the REPowerEU revision package triggered windfall levy fears shows that legislative signal alone does not sustain a rally above EUR 80 if enforcement credibility is questioned.

The 2026 CBAM inclusion is a harder enforcement lever than the 2023 reform proposals, which were consultative rather than binding; however, the 2023 precedent is a live risk for any position relying on sustained EUR 80-plus EUA as a structural base rather than a temporary breakout.

For a standard German hard-coal plant (thermal efficiency 0.40, emission intensity 0.85 tCO2/MWh), EUR 80.73 EUA adds EUR 68.6/MWh in carbon cost alone. Against a summer German day-ahead average near EUR 90-100/MWh during the heatwave period, hard coal loses the power market to gas-fired generation at any carbon price above EUR 65/t.

At EUR 80.73 EUA and EUR 40.75 TTF, the clean dark spread (coal net of carbon) runs roughly EUR -45/MWh while the clean spark spread remains above EUR 50/MWh on average summer days: gas crowds out coal at every point in the July-September forward strip.

For EUA desks, the EUR 80 break activates a non-linear dynamic in the power sector. Above EUR 80, gas generation becomes structurally preferred over coal at all German day-ahead levels above EUR 70/MWh, removing the coal stack as a soft price ceiling.

Carbon bulls holding Q4 EUA longs therefore benefit from a positive feedback through the summer: high EUA prices shift the merit order permanently toward gas, increasing covered-sector demand and tightening the allowance balance ahead of the compliance cycle.

Consensus view: ERCST (European Roundtable on Climate Change and Sustainable Transition) tracked the 2026 ETS Phase IV structural supply tightening as the principal upward driver in its Q2 2026 Carbon Market Update, identifying three concurrent mechanisms: the Linear Reduction Factor lifting the annual cap reduction rate from 2.2% to 4.4%, CBAM's removal of 2.5% of free allocation for steel and cement, and aviation's full ETS integration removing previously exempted intra-EU flights.

ERCST assessed these three levers as independent of gas-sector demand, making the EUA price path a structural supply signal rather than a gas-power clearing proxy. EUA at EUR 78.22 on 4 June was the clawback level from the May ETS benchmark sell-off; the EUR 80.73 settlement on 25 June is the continuation of structural cap tightening through a new threshold.

Counter-view: Ember's June 2026 Carbon Price Outlook argued the EUR 80 breakout overstates near-term tightening because the Innovation Fund backstop, which can release up to 450 Mt of forward allowances before 2030, provides a latent supply ceiling the market has not priced.

Ember modelled the sustainable equilibrium range at EUR 72-78/t, with any breakout above EUR 80 requiring a demand-side shock on the electricity sector that is not yet visible in covered-sector verified emission data for 2025.

Key tension: Whether the EUR 80 break reflects structural Phase IV supply tightening alone or whether electricity-sector demand recovery is amplifying the move, since the two drivers have different implications for the forward carbon curve shape and the sustainability of any EUR 80-plus level.

Sources:ICE / TradingEconomics·TradingEconomics

Mentions:EUA →TTF →CCGT →Germany →Netherlands →European Commission →REPowerEU →Iran →Ember →EU Emissions Trading System →CBAM →

First Reported In

Update #21 · Heat cracks the French-nuclear floor

ICE / TradingEconomics· 26 Jun 2026

Read original →

Causes and effects

Caused by

EUA carbon holds EUR 78.22 above clawback

EUA at EUR 78.22 on 4 June was the clawback level from the May ETS-benchmark sell-off; EUR 80.73 on 25 June is the continuation of that structural cap-tightening recovery through a new threshold

Occurred 4 Jun 2026

Read story →

This Event

EUA carbon breaks EUR 80 as gas sags

Carbon, not gas, now sets the cost floor under German gas-fired power, capping how far electricity can fall when gas is cheap.

Led to

Clean spark spread reaches EUR 74

EUA recovering from EUR 79.25 (29 June) to EUR 80.17 (30 June) after briefly losing the EUR 80 handle set the EUR 32/MWh carbon leg that held the German spark spread below EUR 100 even at EUR 195 day-ahead power.

Occurred 30 Jun 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.