31 Oct 2026

Physical Markets Weekly: Hormuz Risk Reprices East-of-Suez as Atlantic Crude Weakens and Europe Runs Short of Product

Physical commodity markets ended the week with a sharper split between route risk and commodity availability.

Inside the Persian Gulf, the cost of moving crude and refined products remained extreme and began firming again late in the week. PG–China VLCC freight rose from around w1125 on October 26 to w1215 by October 30, while Gulf of Oman alternatives remained roughly half that level. Clean tanker markets showed the same structure: Arab Gulf–Japan LR1 freight remained above w1000 while Oman indications were below w500.

Outside the Gulf, the physical crude market moved in the opposite direction.

North Sea, CPC, Canadian heavy and several Atlantic Basin grades weakened sharply as unsold cargoes accumulated, refinery economics deteriorated and earlier freight dislocations left too many barrels competing for nearby demand. Johan Sverdrup flipped below Dated Brent, Forties was heard in negative territory, CPC offers reached discounts near $10/b and Djeno remained around historically deep discounts.

That creates the central physical-market contradiction of the week:

the cost of accessing some barrels remains extremely high even while the underlying crude itself is becoming cheaper.

Refined products showed an equally fragmented structure. European jet stocks collapsed to a 12-year low, naphtha inventories fell more than 25% week on week and diesel stocks declined again. Yet governments continued releasing strategic reserves, Russian diesel exports were recovering and China issued additional clean-product export quotas.

Fertilizers followed the same regional pattern. European gas moved above €100/MWh, threatening additional nitrogen shutdowns and supporting Egyptian urea above $535/t FOB, while Middle East and Brazilian urea remained materially cheaper.

The market is therefore moving further away from a single global benchmark structure and toward a system in which location, route, insurance, refinery margin and replacement cost determine physical value.

Market at a Glance

Inside-Hormuz freight re-tightened. PG–China VLCC rose from around w1125 early in the week to w1215 by October 30.
Gulf of Oman remained structurally cheaper. GoO–Far East VLCC indications were around w650–690 late in the week versus inside-PG indications of w1200–1450.
The security premium remains route-specific. Charterers continue using shuttle tankers and STS transfers through Oman and West Coast India to avoid direct long-haul voyages from inside the Gulf.
North Sea crude weakened dramatically. Johan Sverdrup flipped to Dated Brent minus $0.79/b and Forties was heard at or below Dated.
CPC remained distressed. November cargoes were offered around $9–10/b below Dated Brent as high freight and limited refinery pull blocked clearing.
Atlantic crude remains oversupplied. Djeno was heard around Dated minus $34.70/b, while Canadian heavy crude remained near multi-year or record-low differentials.
Europe jet stocks fell to a 12-year low. ARA inventories dropped 17.6% week on week to 380,000 mt.
ARA naphtha stocks fell 25.6% to 270,000 mt. Prompt backwardation remained steep and East-West economics strengthened.
European diesel stocks declined to 1.721 million mt. US ULSD exports also fell to a 31-week low.
Strategic reserve releases remain a major policy supply source. European governments plan more than 42 million barrels of releases over three months, around half diesel.
China added a fourth clean-product quota batch. The new allocation was reported around 5.6–5.65 million mt, taking 2026 total quotas to roughly 42.1 million mt.
Russian diesel availability is recovering. October diesel/gasoil loadings were around 1.1 million mt, with November authorized volumes targeted around 2.0–2.15 million mt.
Fuel-oil East-West separation reached a new extreme. The Singapore–Rotterdam 0.5% sulfur spread reached $192.50/mt, the widest in the available series.
European gas moved above €100/MWh. Nitrogen producers warned of possible plant shutdowns.
Egyptian urea strengthened to $535–540/t FOB. A potential 20% production cut from November would reduce export availability further.
Sulina congestion became a fertilizer freight problem. Ukrainian Danube-to-Egypt freight reached around $130/t and voyage times stretched toward two months.

Crude Oil: Route Risk Returned Before Physical Supply Tightened

Middle East crude pricing weakened for much of the week before recovering late.

The Dubai cash-futures premium fell from $6.69/b on October 26 to $5.07/b on October 29, extending a multi-day decline driven by softer Asian demand and adequate prompt supply.

On October 30, however, the premium rebounded sharply to $7.13/b.

That late-week move did not come from a sudden disappearance of barrels.

It followed renewed security concerns around Saudi and Hormuz infrastructure.

Houthi sources claimed attacks on Ras Tanura, Abqaiq and Rabigh during the week. Several of those claims were not independently confirmed, but tanker attacks and incidents around the Strait continued to be reported.

Hormuz traffic itself remained volatile:

17 transits per day on October 24–25;
16 on October 28;
26 on October 29.

The market therefore continued to price an unstable route rather than a stable shortage.

That distinction matters.

The crude exists. The uncertainty is whether the vessel, insurer and charterer will accept the route at an economically viable cost.

Persian Gulf vs Gulf of Oman: The Security Premium Expanded Again

The clearest physical signal remains the freight gap between inside-Persian-Gulf loadings and Gulf of Oman alternatives.

On October 26:

PG–China VLCC: w1125;
Gulf of Oman–Far East: w565.

On October 27:

PG–China: w1150;
Gulf of Oman: approximately w585–615.

On October 29:

PG–China: w1165;
Gulf of Oman: w625.

By October 30:

PG–China: w1215;
inside-PG indications: w1200–1450;
Gulf of Oman: w650–690.

The key point is not the absolute Worldscale number.

It is that the inside-Gulf route still costs roughly twice the outside-Gulf alternative.

This spread represents a package of costs:

war-risk insurance;
owner risk tolerance;
uncertainty over transit timing;
risk of attack or delay;
STS transfer economics;
and the opportunity cost of committing scarce vessels inside the Strait.

The market is effectively pricing access to the cargo separately from transport of the cargo.

Shuttle Tankers and STS: A Parallel Logistics System Is Becoming Structural

Charterers continue adapting to the risk premium through shuttle operations.

Instead of fixing a long-haul LR or VLCC directly from inside the Persian Gulf, some buyers move product or crude through the high-risk zone on owned or time-chartered tonnage and transfer the cargo in Oman or West Coast India.

The second vessel then performs the long-haul voyage.

The structure reduces exposure of mainstream tonnage to Hormuz.

But it has side effects.

It can make the visible vessel list outside the Gulf appear more liquid than the true supply of ships available for immediate long-haul employment.

It also introduces:

additional handling;
STS cost;
timing risk;
transfer coordination;
and potential congestion.

This explains why freight can soften outside the Strait while remaining structurally expensive on a delivered basis.

Atlantic Crude: The Freight Crisis Has Become a Supply-Clearing Problem

Atlantic freight no longer explains the entire weakness in crude differentials.

The first phase of the shock was simple:

freight rose → FOB crude had to discount.

This week showed the second phase:

freight eased → crude remained weak because displaced supply had already accumulated.

West African, North Sea, CPC and Latin American barrels are now competing in a market where refinery margins are weaker and buyers have more options.

The Atlantic Basin therefore shifted from a logistics crisis toward a clearing-price problem.

That is why crude differentials remained distressed even when some tanker benchmarks corrected.

North Sea: The Scarcity Premium Has Collapsed

The most important crude-market change of the week occurred in the North Sea.

At the start of the week, Forties was already heard below $3/b over Dated Brent and Johan Sverdrup remained difficult to place.

By October 29:

Johan Sverdrup FOB Mongstad was assessed at Dated Brent minus $0.79/b;
the grade had fallen more than $2.50/b week on week;
it was the first negative differential since August 27;
Forties was heard in negative territory;
Ekofisk was heard around $3/b;
several November Oseberg, Brent, Ekofisk and Forties cargoes remained unsold as the December program emerged.

This is a major reversal from the extreme premiums seen earlier in the conflict.

The mechanism has changed.

Saudi and other replacement barrels are moving more effectively into Europe, while Atlantic supply has lengthened and high feedstock costs have damaged refinery economics.

The result is that North Sea crude no longer carries the same strategic scarcity premium.

Johan Sverdrup: More Supply Meets Less Urgency

Johan Sverdrup is a particularly useful indicator.

The December loading program was reported around 700,000 b/d, up from roughly 536,667 b/d in November, including the first VLCC cargo since August.

At the same time, spot differentials fell below Dated Brent.

This tells the market that the issue is no longer simply whether Europe can find sour crude.

The issue is whether refiners want the marginal barrel at prevailing margins.

That is a very different market.

When the replacement problem becomes easier but refinery economics worsen, physical crude premiums can collapse even while geopolitical risk remains high.

CPC: Freight and War Risk Still Prevent Clearing

CPC Blend remained under severe pressure.

On October 26, second- and third-decade November barrels were heard around Dated minus $8–9/b.

On October 27, PetroChina offered CPC at:

Dated minus $9.75/b for November 16–20;
Dated minus $9.25/b for November 20–24.

No buyers emerged by the close.

The source data described the Mediterranean market as collapsing and in contango.

The issue is not only supply.

The route carries high Suezmax freight and war-risk cost, while refinery demand is insufficient to absorb the November program at earlier differentials.

CPC is therefore a textbook example of physical value being determined by the entire delivery chain rather than benchmark price alone.

West Africa: Deep Discounts Persist

West African crude remained heavily discounted.

Djeno was heard around Dated minus $34.70/b late in the week, described as an all-time low.

The weakness reflects several overlapping factors:

weak Asian pull;
expensive long-haul freight;
competing Atlantic supply;
reduced urgency from European refiners;
and increasing availability of Saudi and Iraqi alternatives.

WAF–East freight itself was volatile rather than one-directional.

It began the week around w562.5, rose toward w630 and ended around the same level.

That means freight stopped worsening.

But crude differentials did not recover.

This confirms that the regional problem has moved beyond transport cost alone.

Canadian Heavy: US Gulf Heavy Sour Is Oversupplied

Canadian heavy crude also remained under extreme pressure.

On October 26:

WCS Cushing was $23/b below WTI, the weakest level since publication began;
WCS Hardisty was $31.05/b below WTI CMA, the weakest since October 2022.

By October 30, WCS Hardisty had recovered modestly to around a $29.70/b discount, but remained exceptionally weak.

The source data linked the pressure to oversupply of heavy sour crude on the US Gulf Coast and competition from Venezuelan and Colombian grades.

This is another example where crude weakness is no longer simply a freight story.

The receiving market has too much substitutable heavy feedstock.

Dirty Tankers: East and West Are Moving in Different Directions

Dirty tanker markets became increasingly regional during the week.

East of Suez

Persian Gulf VLCC freight strengthened:

w1125 on October 26;
w1150 on October 27;
w1155 on October 28;
w1165 on October 29;
w1215 on October 30.

The security premium remained concentrated around inside-Gulf loadings.

West of Suez

The picture was softer.

WAF–UKC Suezmax fell from around w710 early in the week to w705 by October 30 after brief mid-week strength.

Black Sea–Mediterranean Suezmax fell from around w1100 to w975.

Mediterranean Aframax rates dropped sharply on lengthening vessel supply.

Vancouver–China also fell to $11.7 million, the lowest since October 5.

This divergence reinforces the main theme:

the tanker market is no longer experiencing one global shortage. It is pricing separate regional risks.

Refining Economics: Crude Supply Is Increasing Faster Than Refinery Appetite

The crude overhang is being amplified by refinery economics.

At least five Sinopec refineries were reported planning November run cuts because of high feedstock costs and weak margins.

Sinopec said its Q3 crude procurement premium plus freight and insurance averaged around $4.29/b, far below the Q2 peak of $14.74/b.

But the company forecast Q4 logistics and procurement costs of at least $15/b, potentially above $20/b in December, because Hormuz navigation uncertainty remains unresolved.

This is commercially important.

A refiner can face:

cheaper crude differential;
but higher freight;
higher insurance;
and weaker product margin.

The lower FOB crude price does not necessarily improve the refinery margin.

That is why physical crude can remain difficult to clear even after sellers cut differentials aggressively.

Europe Diesel: Strategic Supply Is Rising, Commercial Supply Is Falling

European policymakers continued using emergency stocks to offset weak commercial inflows.

European countries were reported preparing to release more than 42 million barrels of strategic reserves over three months, roughly half diesel.

France planned around 10 million barrels of diesel at cost.

The IEA had already released roughly 330 million barrels of its broader 400-million-barrel collective action by October 15, with around 20 million barrels of diesel accelerated.

At the same time, commercial US supply weakened.

US ULSD exports fell to 1.32 million b/d in the week ended October 23, a 31-week low.

US diesel/gasoil exports to Europe totaled around 6.8 million barrels in October, down from 7.4 million barrels in September.

The USGC–Europe ULSD arbitrage averaged minus $0.68/b in October, compared with plus $5.29/b in September.

The physical implication is straightforward:

Europe is replacing commercial barrels with policy barrels.

That can stabilize availability.

But it is not the same as a normalized arbitrage system.

ARA Diesel: Still Tight Despite Policy Intervention

ARA diesel and gasoil inventories fell again.

By October 30, stocks were around 1.721 million mt, down roughly 3% week on week.

Earlier in the week, 10ppm diesel CIF NWE reached $1,553/mt, its highest level since September 24.

The physical premium persisted because the market was balancing:

lower US inflows;
Russian export uncertainty;
refinery maintenance;
strategic stock releases;
and inland logistics.

The front-end price could sell off sharply with crude.

But replacement economics remained tight.

European Jet: Inventories Fell to a 12-Year Low

Jet became the strongest inventory signal of the week.

ARA jet stocks fell 17.6% week on week to 380,000 mt.

That was the lowest level since September 2014.

The decline followed an already-low base.

European jet supply therefore ended October with very little inventory cushion.

Flat prices were volatile, falling sharply with crude mid-week and rebounding late.

But the inventory signal is more important than the flat-price move.

A product can fall $50/mt in one day and still remain physically scarce if the benchmark crude price is also falling.

That distinction is central to interpreting the European jet market.

Asia Jet: Supply Is Available, but Europe Cannot Easily Access It

Asian jet continued to show greater availability.

South Korean refiners sold November cargoes at discounts to MOPS.

GS Caltex sold 300,000 barrels loading November 12–14 at approximately $1.30/b below November MOPS.

Earlier in the week, Singapore jet cash differentials were also weak, reaching around 18 cents/b below MOPS.

This is the opposite of Europe.

Asia has cargoes.

Europe has low stocks.

The missing link is economical freight.

Gulf of Oman-to-Northwest Europe jet arbitrage was deeply negative during the week, while Atlantic freight remained punitive on some routes.

This explains why regional balances can diverge for weeks.

Surplus supply does not solve a deficit market if transport destroys the arbitrage.

Naphtha: Europe Tightened Sharply

Naphtha moved from tight to critically low inventory conditions.

Prompt backwardation reached approximately:

$44/mt Nov/Dec;
$28.50/mt Dec/Jan early in the week.

ARA naphtha stocks then fell 25.62% week on week to 270,000 mt.

That was around 43% below late-October 2025.

The East-West spread widened to around $82/mt by the end of the week.

Petrochemical demand was beginning to re-emerge as the main physical pull while gasoline blending economics weakened.

The market therefore has two competing forces:

low inventories and backwardation supporting prompt Europe;
stronger East-West economics pulling replacement barrels toward Asia.

This creates a fragile inventory structure.

Fuel Oil: Record East-West Economics Still Face Logistics Friction

Fuel oil remained one of the clearest examples of price spread versus executable arbitrage.

The Singapore–Rotterdam 0.5% sulfur East-West spread reached $192.50/mt on October 29 — the widest in the available series dating back to April 2022.

The Singapore LSFO crack against Brent reached $29.80/b, its highest since July 2022.

Those are extremely strong signals.

Yet European VLSFO flows to Singapore were far below September.

Only around 177,000 mt loaded in Europe for Singapore during October compared with approximately 682,000 mt in September.

The reason is freight.

The spread is wide.

The cargo economics are attractive on paper.

But the vessel cost and risk premium prevent enough barrels from moving.

That is exactly why regional fuel-oil dislocations can remain extreme.

China: More Export Quota, but Less Immediate Refinery Throughput

China added another clean-product export quota batch during the week.

The fourth batch was reported around 5.6–5.65 million mt, lifting the 2026 total allocation to approximately 42.1 million mt.

The source data contain a small internal discrepancy in the exact total — 42.06 million mt versus 42.19 million mt — but both imply modest year-on-year growth.

The quota headline is bullish for export availability.

The refinery data are less straightforward.

At least five Sinopec refineries were reported planning November run cuts.

The initial November product export target was around 3.13 million mt, roughly 15% below October.

At the same time, full quota usage would require much higher exports later, with December volumes expected above 5 million mt in some estimates.

The market therefore faces a timing issue:

China has export permission, but not necessarily immediate refinery economics to maximize exports in November.

December could look very different.

South Korea: Additional Diesel Supply Is Coming

South Korea also moved toward greater export availability.

From November, the government will allow diesel exports up to 110% of the year-earlier monthly level, compared with the previous 100% cap.

This matters because South Korea is one of the few large refining systems capable of responding quickly to regional product shortages.

The additional flexibility is particularly relevant for:

Australia;
Southeast Asia;
and potentially long-haul replacement into Europe if freight allows.

Again, the main constraint is not refinery capability.

It is delivered economics.

Russia Diesel: Export Recovery Is Becoming Material

Russian diesel availability increased substantially.

Preliminary October diesel and gasoil loadings reached around 1.1 million mt by October 30.

Russia planned to continue the export ban framework through January, but with exceptions.

Authorized October export volume was around 510,000 mt, while November volumes were cited around 2.0–2.15 million mt.

The source material contains inconsistent November figures, so the exact target should be treated as indicative.

Four Russian diesel cargoes were reported shipped under the US waiver by the end of the week.

This is a significant change from the earlier phase of the conflict.

Russia is no longer only a missing source of diesel.

It is becoming a potential incremental export source again.

That could reduce replacement pressure in Europe and the Atlantic Basin if refinery operations continue recovering.

However, Ukrainian refinery attacks resumed on October 30, adding new uncertainty.

European Refining: High Margins Are Incentivizing Output

European refining margins remained strong despite the crude and product volatility.

OMV raised its 2026 European refining margin forecast to $25/b from $20/b, after Q3 averaged around $37.50/b.

TotalEnergies reported a Q3 European margin of $33.20/b, with European throughput up roughly 10% quarter on quarter to 1.55 million b/d.

The European Commission also opened discussions with refiners about increasing regional output after around 10% of capacity was lost over the past two decades.

The physical incentive to run is therefore strong.

But the ability to increase specific products is constrained by:

maintenance;
crude slate;
hydrogen availability;
unit configuration;
and logistics.

More refinery utilization does not immediately guarantee more jet or diesel where inventories are lowest.

Urea: European Gas Has Replaced India as the Main Bullish Driver

The urea market moved away from the earlier India-tender shock and toward European energy economics.

Dutch TTF moved above €100/MWh.

By October 30, front-month gas was around €103.5–104/MWh.

At those levels, European nitrogen economics deteriorate rapidly.

AGF Nitrogen, described in the source material as Europe's second-largest nitrogen producer, was reported considering shutdowns across France, Germany, Austria, the Czech Republic and Slovakia.

At least 5 million mt of ammonia capacity was assessed at risk under current conditions.

A full AGF shutdown scenario could increase the affected volume above 7.3 million mt, around 40% of European ammonia capacity.

That is not an immediate production loss.

But it materially changes replacement-cost expectations.

Egypt Urea: Gas Economics and Potential Production Cuts Support the Premium

Egyptian granular urea strengthened through the week.

Prices moved from around $530–535/t FOB early in the week to approximately $535–540/t FOB by October 30.

Egyptian producers were reportedly informed that a 20% production reduction could begin in November.

The potential export impact was estimated around 70,000 mt/month.

The cut remained assessed/likely rather than fully confirmed in the supplied material, and some European market participants questioned its significance because Egyptian gas availability was not reported to have changed.

Nevertheless, Egypt remains strategically important because it can supply Europe without the same long-haul freight exposure as Gulf or Asian origins.

When European production costs approach $800/t equivalent, a $535/t Egyptian FOB barrel can remain commercially attractive despite high freight.

Middle East Urea: More Available, but Hormuz Still Matters

Middle East granular urea ended the week around $445–455/t FOB.

That is materially below Egyptian values.

The Gulf also had more physical supply visible.

Around seven vessels carrying approximately 390,000 mt of non-Iranian granular urea were reported inside the Middle East Gulf during the week.

But export execution remained constrained.

No non-Iranian urea vessel had reportedly exited the Gulf for a period after mid-October, highlighting the same issue affecting oil:

production availability is not the same as export availability.

For fertilizer buyers, Hormuz risk therefore remains a delivered-cost variable.

Sulina Canal: Fertilizer Logistics Tightened in the Black Sea

A separate logistics problem emerged around the Sulina Canal.

Around:

80 vessels were waiting at Sulina roadstead;
another 20 were awaiting canal entry.

Voyage times had stretched toward two months, compared with roughly two weeks previously.

Freight for 5,000–7,000 mt cargoes from Ukrainian Danube ports to Egypt reached around $130/t, up from above $100/t earlier in October.

That is an enormous logistics burden for fertilizer and other bulk commodities.

The Sulina congestion shows that the week's central theme is not limited to oil.

Across commodities, the market increasingly prices access to transport infrastructure as part of the commodity itself.

Key Physical Market Signals

Hormuz: route security remains unresolved and the late-week risk premium increased again.
PG vs Gulf of Oman: the VLCC spread widened toward roughly 2:1 and remains the cleanest measure of direct Strait risk.
Dirty freight: East of Suez firmed while West of Suez broadly softened.
North Sea: physical premiums collapsed; Johan Sverdrup flipped negative to Dated.
CPC: discounts around $9–10/b show that freight and weak refinery demand continue to block clearing.
West Africa: deep discounts persist even without a new freight spike.
Canadian heavy: USGC heavy-sour oversupply remains severe.
Refiners: high freight and insurance can offset lower crude differentials.
Europe jet: ARA inventories reached a 12-year low.
Europe diesel: commercial inflows remain weak and strategic reserves are replacing some missing arbitrage barrels.
Europe naphtha: inventories fell more than 25% w/w and prompt backwardation remains steep.
Asia jet: cargoes remain available at discounts, but arbitrage to Europe is freight-constrained.
Fuel oil: record East-West spreads are still not generating normal physical flows.
China: additional export quotas create future supply optionality, but November run cuts limit immediate output.
South Korea: diesel export flexibility increases from November.
Russia: diesel exports are recovering materially, though refinery security remains uncertain.
European nitrogen: gas above €100/MWh threatens additional ammonia shutdowns.
Egypt urea: potential November production cuts support a substantial premium.
Sulina: canal congestion has become a major delivered-cost problem for Black Sea fertilizer flows.

What to Watch Next

1. PG–China versus Gulf of Oman VLCC freight

This remains the most useful indicator of Hormuz risk. A narrowing spread would signal improved owner confidence. A further widening would confirm that the security premium is becoming more structural.

2. Confirmed damage to Saudi infrastructure

Several attacks were claimed during the week. The market needs confirmation of whether Abqaiq, Rabigh or Ras Tanura sustained any material operational damage.

3. Hormuz vessel transit frequency

The late-week rise to 26 vessels matters only if it becomes sustained. One-day increases do not restore normal route economics.

4. North Sea unsold November cargoes

If Forties, Oseberg, Ekofisk and Brent cargoes continue clearing at progressively weaker levels, the market will have confirmation that Atlantic oversupply has replaced scarcity.

5. Johan Sverdrup December program

The larger December program will test whether the negative differential is temporary or a structural response to excess sour availability in Europe.

6. CPC November clearing

CPC discounts near $10/b are already extreme. Further weakness would indicate that war risk, freight and refinery economics are still preventing the Mediterranean market from absorbing supply.

7. European jet inventories

At 380,000 mt, the ARA system has very little buffer. Any refinery outage or import delay could reprice the physical premium quickly.

8. Naphtha East-West arbitrage

The East-West spread has strengthened while European inventories collapsed. The market needs enough replacement supply to prevent further prompt backwardation.

9. US diesel exports

The 31-week-low export rate is a direct constraint on European replacement supply. A rebound would reduce dependence on strategic reserves.

10. Russian diesel November volumes

The indicative 2.0–2.15 million mt target is materially above October. Actual loadings will determine whether Russia becomes a meaningful balancing source again.

11. China November refinery runs

Export quotas alone do not create barrels. Refinery run cuts could keep November exports subdued despite additional allocation.

12. China December product exports

If refiners attempt to use more of the annual quota before year-end, December could bring a large increase in export supply.

13. South Korean diesel exports

The higher export cap from November gives the Asian market an additional balancing mechanism.

14. European gas above €100/MWh

Sustained triple-digit TTF materially raises the probability of nitrogen production curtailments and increases import dependence.

15. Egypt production policy

A confirmed 20% production reduction would tighten one of Europe's closest urea supply sources.

16. Sulina Canal congestion

Any improvement in queue length or canal operating time would directly reduce delivered Black Sea fertilizer costs. Continued closures would keep freight exceptionally high.

The Bottom Line

The physical commodity market ended October with an unusual combination:

expensive access and cheap barrels.

Persian Gulf crude remains expensive to move because the Strait of Hormuz still carries a substantial security premium.

But the Atlantic Basin is no longer short crude.

North Sea barrels are unsold.

Johan Sverdrup has flipped below Dated Brent.

CPC is offered near double-digit discounts.

West African and Canadian heavy grades remain deeply discounted.

That means the market's main constraint has changed.

Earlier in the conflict, buyers were asking:

where can I find a replacement barrel?

Now, in several crude markets, the question is:

can I move this barrel cheaply enough and process it profitably enough to justify buying it?

Refined products are following a different cycle.

Europe still lacks jet, diesel and naphtha inventory.

Strategic reserves are being used to replace some missing commercial flows.

Russia is restoring diesel export optionality.

China has more quota available.

South Korea is allowing higher diesel exports.

But those barrels still need economically viable transport.

That is why Europe can have 12-year-low jet stocks while Asian jet trades at a discount.

It is why Singapore can show a record East-West fuel-oil spread while European exports to Asia collapse.

And it is why cheap crude in one basin does not automatically translate into cheap product somewhere else.

Fertilizers show the same logic.

European gas above €100/MWh raises nitrogen replacement cost.

Egyptian urea strengthens.

Middle East urea remains cheaper.

But Hormuz risk and Sulina congestion add large logistics premiums between producer and buyer.

The defining physical-market equation at the end of October is therefore:

commodity price + route access + freight + insurance + refinery or production economics + regional inventory = usable replacement cost

That is the market that matters.

Not the benchmark alone.

CommodityScope — Physical Market Intelligence

This report is an independent analytical synthesis of physical commodity market conditions observed primarily from October 26 through October 30, 2026. It focuses on physical supply, trade flows, freight, route risk, inventories, arbitrage, refinery economics, refined products and fertilizer markets. Market levels are indicative observations for analytical context and are not firm offers or investment recommendations.

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