UK Steel's £90.55/MWh number is the right warning, but the wrong headline: what the 2026-27 electricity gap really tells us about Britain's EAF transition

UK Steel's latest electricity pricing report lands in a policy environment where the UK has already spent several years and a great deal of money trying to close the gap. That is precisely what makes its central finding awkward: after the exemptions, the compensation and the network charging discounts, British steelmakers are still projected to pay £90.55/MWh in 2026-27, against £78.62/MWh in Germany and £60.64/MWh in France.

The headline numbers are stark. The 49% gap to France is expected to cost the sector roughly £66 million in a single year; the cumulative penalty since 2017-18 is put at £917 million against France and £752 million against Germany. But the more consequential message is buried in the report's diagnosis rather than its costings: the residual disparity is now driven by wholesale prices, not by the network charges and policy levies that government has been steadily attacking. That changes the nature of the problem, and it changes what a sensible policy response looks like.

What the numbers actually say

The reported estimates, after available government exemptions and compensation:

Source: UK Steel, as reported by SteelOrbis, 20 October 2026. Percentages are my calculations on the reported figures.

My arithmetic on the reported prices reproduces the stated gaps exactly (90.55/60.64 = 1.49; 90.55/78.62 = 1.15), which is reassuring but tells us nothing about the underlying modelling. The non-European comparators are more interesting analytically than the European ones: Alberta at £40.20/MWh is a gas-rich jurisdiction with a very different generation mix, and Vietnam and Turkey reflect state-influenced industrial tariff structures rather than liberalised marginal pricing. They are useful as a reminder of the scale of the global competitive field, but they are not policy-relevant comparators for a UK mechanism designed around European parity.

One number does not quite hold together with UK Steel's own earlier work. The association's campaign material, drawing on September 2025 research, projected a 2026-27 gap of 14–25% versus France and Germany combined, adding around £26 million a year. The October 2026 report puts the France-only gap at 49% and the annual cost at £66 million. A shift from a combined France/Germany average to a France-only comparison widens the percentage gap, but not by enough to explain a 2.5x increase in the cash figure at constant volumes. Scope (downstream re-rollers included?), volume assumptions or gas price decks must have changed. Readers should treat the £66m as a reported figure requiring methodology verification rather than a like-for-like update of the earlier £26m.

The real mechanism: gas sets the price, and Britain is gassy

UK Steel's diagnosis — that wholesale prices are now the dominant residual driver — is the analytically important claim. Britain's wholesale electricity price is set by the marginal generating unit, which in most hours is a gas-fired plant. The UK has retired most of its coal capacity and has not yet built enough storage or flexible low-carbon capacity to displace gas from the margin. The result is that British power prices track gas prices with high fidelity, while France's price formation is heavily influenced by its nuclear fleet and Germany's by a larger renewables share plus, historically, more industrial exemptions at the wholesale level.

This has a specific and uncomfortable implication for steel. The cost of decarbonising steel by switching from blast furnace–basic oxygen furnace (BF-BOF) routes to electric arc furnaces is, in energy terms, a switch from coal to electricity. UK Steel's own figures put an EAF at around 0.5 MWh per tonne of steel, with full sector electrification roughly doubling total consumption and greenfield BF-to-EAF conversions seeing power use "almost quintuple". Every increment of that electrification converts a coal exposure — globally priced, and partially sheltered by free allocation under the UK ETS — into an electricity exposure that is set by British gas markets.

That is the structural trap. A country can compensate industrial electricity bills, but compensation is a fiscal transfer that grows with the size of the gap and the volume of consumption. As the sector electrifies, both grow. The £917 million cumulative figure is, in effect, the bill for the last decade of partial fixes; without a change in price formation, it is a down payment on the next decade.

What is being proposed, and what it really does

UK Steel's ask is a wholesale electricity price rebalancing mechanism for energy-intensive industries: a financial settlement that aligns GB industrial wholesale prices with those of major European competitors. Its own design description is a contract-for-difference-style structure — fixing the steel sector's electricity price to the lower of French and German prices, with a clawback when GB prices fall below the reference level, so risk and reward are shared with the state.

Based on Baringa modelling, UK Steel estimates the mechanism would cut steelmakers' costs by about £24/MWh, taking the 2026-27 UK figure from £90.55 to £66.55/MWh. The fiscal profile is: average annual net cost of roughly £51 million over 2026–2030, turning to an average annual net gain of about £13 million over 2031–2035.

Two observations. First, the £66.55 outcome is still 9.7% above the French estimate and 15% below the German one — it is a partial convergence, not parity. The £24/MWh benefit is arithmetically consistent with the reported prices, but the report's own design language (parity with the lower of France/Germany) implies a larger transfer than the modelled £24/MWh delivers. Second, the claimed net gain in 2031–2035 depends on the clawback being collected, which in turn depends on GB wholesale prices falling below the European reference — a bet on British gas and power markets converging downward. That is a reasonable expectation if renewable build-out continues, but it is a forecast embedded in a policy costing, not a certainty.

The £51 million average annual net cost over 2026–2030 is, in context, small: less than the £66 million annual penalty the report attributes to the France gap alone, and a fraction of the sums already committed to steel decarbonisation through the UK's wider industrial strategy. The case for the mechanism is therefore less about fiscal cost than about whether it is the most efficient instrument. An alternative — and arguably cleaner — approach would be to decouple industrial electricity prices from gas entirely through a split market or a marginal-price reform, which would benefit all energy-intensive users rather than a single sector. UK Steel's proposal is narrower and therefore cheaper to administer, but it also leaves the underlying price-formation problem intact for everyone else.

The political economy

The report's timing matters. It arrives after the UK government has already moved on network charging — the Network Charging Compensation discount rose from 60% to 90% from April 2026 — and after a series of steel-specific interventions including nationalisation of British Steel's Scunthorpe operations and a revised steel strategy with higher tariffs and lower quotas. UK Steel's own campaign material notes that the NCC uplift only reaches industry in 2027 because compensation is paid a year in arrears, worth about £14.5 million, and has asked for it to be backdated to April 2025.

The pattern is familiar: government addresses the visible, administrable cost components (network charges, levies, compensation), while the largest and least tractable component — wholesale price formation — remains untouched. Each round of compensation narrows the gap and each round of gas price volatility reopens it. The October 2026 report is, in effect, UK Steel saying that the incremental approach has run its course.

There is also a trade-policy dimension that the report does not develop but which readers should keep in view. The UK's carbon border adjustment mechanism and its revised steel import regime raise the cost of imported steel, which partially insulates domestic producers from the French and German cost advantage on the sale side. But CBAM does not help exporters, and it does not help the competitiveness of UK steel sold into third markets. Electricity cost disparities bite hardest on export-oriented product and on any downstream segment — rebar, sections, wire — where the marginal producer sets the price and the UK producer is a price-taker.

What to watch

Three things will determine whether this report becomes a policy inflection point or another entry in a long series:

1. Whether the rebalancing mechanism enters the government's industrial electricity strategy. A mechanism with a net cost of £51 million a year is politically cheap; the obstacle is not fiscal but structural, because it creates a precedent for other energy-intensive sectors (chemicals, ceramics, glass, aluminium) that face the same gas-set marginal price.
2. The trajectory of GB gas prices relative to European hubs. If the post-2021 volatility that the report attributes in part to Middle East conflict persists, the case for decoupling strengthens; if gas converges downward, the urgency fades and the mechanism becomes harder to justify.
3. The pace of EAF conversion. Each furnace commissioned converts coal exposure into electricity exposure. If the sector's consumption roughly doubles as UK Steel projects, the £66 million annual penalty modelled for 2026-27 becomes a smaller fraction of a much larger bill — the gap compounds with electrification.

The headline number — £90.55/MWh against £60.64 in France — is the kind of figure that gets quoted in parliamentary debates. The more useful takeaway for industry readers is the structural one: Britain has built an electricity market whose industrial price is set by gas, and is simultaneously asking its steel sector to electrify. Those two policies are in direct conflict, and compensation has so far masked rather than resolved it.