The Crude Is There. Getting Diesel to Britain Is What Costs.

Record pump prices, shifting US export policy and low European gas stocks are converging on January. Britain's problem is the price of delivered energy, not its absence.

UKOilWatch · 13 October 2026 · OilWatch Network Analysis

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The RAC's UK average for diesel passed £2 a litre for the first time on 2 October, at a record 200.01p, against 142.38p when the conflict began on 28 February (ITV News). It has barely moved since: the RAC put it at 199.90p on 9 October (Fuel Finder UK). The government's Fuel Finder feed, a separate series, showed an equal-station average of 199.7p on 4 October (Fuel Finder UK).

The official series has now crossed the threshold too. DESNZ's weekly figure for 12 October, published on 13 October, puts diesel at 200.04p a litre, up 0.52p on the week and the first time £2 has been exceeded on the government's own measure. Petrol rose 0.40p to 175.28p (DESNZ).

There is no verified evidence of a nationwide shortage. Fuel keeps arriving. What has changed is the cost of getting it here.

Three decisions before the end of the year will set whether that cost rises further: Washington's stance on diesel exports, the 28 October Budget, and Ofgem's January price cap.

At a glance

• Britain imports 54% of the diesel it uses, and nearly a third of those imports come from the US.
• Crude is plentiful; diesel is not. US crude stocks sit slightly above their five-year average, distillate stocks about 12% below it.
• Washington backed away from a diesel export ban on 3 October, but the pressure behind it, record US diesel prices before the midterms, remains.
• Unless the Budget changes course, 1 January brings a 3p fuel duty rise and a forecast 16% rise in the energy price cap.

Britain buys more than half its diesel abroad, and a third of that from America

The UK imports 54% of the diesel it consumes, up from 16% in 2000 (Fuels Industry UK, 2 October). Its three largest suppliers are:

The Dutch and Belgian volumes largely pass through the Amsterdam–Rotterdam–Antwerp hub, which blends and re-exports barrels refined elsewhere, including in the US. Britain's real dependence on American refineries is probably higher than the 17% headline, though the hub draws on many origins. RSM puts direct US distillate flows to the UK at almost 90,000 barrels a day (City AM).

The squeeze comes from what has been lost elsewhere. The Hormuz disruption cut diesel exports from Gulf refineries, and Russia has restricted its own diesel exports, with non-producers barred until January 2027 (S&P Global). Europe has leaned harder on the US Gulf Coast to fill the gap.

At home, Grangemouth and Lindsey stopped refining in 2025, leaving four refineries. Fawley, the largest, was rated at about 20% of UK refining capacity before those closures, so its share of what remains is higher. It began planned maintenance at the end of September lasting into November (Share Talk). This is a scheduled turnaround, not damage, and the reduction in output has not been disclosed. Fawley's marine terminal lets ExxonMobil supplement production with imported finished fuel, but that raises import dependence for several weeks.

Argus judges the UK the most exposed country in Europe to tightening diesel and jet fuel supply (Argus). The Fuels Industry UK figures come from a statement lobbying for carbon-leakage protection in the Budget: the numbers are sound, the framing is advocacy.

Crude is plentiful; diesel is tight

The clearest sign of the imbalance is in US inventories. In the week to 2 October, US commercial crude stocks were 1% above their five-year average, while distillate stocks, at 105.1 million barrels, were about 12% below it (EIA via Oil & Gas 360; Reuters via BOE Report). US refineries ran at 92.7% of capacity.

That gap shows up in refining margins. The Amsterdam–Rotterdam–Antwerp diesel crack reached $98 a barrel in early September, a record at the time (S&P Global). With Brent around $105 a barrel, the premium for diesel over crude is a large part of what drivers pay.

Freight is where the usual story needs correcting. On the US Gulf–UK Continent route, crude tankers have faced far sharper rate pressure than the medium-range tankers that carry finished products. Baltic Exchange round-trip earnings in the week to 9 October:

Source: Baltic Exchange, 9 October. The MR rate fell 95 Worldscale points in the week, to WS285.

These are time-charter equivalents: owners' daily earnings, not freight per barrel, and the vessels differ in size and voyage pattern. They show that on these Atlantic routes crude shipping is under far more strain than product shipping. They do not show that product freight is cheap everywhere: the Baltic assessed the Middle East Gulf–UK Continent 90kt clean-products route (TC20), an LR2 run, at about $18.4 million per voyage in the same report, equivalent to roughly $281,800 a day.

For the 54% of British diesel that arrives as finished product, crude-tanker spikes are not the freight cost of importing diesel. The international diesel price, the refining margin, route-specific product freight, insurance and terminal costs set what Britain pays.

At the pump, tax adds a fixed layer on top: 52.95p duty plus VAT come to roughly 86p of the 200.01p record price (PetrolPrices).

Washington stepped back from an export ban, then turned to Russian diesel

The biggest risk to UK diesel supply in the past month came from Washington, not the Gulf. On 22 September President Trump said he backed a ban on US diesel exports, as US diesel prices reached about $6.52 a gallon ahead of the November midterms (Cyprus Mail/Reuters). European diesel margins hit a new record that day.

The stakes were large. S&P Global CERA estimated that a full ban from October to December would strand 1.48 million barrels a day of forecast US exports and force US refiners to cut runs by nearly 2 million barrels a day (S&P Global). Britain would have had to outbid Europe for non-US barrels while Gulf and Russian supply was already impaired.

On 2 October the UK and other G7 nations agreed to release up to 100 million barrels of fuel and oil from emergency stocks and committed to refrain from energy export restrictions. The next day Trump said the US would not impose a ban, and credited Europe's release (ITV News).

The sequence suggests a link, and Trump drew it himself, but it does not prove a formal bargain. Nor was the release mostly new oil: an internal IEA document seen by Euronews indicates the 100 million barrels are largely the unfinished part of March's pledges (Euronews). The pressure behind the threat, record US diesel prices before the midterms, has not gone away.

Washington's next move came on 9 October. Trump announced that Russia would supply diesel to the US and global markets: more than 300,000 tonnes immediately, 500,000 tonnes in November and 1 million tonnes after that, with a further 3 million tonnes promised later, subject to the condition of its refineries (AP via ABC30). The US Treasury issued a licence allowing imports of Russian diesel until 7 April 2027 (AAP via The Senior). The arrangement has drawn bipartisan criticism in Washington and objections from Kyiv.

The volumes are small and their delivery uncertain. The first tranche is about 2.25 million barrels, roughly a day and a half of the 1.48 million barrels a day of projected US diesel exports. Moscow partially lifted its diesel export ban on 10 October for an initial 500,000 tonnes (Interfax), but refinery damage, remaining export restrictions and shipping logistics complicate delivery (Reuters).

For Britain any benefit would be indirect. Russian barrels that actually arrive might ease US diesel prices and reduce the political incentive to restrict exports. Britain's own sanctions on Russian oil products remain in place.

The heavy-crude glut in the Americas is context, not relief

Heavy crude from Canada, Venezuela, Colombia and Ecuador is piling up in the Americas, and some grades have fallen more than $10 a barrel over six weeks (Reuters, 12 October). Two things stop it moving.

First, US refineries have little room left. Reuters reports utilisation has averaged about 93.5% so far in 2026, the highest in 28 years. Gulf Coast coking and conversion units can take heavier barrels, but only up to their physical limits.

Second, crude freight has absorbed the discount. Reuters estimates US Gulf–Europe VLCC costs, including ship-to-ship loading, at about $24.50 a barrel last week, against roughly $4 before the conflict, and above $40 on some routes to Asia. OPEC+ ministers said on 12 October that shipping and insurance had passed one third of commodity value (OPEC). Producers have an interest in blaming freight for high prices, but the Baltic data support the point for crude.

For Britain the glut matters mainly through Europe. High transport costs can stop continental refiners that supply the Amsterdam–Rotterdam–Antwerp hub from buying discounted heavy crude economically. The glut does not add diesel to British terminals.

Emergency stocks include real diesel; the question is how much governments will draw

About 325 million barrels have been released under the IEA's March 2026 collective action, and completing the remaining pledges would add roughly 100 million more (IEA, 7 October). That is an acceleration of existing pledges, not a new commitment. Members backed prioritising diesel where possible.

The buffer is not only crude. IEA members still hold about 1.1 billion barrels of public emergency stocks, including over 200 million barrels of diesel, and the agency says it is ready to release more. Released crude needs spare refining capacity before it becomes diesel; released diesel does not.

Stocks buy time. They do not replace lost refining capacity, and every barrel drawn this winter must be rebuilt later. The IEA Governing Board is due to settle the volumes, timing and products on 15 October, according to the document seen by Euronews.

Europe enters winter with low gas storage, and Britain has even less of its own

Reuters analysis expects EU gas storage to reach only 75–78% by 1 November (Reuters, 12 October). In an average non-crisis year storage reaches about 89% by that date, so Europe may start winter 11 to 14 percentage points short (IntelliNews). Amended EU rules allow until 1 December to meet a 90% target, reduced to 80% in difficult market conditions, so a 1 November shortfall would not by itself mean a missed target.

The loss of Qatari and UAE LNG has left Europe competing with Asia for US cargoes, and benchmark wholesale gas prices have risen more than 150% in 2026. Under average weather, northwest European storage could fall to about 20% by early April. Whatever is drawn this winter must be bought back next summer, so the pressure is unlikely to end in spring.

Ships are not the constraint on the Atlantic. The Baltic US Gulf–Continent LNG carrier rate fell to $21,200 a day in the week to 9 October (Baltic Exchange). On that route, scarce cargoes and depleted storage matter more than a lack of vessels.

Britain sits outside the EU storage system but not outside its market. The UK has little seasonal gas storage of its own and relies on Norwegian pipeline gas, LNG imports and interconnectors to the continent. Contracted deliveries help, but bills still follow international wholesale prices.

The effect on bills is already visible. Ofgem's typical cap rose 4% to £1,723 for October to December (Ofgem), partly offset by zero VAT on domestic electricity from October to March. Cornwall Insight forecasts a further 16% rise to £1,999 in January, the largest quarterly increase in four years (Money to the Masses). Ofgem confirms the January cap by 25 November.

Our view: without Budget action, households face a double hit on 1 January

Under the published fuel-duty schedule and the latest energy-price forecast, households could face two increases on the same day. The temporary 5p duty cut ends in two steps: 3p on 1 January, taking duty to 55.95p a litre, and 2p on 1 March (Forecourt Trader). The Treasury has signalled it intends to proceed (Forecourt Trader). The January price cap is forecast, not yet confirmed, to rise by about 16%.

If neither is softened:

• Fuel: the 3p January step adds about 3.6p a litre with VAT, or about £1.98 on a 55-litre tank. March adds another 2.4p a litre.
• Haulage: the Road Haulage Association estimates the full 5p would add £2,325 a year per lorry, and is lobbying to keep the cut (Trans.info).
• Energy: Cornwall Insight's forecast adds about £276 a year to a typical dual-fuel bill, from £1,723 to £1,999.

Both would land in one of the coldest, most expensive months of the year, on top of record diesel prices. The 28 October Budget decides the duty path, and the government is under pressure to add support for energy bills (Rest Less). It is the most important UK energy-cost event before winter.

What to watch

Where we stand

There is no verified evidence that Britain is running out of diesel. The product-freight benchmark from the US Gulf has eased, emergency stocks include finished diesel, and the threatened US export ban has not been imposed.

But spare capacity is thin. US distillate stocks are about 12% below their five-year average, refining margins are exceptionally high, and European gas inventories are low for the season. Britain depends on one country for nearly a third of its imported diesel, and on international markets for much of its gas.

The cost of the next three months will turn on actual deliveries and refinery operations, and on three decisions: Washington's export policy, the 28 October Budget and the January price cap.

The world has oil. Britain needs diesel. Between the two sit refineries running near their limits, a volatile freight market, and political decisions taken in other capitals.

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UKOilWatch distinguishes verified physical supply, published market data, official statements and forward-looking assessments. Market tightness and high prices do not, by themselves, establish a nationwide fuel shortage. Statements from industry bodies and producer groups are reported as such.