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JPMorgan warns on chemicals margin squeeze

3 min read

22:33UTC

Yara needs an 11% European price increase just to break even; BASF is exposed on spot gas until its Cheniere contract starts.

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Key takeaway

Yara needs an 11% price rise to offset gas costs eating 20-22% of EBITDA in 2026-27.

JPMorgan warned this week that European chemicals margins face renewed compression with TTF above EUR 47/MWh. The most quantified exposure belongs to Yara International: higher gas costs are equivalent to 20% of 2026 EBITDA and 22% of 2027 EBITDA, requiring an 11% European price increase in both years to break even. Ammonia production uses natural gas as primary feedstock, so Yara has no substitution option at current technology.

BASF is exposed via spot gas purchasing at elevated prices. Its long-term Cheniere LNG supply contract begins mid-2026 but does not cover the current gap. Until that contract kicks in, BASF buys at whatever TTF offers. Bruegel confirms that industrial gas demand across the EU has remained depressed throughout 2026 with no recovery signs, even during periodic price dips. Demand destruction is the market's own price ceiling, but it operates with a lag, and it comes at the cost of European industrial output.

Deep Analysis

In plain English

Fertiliser and chemicals are among the most gas-intensive industries, because natural gas is both a fuel and a raw material. Companies like Yara (which makes fertiliser) and BASF (chemicals) consume enormous amounts of gas in their factories. With European gas prices near EUR 47/MWh, these companies' gas bills are consuming a large share of their profits. Yara says it needs to raise prices by 11% just to break even. If it cannot, it may close European factories entirely, which would reduce food production and chemical supply across the continent.

Deep Analysis

Root Causes

Ammonia production is fundamentally constrained by chemistry: the Haber-Bosch process requires natural gas both as a hydrogen feedstock and as fuel, consuming approximately 33 GJ of gas per tonne of ammonia produced. There is no viable substitute for natural gas in ammonia production at current green hydrogen costs (approximately EUR 6-8/kg, versus the EUR 0.8/kg natural gas hydrogen equivalent at EUR 25/MWh TTF).

BASF's spot gas exposure specifically reflects a procurement strategy error: the company hedged its 2022-23 gas demand through long-term contracts but allowed those contracts to roll off in 2024-25, expecting lower spot prices. Its Cheniere LNG contract beginning mid-2026 was designed to restore long-term supply certainty but the timing means it provides no protection during the current crisis.

What could happen next?

Risk
If TTF remains above EUR 45/MWh through Q3 2026, Yara is likely to announce additional European ammonia plant curtailments by June, reducing domestic fertiliser supply by an estimated 1-2 million tonnes.
Consequence
BASF's Ludwigshafen gas cost exposure at EUR 47/MWh TTF makes further German chemical capacity rationalisation economically rational regardless of any short-term supply normalisation.

Source Landscape

This story draws on neutral-leaning sources

Primary parallel: In 2021-22, TTF rising from EUR 25/MWh to EUR 200/MWh led to Yara closing its Montoir (France) and Porsgrunn (Norway) ammonia plants within nine months, removing 2.4 million tonnes per annum of European ammonia capacity permanently. BASF suspended Ludwigshafen ammonia production in late 2022. Current TTF at EUR 47/MWh approaches the levels that triggered those closures, though the 2022 spike was faster and more severe.

Counter-parallel: During the 2005-08 gas price run-up, European ammonia producers survived through temporary curtailments rather than permanent closures, because prices returned to sub-EUR 25/MWh by 2009. The 2026 situation differs: QatarEnergy's force majeure timeline is measured in years, not months, making temporary curtailment a commercially viable strategy only if producers have confidence in a normalisation date.

Yara's 20% EBITDA exposure at current TTF translates to approximately EUR 800-900 million in additional annual gas costs versus pre-crisis 2024 levels, based on Yara's 2025 EBITDA of approximately EUR 4 billion. The required 11% European fertiliser price increase conflicts with EU farmers' purchasing power after two years of elevated input costs.

BASF's Ludwigshafen complex is the largest chemical site in the world by integrated output value, consuming approximately 3.5 TWh of gas per day. Each EUR 1/MWh TTF increase adds approximately EUR 1.28 billion to Ludwigshafen's annual gas cost. At EUR 47/MWh versus a 2019 baseline of EUR 15/MWh, the cumulative additional burden on Ludwigshafen alone is approximately EUR 41 billion per year, explaining BASF's accelerated capacity rationalisation programme.

Consensus view: Goldman Sachs European chemicals team assessed in its April sector note that ammonia producers face a permanent cost floor problem: North African competitors (Egypt, Morocco, Algeria) source gas domestically at EUR 5-8/MWh equivalent, giving them a structural EUR 40/MWh advantage over European producers at current TTF, sufficient to undercut European ammonia prices even after shipping costs.

Yara's 11% required price increase assumes European buyers absorb the full cost differential; demand substitution to imported ammonia is already occurring.

Counter-view: SEB Research commodity analyst Bjarne Schieldrop argued that the European fertiliser market cannot simply be replaced by imports: nitrogen fertiliser applied in April for the summer growing season requires physical storage and just-in-time distribution networks that take years to relocate. European farmers who depend on Yara's distribution network face a practical supply constraint regardless of price, limiting the demand destruction risk in the short term.

Key tension: Whether European agricultural dependence on domestic fertiliser production provides a structural demand floor for Yara and BASF that limits near-term demand destruction, or whether price pass-through triggers enough farmer substitution to accelerate European fertiliser production closures.

Sources:EU Energy Live

Mentions:BASF →Cheniere →Iran International →France →Prima →QatarEnergy →Egypt →Qatar →Goldman Sachs →Norway →Morocco →Algeria →Bruegel →TTF →JPMorgan Chase →

First Reported In

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

EU Energy Live· 13 Apr 2026

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Causes and effects

This Event

JPMorgan warns on chemicals margin squeeze

The JPMorgan note quantifies what demand destruction looks like in practice: fertiliser and chemical producers face permanent margin erosion at current TTF levels, with no feedstock substitution option.

Led to

Cefic: 37Mt of EU chemical capacity gone

JPMorgan's Yara/BASF gas-cost exposure analysis contextualises the Cefic capacity loss data showing 37Mt of EU chemical capacity gone since 2022.

Occurred 15 Apr 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.