Data cut-off: 1 September 2026, 08:30 UTC

Update, 2 September 2026

After this note’s 1 September 08:30 UTC cut-off, Sparta published its assessment that the USGC-Europe diesel arb had reopened.

Sparta assessed Houston-Rotterdam at +$14.75/mt for September loaders on 1 September, with room for TC14 to rise toward roughly WS250 before freight alone closes the trade.

On 2 September, Sparta still showed Houston among the open origins for late-September loaders.

The distinction below between tanker economics and cargo economics is unchanged. The current cargo-arb state has moved from closed to open.

Update, 3 September 2026

A later 2 September Sparta Freight update put Houston MR freight at WS220 with the diesel arb margin at +$8.75/mt, leaving room for TC14 to rise to around WS255 before the arb shuts.

This supersedes the earlier +$14.75/mt / roughly WS250 snapshot above. The trade remains open, but the cargo margin has narrowed.

A diesel barrel can exist, have a ship available and still fail before it reaches the buyer. The US Gulf Coast shows how.

In its Week 35 report, based on the 27 August assessment, the Baltic Exchange put the TC14 US Gulf to UK/Continent round-trip TCE at $19,742/day. Freight economics were positive and Atlantic MR tonnage was available.

Sparta’s 27 August assessment still had USGC ULSD MR diesel arbitrages into Europe closed. Positive tanker earnings therefore did not establish that the cargo itself cleared economically for a European buyer.

Replacement supply is increasingly being decided further down the chain. China, Russia, the Gulf, the US Gulf Coast and India all have potential barrels, but each faces a different obstacle between refinery and delivery.

US Gulf Coast

The August sequence shows why freight cannot be read in isolation.

On 10 August, Sparta had Houston-Rotterdam diesel open by roughly $29/mt for August loaders when TC14 had fallen to around WS155. By 20 August, stronger US diesel pricing had pushed Houston-Rotterdam back to about -$12/mt, even though freight remained comparatively soft.

That is the same route moving from clearly open to clearly closed within days as the components of the cargo calculation changed.

The last direct prompt assessment available before the cut-off still had the European diesel arb closed. Gibson, the shipbroker, was more constructive about the period ahead in its 28 August report, No Margin for Error. With US refinery utilisation high and relatively little autumn maintenance scheduled, Gibson expected continued export flows to support the transatlantic trade.

Fresh flow data were less encouraging. Vortexa showed US diesel exports to Europe falling from roughly 540 kb/d in the first half of August to around 350 kb/d in the second half, a decline of about 35%. Flows are not an arbitrage calculation, but the direction is consistent with weaker late-August European pull.

The next useful datapoint is a fresh Houston-Europe cargo-arbitrage assessment.

China

China has refinery headroom, while additional diesel exports remain heavily dependent on policy.

No standalone September product-export allowance had been issued by the cut-off. Refiners could carry unused August allowance into September, although neither the amount carried over nor actual September diesel nominations had been published.

Reuters reported the front-month East-West gasoil spread at around -$135/t in August, compared with about -$100/t in July, as Asian barrels moved west. Asian refiners’ diesel margins averaged $66/bbl in August, up from $61/bbl in July.

Sparta’s 31 August note was more cautious about what came next. Its own SG 10 E/W series had reached an extreme, and Sparta argued that the move was closer to a floor than another breakdown. It also identified additional Chinese or South Korean export quotas as a risk that could leave excess regional supply in place for longer.

For China, the practical evidence will be the next allocation and the cargo nominations that follow it.

Russia

Russia combines refinery disruption with a separate legal restriction on exports. Refinery damage, reduced throughput and lower exports overlap, so adding them together would exaggerate the loss.

Government Resolution No. 1097 extended restrictions on diesel, marine fuel and gasoil exports by direct producers through 30 September 2026. Diesel exports by non-producers remain prohibited through 31 January 2027. The end-September date does not imply a general reopening of Russian diesel exports on 1 October.

The export data show how severe the constraint already is. Vortexa data cited by Kommersant put Russian seaborne diesel exports at roughly 150 kb/d over 1-25 August, about 81% below the five-year average.

The physical position deteriorated further at YANOS. Reuters reported, citing two industry sources, that the 28 August attack shut AVT-3 and AVT-4, together representing roughly 73% of primary crude-distillation capacity. The smaller AT-4 unit remained in operation. On 31 August, YANOS diesel sales on SPIMEX fell several-fold.

KINEF was hit on 30 August as well. A fire was confirmed, but no operator or major wire had quantified the resulting processing loss by the cut-off. It remains a material watch item without justification for adding another loss figure to the Russian balance.

The Gulf

Kpler’s 20 August assessment put Middle East refinery runs at roughly 7.3 mb/d, compared with 9.9 mb/d in February 2026.

The resulting 2.6 mb/d gap is crude throughput. It is not a 2.6 mb/d diesel loss.

Using historical product shares gives an order-of-magnitude middle-distillate impact of roughly 1.0 mb/d. This is a sizing exercise rather than measured current diesel output.

Kpler also found that run losses exceeded the refinery capacity directly damaged. Otherwise-operational plants had curtailed throughput as restricted exports caused product inventories to build.

Ruwais makes the distinction visible at asset level. Kpler already described its earlier disruption as largely resolved in the 20 August regional assessment. Bloomberg then reported on 31 August, citing people familiar with the matter, that ADNOC’s 922 kb/d Ruwais refinery had returned to full potential. ADNOC declined to comment.

Bloomberg put total refined-product exports at roughly 70% of pre-war levels. Against a pre-war baseline of about 600 kb/d, that implies roughly 420 kb/d of current exports despite restored refinery capability.

Hormuz remains the immediate constraint on evacuation. Reuters, citing Kpler data, reported only five commodity-vessel transits on Monday 31 August, against a ten-day average of roughly fourteen. None of Monday’s transits was a liquid tanker, and vessels travelling with AIS switched off are excluded from the count.

Clean-tanker war-risk premiums have not received a fresh public numeric assessment since late July. Tanker movements therefore provide the cleaner current evidence on whether product evacuation is improving.

India

India has already demonstrated that replacement supply can move.

PPAC’s provisional July HSD export figure was 2.438 million tonnes, equivalent to approximately 586 kb/d across the month.

August adds further evidence, although the geographic attribution needs care. Reuters reported that Asia, including India, was estimated to ship 1.8-2.0 million tonnes of diesel to Africa in August, the highest level in at least four and a half years. Middle East shipments to Africa fell to 0.6-0.8 million tonnes, close to a nine-year low.

India’s individual share of the Asian total was not disclosed.

India’s latest confirmed total diesel export levy was ₹24/litre under the 15 August revision. No later primary notification had been established by the cut-off. The August export total will show whether July’s roughly 586 kb/d monthly-equivalent pace was sustained.

Jazan

Kpler data cited by Reuters showed Jazan diesel shipments to Africa falling to zero in August, from 163,000 tonnes in July.

No confirmed diesel loading or sustained export resumption had been established by the cut-off. The first post-disruption cargo will provide a firmer signal than another provisional restart date.

What would move the ranking

A fresh Houston-Europe cargo-arbitrage print would clarify the US Gulf Coast position. China needs actual September nominations or another export allowance. Russia needs evidence on KINEF’s operating impact and YANOS recovery. In the Gulf, several days of sustained clean-product tanker movement through Hormuz would materially improve the case for available refinery output becoming exportable supply.

India’s August export data will show whether July’s roughly 586 kb/d rate persisted. Jazan still needs a confirmed diesel cargo.

The incremental European barrel is likely to come from whichever constraint clears first. Spare refinery capacity alone does not rank the alternatives.

Selected source notes

Baltic Exchange, Tanker Report Week 35, assessment 27 Aug 2026

Sparta Commodities, USGC diesel/TC14 analysis, 10, 20 and 27 Aug 2026

Gibson, No Margin for Error, 28 Aug 2026

Russian Government / Resolution No. 1097, 28 Aug 2026

Kommersant / Vortexa, Russian diesel exports, 30 Aug 2026

Reuters, Asia-to-Africa diesel flows, 31 Aug 2026

Reuters / Kpler, Hormuz vessel transits, 1 Sep 2026

Kpler, Middle East refining under pressure, 20 Aug 2026

Sparta Commodities, SG 10 E/W analyst brief, 31 Aug 2026

PPAC, provisional July 2026 HSD export data

Bloomberg, Ruwais refinery recovery, 31 Aug 2026

Vortexa, US-to-Europe diesel flows, 1 Sep 2026

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• Gulf: refinery throughput loss is separate from the Hormuz, insurance and clean-tonnage evacuation constraint.

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It prices a selected Saudi execution route against an executable Mars replacement barrel using your own inputs, and shows the lift-success probability at which waiting stops being cheaper. It is the same workbook that sat behind the paywall …

Read more

South Korea still has aggregate crude cover, but the official posture is tighter than it was in July. At an 11 August cabinet meeting, the government said August crude and naphtha volumes were being secured at 100% or more of the previous-year average, while supply conditions from September onward required additional management. It also planned to reactivate the strategic-reserve crude SWAP within August and pursue an extension of emergency naphtha and petrochemical supply measures.

The shift is toward tighter contingency management even though August supply remained covered.

On 13 August, Reuters reported that a refiner with its full Saudi allocation still described the barrels as conditional because it did not know whether it could lift them. Saudi term crude is typically sold FOB, leaving the buyer to arrange transport. Reuters also reported that few shipowners were willing to enter Hormuz or the Red Sea to load from Saudi Arabia’s main export ports.

This applies to buyer-arranged term barrels. Aramco has also sold crisis spot cargoes on CFR terms, and seller-delivered arrangements have been reported as possible.

Reuters reported on 12 August that crude and condensate loadings at Sidi Kerir averaged a record 2.17 million b/d, around 90% of it Saudi crude, based on Vortexa data.

Throughput still leaves the cargo-execution question open. Reuters also reported that all Yanbu loadings in the prior week were conducted with AIS dark, while Vortexa, Kpler and AXSMarine produced sharply different estimates for the same loading system. Sidi Kerir can operate at scale; headline flow data still does not show whether a buyer’s cargo will lift.

One PetroChina-chartered VLCC loaded at Yanbu and cleared Bab el-Mandeb, while separate Unipec-chartered VLCCs scheduled to enter the Red Sea and load at Yanbu slowed and circled in the Gulf of Aden instead of entering as scheduled. Public reporting does not state why the decisions differed.

Saudi Arabia set the September Arab Light Asia OSP at $2/b below the Oman/Dubai average. That differential cannot simply be carried onto an Asia-bound Sidi Kerir cargo. The published Saudi Sidi Kerir OSP structure is for Europe and references ICE Brent; no public pricing mechanism for Sidi Kerir cargoes to Asia has been established.

Reuters reported on 14 August that GS Caltex bought 2 million barrels of Mars from Shell for November arrival at about $13-14/b over October Dubai. The transaction basis was not stated.

The procurement choice is narrower than the headline spread: keep waiting on a selected Saudi execution route, or lock an executable replacement barrel now? The paid workbook prices that choice from the buyer’s own route, basis, freight, timing, refinery-value and failure-cost inputs.

Read more

China’s July customs print came in at 8.41 million b/d, up from 7.12 million in June. Read on its own that looks like the rebound starting. It is not enough to settle a September loading decision, and the reason sits in the refinery numbers rather than the import numbers.

Read more

Budapest, 8 August 2026

Update, 10 August 2026
IIR Energy now expects Saudi Aramco’s 400 kb/d Jazan refinery to restart by 30 August after another attack on the site. That is roughly two weeks later than the previous estimate. Aramco has not confirmed the date. https://www.bloomberg.com/news/articles/2026-08-10/saudis-delay-restart-of-jazan-plant-to-late-august-iir-says?accessToken=eyJhbGciOiJIUzI1NiIsInR5cCI6IkpXVCJ9.eyJzb3VyY2UiOiJTdWJzY3JpYmVyR2lmdGVkQXJ0aWNsZSIsImlhdCI6MTc4NjM5MzExMiwiZXhwIjoxNzg2OTk3OTEyLCJhcnRpY2xlSWQiOiJUSks3TVBOM04wOUEwMCIsImJjb25uZWN0SWQiOiJENTU0M0FCMTYxREI0RUU5OTc1RDRDNkM5QkIyNzYwMCJ9.ocbakN3jAfdPL0BQlzXCjAgf6WatChpnaIPBg1Meq0Q

Decision: keep Jazan out of firm September cover until the refinery is operating and export availability is confirmed.

Why September is the real procurement window

Two Saudi Red Sea naphtha cargoes lined up for Japan turned west.

Torm Innovation loaded about 58,000 tonnes at Yanbu on 23 July and shifted to Spain. Hafnia Experience loaded about 55,000 tonnes at PetroRabigh on 25 July for an expected 20 August arrival in Japan; ship-tracking data later showed New York as its discharge destination. [1] Seferis, carrying gasoline from Yanbu, also turned north toward Suez.

Argus data show Saudi naphtha flows through Bab el-Mandeb at about 433,000 tonnes in May, around 370,000 tonnes in June and only 76,000 tonnes in July to date. May flows were mainly headed to Indonesia, Singapore, Malaysia and South Korea. Argus also reported that no tanker carrying Saudi gasoline or naphtha appeared to have crossed Bab el-Mandeb after the Houthis’ 20 July maritime-ban announcement. Keeping an eastbound destination after diversion through Suez and around the Cape can add around a month to the voyage. [1]

Korea is not facing a blanket August shortage. At a 28 July emergency review, the industry ministry said naphtha through August had been secured at or above the previous-year level and that measures would be prepared to secure September-onward volumes. [2] 4th Journal reported that a Hanwha TotalEnergies official said September volumes were partly secured and that the company could adjust its naphtha, condensate and LPG feed mix. [9] September procurement therefore turns on the quality and timing of replacement cover, not a simple shortage call.

Kpler estimates that west-to-east naphtha through Bab el-Mandeb averaged 426 kb/d in Q2 2026, around 17% of seaborne trade. Roughly 215 kb/d was Russian naphtha moving through Suez toward Asia on a full-2026 average basis. [3]

Those reference flows cannot be carried straight into September. Russian export availability has weakened, Saudi west-coast supply has been diverted or disrupted, and vessel affiliation affects whether a nominated ship can use the intended route.

Update, 9 August 2026

Saudi Arabia’s energy ministry said a fire at Aramco’s Jizan refinery was extinguished with no reported injuries. The Houthis claimed a drone attack. Jizan has been shut since 27 July, according to an IIR note seen by Reuters. The tentative mid-August restart remains unconfirmed. Re-date any September arrival that depends on it pending confirmation of operating status.

Source: https://www.reuters.com/business/energy/fire-extinguished-aramco-facility-jizan-saudi-arabia-says-2026-08-09/

Windward recorded 22 Chinese-linked vessels moving through Bab el-Mandeb and/or calling Saudi ports between 20 July and 2 August without incident while four Saudi tankers were struck. The useful procurement question is therefore fixture-specific: does the barrel exist, will the nominated vessel and owner accept the route, and will the cargo still arrive inside the buyer’s required window? [4]

The paid brief applies that test to Russian, Mediterranean and Atlantic replacement candidates. The Mediterranean lane now starts later than it did in the previous screen: Argus reports zero Algerian naphtha transits through Bab el-Mandeb to Asia in July, down from 132,000 tonnes in June, while Cape-routed exports to Asia rose to 441,000 tonnes from 292,000 tonnes. Strong European blending economics were also actively pulling on the same supply. [7]

Read more

Saudi Aramco cut the September Arab Light official selling price for Asia to USD 2.00/bbl below the Oman/Dubai average on 6 August. That is the lowest Arab Light differential since June 2020. [1]

The operational instruction matters more than the headline. Asian term customers were asked to nominate Ras Tanura by 7 August and to file an alternative from Yanbu or Sidi Kerir if the Strait of Hormuz remains closed. That instruction governs the whole September loading programme, not only the nomination date. Alternative-port volume is limited, and only Arab Light is available there. [1]

Full post and paid workbook: https://gyulatoth559216.substack.com/p/three-load-ports-one-nomination-what

A single grade differential now sits under three different delivery structures.

Ras Tanura remains contingent on the strait becoming commercially loadable. Yanbu adds an unpublished East-West pipeline fee and a Red Sea voyage. Sidi Kerir adds Ain Sukhna and SUMED handling, a separate differential that Aramco had not published, and a Mediterranean-to-Asia route. [2][3]

The September grade table also splits the signal. Arab Light fell by USD 0.50/bbl from August, while Arab Medium and Arab Heavy each increased by USD 1.25/bbl. The alternative ports offer Arab Light only. A medium-sour refiner is therefore not choosing between identical barrels at three ports. [1]

Aramco was sustaining exports at about 5 million b/d, while Amin Nasser said a Suez-plus-Cape routing could add 20 to 25 days to Asian delivery if Bab el-Mandeb is unavailable. Indian and South Korean refiners were reported to be seeking USD 5-10/bbl discounts on Yanbu-based barrels, while one Sidi Kerir reroute estimate was near USD 5/bbl. [3][4][5][8]

Yanbu also carries an availability question. Aramco reports the East-West Pipeline at 7 million b/d maximum capacity. Argus estimates about 2 million b/d feeds west-coast refineries, leaving roughly 5 million b/d for export against lower estimated terminal loading capability. That supports a potential bottleneck. It does not prove that a particular buyer has a berth or allocation. [7][8]

The analytical rule is simple:

The published grade differential is only the common starting point. Once the load port changes, the decision is driven by port-specific fees, freight, war risk and financing. None of those inputs should be filled with a public average.

The paid asset is therefore an input template, not a universal recommendation. The worked example normalizes the common benchmark to zero because it cancels from the port ranking. It then shows the mechanics with clearly labelled illustrative route inputs.

In that example, the normalized costs are:

The alternative-nomination structure changes the breakeven. Under the reported DUAL structure, Ras Tanura is filed in both strategies and cancels from the comparison. At a 30% reopening probability, Sidi Kerir needs a USD 3.29/bbl discount to match Yanbu. Under an EXCLUSIVE structure, the threshold is USD 4.76/bbl. The workbook requires the buyer to choose the applicable structure; blank returns NO RESULT. A proposed Hormuz passage deal remained commercially unresolved on 6 August, so reopening probability is still a buyer input rather than a settled fact. [6]

Paid subscribers receive the report and the live workbook. A company-specific screen can use the buyer’s actual destination, cargo size, contractual fees, freight, insurance, loadability and confirmed allocation. Start through the public Substack message path. Scope, inputs, fee and delivery date are agreed in writing before work begins.

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A tanker that turns back after entering the Red Sea has already spent days and fuel getting there. That spent time and fuel remain in the voyage account. The return leg sits on top of them, followed by the longer route around Africa.

Reuters reported that the Suezmax Sea Icon loaded at least 100,000 tonnes of Russian naphtha at Ust-Luga for Asia, approached Bab-el-Mandeb and then changed course for the Cape. That report establishes the event. It does not identify the buyer’s contract, the vessel’s performance curve or a verified sailed track, so the cargo works here as a dated illustration rather than as a reconstruction of a decision that has already closed.

The first public anchor is the Suez Canal Authority’s own distance table. Singapore to Rotterdam runs 8,288 nautical miles through the canal against 11,755 around the Cape, a structural difference of 3,467 miles.

Most commentary stops at that number. It describes a clean routing choice made before departure. A reversal is a different shape of problem, because the ship has to unwind the distance it already covered before it can start the longer route at all.

Add a two-way retrace to the structural delta and the worked case gives 6,221.6 incremental nautical miles. At 13 knots, that is 19.94 extra days at sea.

Nineteen days is where the commercial question actually begins, because a ship earns while it sails. Every day of that diversion is a day the vessel is not earning on its next employment. Three listed Suezmax owners each disclosed realised or booked earnings covering the second quarter of 2026, and the highest of the three sits more than sixty percent above the lowest. The same 19.94 days is therefore worth very different amounts depending on whose ship it is and how that ship is employed.

Fuel is the line everyone quotes, and on this voyage it is the smaller one.

The canal line resists averaging as well. The SCA calculator will not return a figure without the vessel’s actual particulars, and the Authority raised its temporary transit surcharges again on 15 July 2026, with crude and product tankers absorbing the steepest increase of any vessel class. Under the long-haul rebate process, full dues are paid at transit and any approved refund arrives later, subject to conditions that a reversed voyage may not satisfy.

So the honest answer to what a U-turn costs is a range, and the width of that range is set by the ship rather than by the sea miles.

Read more

Evidence cut-off: August 4, 2026

India’s petroleum ministry reported that household LPG availability was protected during the Middle East supply shock and that distributor dry-outs were avoided. The same period still produced a sharp physical adjustment. Reuters reported that first-half 2026 LPG imports fell about 28% to roughly 7.5 million tonnes, while consumption declined about 8% to 14.7 million tonnes.

The official outcome therefore needs a precise reading. Priority allocation, higher refinery LPG yields, alternative procurement, longer booking intervals and controls on commercial supply protected households. That result does not establish an unconstrained import and logistics system.

The distinction matters for the proposed 2027 U.S. programme. Reuters reported on 28 July that India could source up to 25% of roughly 20 million tonnes of LPG imports from the United States in 2027. The 20 million-tonne figure was attributed to a source cited by Reuters; it was not an awarded volume or an official forecast. The workbook therefore tests three import totals.

The low case annualises Reuters’ roughly 7.5 million tonnes of first-half imports to 15 million tonnes. The central case uses the reported 20 million-tonne estimate. The upper case uses 25 million tonnes as an upside sensitivity. At a 25% US share, the cases equal 3.75, 5.00 and 6.25 million tonnes.

On a 44,000-tonne planning parcel, that range produces about 85, 114 and 142 cargoes. The headline share carries less precision than it appears to carry, because the import total can move the annual lifting requirement by roughly one third in either direction.

Official Indian reporting identified India-bound LPG cargoes of 45,000 tonnes and 47,600 tonnes during the March disruption. Those movements support the commercial plausibility of a 44,000-tonne standard parcel at national scale. They do not identify the receiving terminal, the discharge split or the amount accepted at a single call.

West-coast evidence is stronger than it was. IndianOil identifies Kandla, Pipavav, Dahej and Mundra as LPG import facilities connected into India’s bulk distribution system. Mundra’s official port information booklet lists liquid and LPG berths, two 12-inch LPG arms and 50,000 tonnes of LPG storage scale. The port’s vessel schedule also showed an LPG carrier waiting for LPG operations in July.

That evidence supports vessel fit and storage-scale plausibility at a relevant west-coast location. Berth and storage specifications are not proof of available ullage, a full 44,000-tonne discharge, unloading time or allocation to the 2027 programme. The terminal question remains open at the level that matters to a chartering decision.

The freight market is moving at the same time. Baltic Exchange BLPG3 Houston-Chiba rose from USD 220/mt on 10 July to USD 292.17/mt on 24 July, then closed at USD 269/mt on 31 July. BLPG1 Ras Tanura-Chiba closed at USD 213/mt on 31 July while producing higher daily TCE earnings than BLPG3. Route length and vessel-cycle efficiency can dominate the headline rate per tonne.

The free conclusion is specific. Gross cargo counts overstate the shipping effect when US tonnes replace an existing Arabian Gulf programme. The reported 20 million-tonne central case remains growth-led under the controlled 15 million-tonne baseline because non-US imports still exceed baseline. The 15 million-tonne case is substitution-led and receives a credit for the shorter Arabian Gulf cycle.

The analytical judgment behind this reading is that the binding variable is terminal acceptance rather than freight.

Freight is expensive, visible and hedgeable. It reprices weekly, it is published, and an owner can act on it. Terminal parcel acceptance is none of those things. It is unpublished, it changes with ullage and evacuation conditions on the day, and it decides whether a programme moves in 44,000-tonne parcels or in something smaller. A smaller accepted parcel raises cargo frequency, vessel demand and freight per tonne simultaneously, which is why it sits inside the paid screen rather than beside it.

Berth dimensions establish that a vessel fits. They do not establish that a full parcel discharges. The published Mundra B01 parameters clear a VLGC on length, beam and displacement, and that is genuine progress on the west-coast question. It says nothing about available ullage at the nominated call, discharge rate, evacuation capacity behind the tank farm, or how a 2027 programme would be allocated across Kandla, Pipavav, Dahej and Mundra. Those are the questions that decide vessel productivity, and none of them is in the public record.

The second load-bearing assumption is post-discharge employment. The triangulated cases in the workbook assume prompt Arabian Gulf employment after a west-coast discharge. If that employment is prompt, the long-haul economics improve materially and the Gulf credit in the net calculation is real. If it involves waiting, the triangulated cases overstate the position and the full-cycle cases are the correct reference. That assumption is disclosed as an editable input for exactly that reason.

Taken together, this is why the reported programme is treated here as a charter-market question rather than a joint-venture question. Two half-interests cover roughly one vessel-equivalent against a modelled twenty to twenty-four. The exposure sits with owners who hold flexible tonnage, and it resolves on terminal execution rather than on the tender outcome.

Read more

Evidence cut-off: 30 July 2026, 17:00 UTC

On a petrochemical desk, public milestones often arrive before the physical evidence needed for the balance. I learned to hold an ETA outside inventory until operations confirmed receipt, and to leave a planned shutdown outside demand until the feed stop had an effective date. Korea’s current naphtha position needs that discipline.

The immediate picture has improved. MOTIR said on 28 July that Korean petchem companies had secured the naphtha required through August at above the previous-year level. Product inventories were stable, and the ministry was studying additional measures for September onward. [1]

That removes the case for treating an immediate national shortage as the base assumption. A buyer’s Sep-Dec position still depends on info that is private: on-spec inventory, accepted cargoes, terminal access, the operating plan and executable economics.

Barossa improves SK Incheon’s optionality

Santos loaded about 300,000 barrels of Barossa condensate on 24 July aboard the Boccadesse for delivery to SK Incheon Petrochem. [2] SK has stated where the resulting naphtha is intended to go: paraxylene, gasoline and jet-fuel production at the Incheon complex. [3]

I would record the cargo as a credible supply route for SK’s refinery and aromatics chain. The buyer balance changes after arrival, discharge and quality acceptance. At the cut-off, the public record had no accepted quantity, assay, yield split or allocation to a Korean steam cracker.

Capacity announcements need a physical date

The Yeosu and Daesan restructuring approvals are important for the medium-term capacity base. MOTIR has approved the targeted configurations, while H&L Advanced is scheduled to launch legally on 1 September. [4][5][6]

For Q4 procurement, the useful date is the day feed actually stops. Until an operator or filing establishes that date, the planned reduction stays outside the live balance. LG Chem’s Yeosu No.2 filing follows the same discipline: production was suspended on 23 March, the restart date was left blank, and LG Chem committed to re-disclose when a date is determined. [7]

Demand can move before capacity does

Operating rates, LPG co-feed and direct monomer purchases can change the naphtha requirement well before a formal closure. SK Innovation’s Q2 materials provide a newer directional signal for chemicals, without a site rate. MoneyToday and Yonhap remain the named site-level anchors for April-May. [8][9][10]

Public analysis reaches its limit here. A procurement decision needs the buyer’s approved monthly requirement and a matched margin. The public rate observations belong in a stress case rather than a company tonne allocation.

The next dates that can change the call

Four things can move this before September. S-OIL reports on 3 August, when Shaheen’s owner-accepted milestone and startup sequence may become clearer. [11] Barossa arrival and discharge should be checked in the same week. Company Q2 calls and H1 filings can replace the dated operating-rate anchors. On 26 August, the naphtha export regulation and the separate petrochemical anti-hoarding regime both reach their current legal boundary. [12][13]

My public-data conclusion is staged coverage. Keep the August improvement in the base case, preserve flexibility around the official triggers, and advance Q4 volumes only after the buyer’s own cover ratio and margin tests pass.

If you need this for one company

Public evidence cannot close a company balance. The Korea Q4 Company Screen converts one buyer’s approved operating plan, physical cover and executable economics into a September-December action map for a single complex, with three stress cases and one trigger update. Fixed pilot fee, written work only, no call required.

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The paid report provides the full trigger map, three illustrative stress cases, a reconciled worked example, claim-level sources and a fail-closed workbook. One concise trigger update is included after the first material event.

Notes and sources

[1] Ministry of Trade, Industry and Resources (MOTIR). Government conducts emergency review of naphtha supply as Middle East tension rises. 28 July 2026. https://www.motir.go.kr/kor/article/ATCL3f49a5a8c/172062/view

[2] Santos Limited. Santos announces successful sale and lifting of first Barossa condensate cargo. 27 July 2026. https://www.santos.com/wp-content/uploads/2026/07/Santos-announces-successful-sale-and-lifting-of-first-Barossa-condensate-cargo.pdf

[3] SK Innovation. SK Innovation E&S to bring home condensate from Australia after LNG. 27 July 2026. https://askinno.com/global/archives/156576

[4] MOTIR. Yeosu petrochemical restructuring approval. 22 July 2026. https://www.motir.go.kr/kor/article/ATCL3f49a5a8c/172042/view

[5] MOTIR. Daesan No.1 petrochemical restructuring approval. 25 February 2026. https://www.motir.go.kr/kor/article/ATCL3f49a5a8c/171535/view

[6] MoneyToday. H&L Advanced name and launch timetable for HD Hyundai-Lotte integrated company. 28 July 2026. https://www.mt.co.kr/industry/2026/07/28/2026072808561360349

[7] LG Chem / Korea Exchange (KIND). Temporary production suspension at Yeosu NCC No.2. 23 March 2026. https://kind.krx.co.kr/external/2026/03/23/001748/20260323007289/61241.htm

[8] SK Innovation. 2026 second-quarter earnings release. 30 July 2026. https://www.skinnovation.com/ir/earning

[9] MoneyToday. Korean cracker operating-rate observations. 14 May 2026. https://www.mt.co.kr/industry/2026/05/14/2026051414463592496

[10] Yonhap News Agency. KPIC raises NCC operating rate to 72 percent. 28 April 2026. https://www.yna.co.kr/view/AKR20260428040900003

[11] S-OIL / DART. Investor-relations meeting notice. 24 July 2026. https://dart.fss.or.kr/dsaf001/main.do?rcpNo=20260724800690

[12] MOTIR / Korea National Law Information Center. Regulation on naphtha export restrictions and supply adjustment. 27 March 2026. https://www.law.go.kr/LSW/admRulLsInfoP.do?admRulSeq=2100000276612

[13] MOTIR. Amendment to the petrochemical feedstock and product anti-hoarding and emergency supply-demand adjustment regulation. 1 July 2026. https://www.motir.go.kr/kor/article/ATCL0c554f816/65048/view

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Update, 27 July 2026

Reuters reported that Saudi Aramco had offered additional crude cargoes for loading at Sidi Kerir and that Asian refiners were seeking cargoes and vessels from the Egyptian port.

This is useful evidence that the northern route is being marketed and assessed commercially. It does not establish current bookable SU…

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Government approval makes the Yeosu restructuring plan executable, but contracts, boards, legal restructuring, competition review and permit succession still determine when commercial assumptions must change. This screen separates the exposures that need action now from those that only need monitoring or no action at all.

What changed

The Korean government approved the final Yeosu restructuring plan on 20 July and announced it on 22 July. The plan brings YNCC and Lotte Chemical Yeosu assets into a new integrated structure. The approved shutdown perimeter totals 1.39 mt/y of YNCC ethylene capacity. Within that perimeter, the 920 kt/y NCC2 shutdown is the additional step still ahead, while the 470 kt/y NCC3 is already stopped. The plan states that the affected units will remain stopped for at least three years. This is a minimum operating period, not evidence of permanent closure. The additional physical supply removal to plan for is therefore the 920 kt/y NCC2, not the full 1.39 mt/y.

Hanwha Solutions and DL Chemical plan KRW 545bn of equity injections to repay YNCC debt. The companies also plan KRW 253.2bn of restructuring investment, including shared infrastructure and conversion toward higher-value medical LDPE and POE applications. The government support package is stated at more than KRW 700bn, including new finance and import-insurance support. Creditor arrangements provide for repayment deferral through end-2029, while the support package targets a reduction in the competition-review period from 120 days to 90 days. Those are control dates and process targets, not a merger-closing date.

What approval does not prove

Approval does not establish the legal closing date, the final counterparty structure, the exact transition schedule or the commercial effect on any individual contract. The companies still need merger contracts, board approvals, the Lotte split and merger process, competition review and relevant permit procedures. The at-least-three-year shutdown period, end-2029 debt deferral and 90-day review target should therefore be tracked as separate operating, financing and regulatory clocks.

Which nominations depend on NCC2, NCC3, current YNCC supply or connected utilities? Direct physical exposure should be revalidated against the transition sequence rather than inferred from the headline capacity number.

Which contracts and master-data records assume the current counterparty identity? The split, merger and integrated-company sequence can affect invoicing, credit, change-of-control and documentary responsibilities.

Which high-value product claims rely on future investment rather than qualified supply? Medical LDPE and POE are investment objectives. They are not evidence of current start-up, specification or customer qualification.

The complete five-gate decision rule, worked application, operating controls and downloadable Yeosu exposure workbook follow for Paid subscribers.

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Budapest, 21 July 2026

Platts is consulting on a methodology change that could leave the physical cargo specification and delivery terms unchanged while altering the certification basis of the price reference. That creates a contract-control issue even before the market establishes a visible certification differential.

The current FOB Straits neat SAF assessment reflects ISCC EU-certified cargoes. ISCC CORSIA-certified cargoes are also considered, but may be normalized. Under the proposal published on 20 July, ISCC CORSIA-certified cargoes would become the reference basis from 1 September 2026. ISCC EU-certified cargoes could still be considered, but may be normalized.

The change is not final. Platts requested feedback by 10 August and also asked whether the market would benefit from a separate ISCC EU assessment or a tradable spread between the CORSIA and EU bases.

Current methodology versus the proposal

The proposal reverses the reference certification basis. The public notice otherwise leaves the HEFA-SPK specification, FOB Straits location, 5,000 to 10,000 mt parcel range and 15 to 30 day loading window unchanged.

A price reference, a contract certificate clause, the documents delivered with the cargo and the buyer’s intended claim can therefore point to different bases even when the physical fuel remains within specification.

Four questions before a fixing or approval

1. Which assessment symbol, pricing dates and methodology version govern the contract?

2. Which certification scheme, Proof of Sustainability and chain-of-custody records will the seller provide?

3. Which CORSIA, EU regulatory or voluntary claim does the buyer intend to support?

4. Does the contract state how a benchmark normalization or certification-basis adjustment will be handled?

The free diagnostic identifies the four headline questions. The paid workbook expands them into eight operational controls and reconciles failed controls with required evidence gaps.

Why the control matters beyond the benchmark name

Transport Canada’s 2026 SAF Blueprint notes that an international airline may need fuel to satisfy CORSIA sustainability requirements as well as local requirements in the receiving jurisdiction. It also identifies traceability, supply-chain certification, sustainability documentation, carbon-accounting methodology, attribute ownership and protection against double counting as separate control requirements.

The same physical SAF can therefore produce different compliance and claims outcomes under different accounting systems. That is why the benchmark basis, contract wording, batch-level evidence and intended claim belong in one approval record.

What Paid subscribers receive

The paid section applies the diagnostic to a worked October contract case, separates documentary gaps from pricing exposure, adds a desk-by-desk action matrix and provides a downloadable FOB Straits SAF Basis Alignment Mini-Screen.

The workbook records jurisdiction and claim controls, tests whether a pricing period straddles a methodology change, reconciles required evidence with the decision status and quantifies only buyer-entered basis, delay and replacement exposure. Blank values remain NOT QUANTIFIED.

Sources above the paywall

S&P Global Energy, current FOB Straits methodology, 2 February 2026:
https://www.spglobal.com/energy/en/pricing-benchmarks/our-methodology/subscriber-notes/020226-platts-updates-sustainable-aviation-fuel-fob-straits-assessment-feb-2

S&P Global Energy, proposal dated 20 July 2026:
https://www.spglobal.com/energy/en/pricing-benchmarks/our-methodology/subscriber-notes/072026-platts-proposes-to-update-saf-fob-straits-to-reflect-iscc-corsia-certified-cargoes-sep-1-2026

Transport Canada, Sustainable Aviation Fuels Blueprint, July 2026:
https://tc.canada.ca/sites/default/files/2026-07/sustainable-aviation-fuels-blueprint-canada.pdf

The worked case, decision rule and downloadable Mini-Screen continue below for Paid and Founding subscribers.

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Russia’s diesel restriction is now visible in the freight book.

Reuters, citing Kpler, put Russian diesel and gasoil loadings at 234,000 b/d during 1-10 July. June averaged 400,000 b/d. The 2025 average was about 817,000 b/d.

The current restriction runs through 31 July. Resolution No. 854 extended it to producers while retaining specified intergovernmental-agreement and transitional exemptions.

Replacement supply now travels farther. S&P Global described a shift from short Baltic movements toward longer routes from the US Gulf Coast, the Middle East Gulf and India.

LR2 freight has nearly doubled since early June. The Platts index for non-scrubber-fitted, non-eco vessels rose from $57,204/day to $97,872/day on 14 July. The physical ARA diesel crack reached $70.3/b on 13 July, its highest level since 23 March.

For an August nomination, the cheapest FOB quote can still be the wrong cargo. Vessel availability, insurance, loading lead, specification, financing and arrival exposure can reverse the ranking.

The 31 July decision will not settle the physical market by itself. A legal expiry needs to be followed by recovering Russian loadings and executable seller offers before a buyer can assume that the long-haul premium will unwind.

Paid subscribers receive the Russia Diesel Replacement-Barrel and Freight Screen. The Excel file excludes routes that fail origin, specification or provenance checks. Supply status then determines whether the next step is a firm order, an allocation request or a hold.

Paid access includes the working file, the post-decision refresh, material market updates and the subscriber archive. The examples demonstrate the method and are not live quotes.

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Public comments close at 12:00 on 9 August 2026. The draft supports several planning sensitivities; it does not yet support one settled private-sector compliance number.

South Africa has published one draft policy with three private-stock formulations. They do not reconcile. For a product importer, the practical question is immediate: could the 21-day reading require crude even when the business handles only finished products?

Three readings, three exposures

The executive summary on page 4 recommends 90 days of government stocks and another 14 days of refined products for licensed manufacturers and wholesalers. Section 9, on page 12, moves to 60 state days and 21 private days for licensed wholesalers and importers, with the private stock split 70% crude and 30% finished products.

Policy Statement 1 on page 16 then refers to 21 days of refined-product cover while retaining the crude-product split. The sentence cannot be implemented literally. Days, scope and physical stock form all change across the same official document.

The working screen therefore treats the Section 9 wording as a conservative company-level sensitivity, not as the final legal interpretation. It also runs the executive-summary case and an explicit national-portfolio sensitivity in which a product importer carries no company-level crude allocation.

Credit stock against the same category

The draft is silent on whether ordinary operating inventory can be pooled across categories. The prudent planning treatment is category-specific crediting until DMPR or counsel confirms otherwise. Diesel reduces a diesel requirement. It does not reduce crude exposure without explicit authority.

A worked exposure

Use a provisional annual reference volume of 1.0 billion litres. One day equals 2.74 million litres. Under the 21-day body sensitivity, gross stock reaches 57.53 million litres: 40.27 million litres of crude and 17.26 million litres of finished products.

Now enter 9.5 million litres of eligible product inventory and no eligible crude. Category-specific crediting leaves 40.27 million litres of incremental crude and 7.76 million litres of incremental products, or 48.03 million litres in total. Pooling the product inventory before applying the split would understate crude exposure by about 6.65 million litres.

ILLUSTRATIVE: The reference volume, stock, prices, funding terms and storage inputs are examples. Replace them with company data and the final regulatory methodology.

Why act during consultation

The policy contemplates mandatory private stocks, monthly reporting and penalties under the National Energy Act. Refined strategic products would rotate at least every three months. The draft also acknowledges a refined-product storage shortfall and assigns National Treasury and SANPC to develop financing or guarantee mechanisms.

The missing calculation method, phase-in, eligible-stock rules, storage access and financing terms prevent a final compliance decision. They do not prevent a company from identifying which interpretation would create a crude-handling problem, how large the funding range could be, and which questions need a written answer before storage or bank commitments are signed.

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Saudi Aramco published its August official selling prices on Monday. Arab Light to Asia printed at 1.50 dollars under the Oman/Dubai average, the first discount since June 2020 (Aramco pricing statement via Argaam, 6 July 2026).

The arc from the war peak: May +19.50, June +15.50, July +9.50, August -1.50. Reuters called the 11 dollar cut the biggest in its records, which reach back to 2003.

That is the headline. The sheet says more.

The slate, not the headline

Europe took the largest cut in dollar terms, 15 off Arab Light, but from war-inflated levels back to roughly flat: +0.85 in the northwest, +0.65 in the Mediterranean. North America kept a premium on every grade, +2.65 to +5.95. Asia is another matter: the entire slate except Super Light was cut through zero, and the discount deepens as the barrel gets heavier and more sour. Extra Light -1.00, Light -1.50, Medium -3.25, Heavy -4.60.

This is not a blanket retreat: Aramco is defending specific barrels, medium and heavy sour east of Suez, where reopened Gulf volume meets the weakest Chinese buying in a decade. The buyer being defended is specific too: Bloomberg reports Chinese crude purchases at a ten-year low, and Renaissance Energy Advisors’ Ahmed Mehdi, quoted by Bloomberg on Monday, read the cut as a function of Hormuz’s messy normalization rather than a price war, with pricing needing to be competitive enough to reinvigorate Chinese interest. Not everyone reads it that benignly: Mizuho’s Robert Yawger told WSJ clients it increasingly looks like the Gulf producers are gearing up for a price war.

In February this desk wrote that Arab Light’s share erodes at nomination, not at invoice: the exposure is created in the weeks when parity quietly holds and substitutes stop being penalized (”Arab Light: share erodes before it shows,” 22 February 2026). That note promised an update when the parity regime changed. The OSP side moved through zero on Monday; whether delivered parity against substitutes moved with it is the parcel question.

What the cut does and does not tell you

A record cut is not a buy signal, and by Tuesday morning the market had said so out loud. Reuters’ refiner and trader check found August-loading Saudi crude still a few dollars a barrel more costly than rival Gulf grades, with one Indian refiner asking why he would buy more Saudi oil while Upper Zakum and Das are on offer around 7 dollars under, and Vortexa’s Emma Li noting competing Middle East spot grades trading at even deeper discounts. An official selling price is one leg of a delivered cost. It tells you nothing by itself.

What the cut does, precisely, is move the hurdle. A hurdle is not a call. It is the level a competing barrel must clear for switching to pay, and whether it clears is your parcel’s arithmetic, not mine. A term buyer’s August question is unchanged in form: nominate full volume under the term formula, or cut nominations and buy spot. What changed is the number the spot alternative has to clear.

The arithmetic, worked once

Take a term buyer of Arab Medium weighing Upper Zakum spot, the cleanest pair: both medium sour, both load in the Gulf, so freight, war risk and financing largely net out and the comparison lives in differential space against Dubai.

Term Arab Medium now comes at the benchmark minus 3.25, by the official sheet. On Monday’s information the spot leg was the reported wording of ADNOC’s recent tenders, flat to a slight premium to Dubai: against that sensitivity, term Arab Medium sat 3.25 to 3.75 dollars per barrel below the spot barrel, before quality.

Tuesday moved the spot leg. Reuters’ trader check puts Upper Zakum at 6 to 8 dollars under Dubai for ship-to-ship transfer at Sohar, and an Indian refiner indicates Upper Zakum and Das around minus 7. Against the minus 3.25 OSP, the raw differential flips 2.75 to 4.75 dollars in the spot barrel’s favor. But the basis moved with the number: the Sohar barrel already sits outside the strait, and Reuters’ own freight quotes carry the reconciliation - a VLCC for the Sohar trade at 4 to 5 dollars a barrel, more than double that to load inside the Gulf at Ras Tanura, one estimate putting the all-in inside-versus-outside wedge near 15. Whether the deep spot discount survives that wedge for your discharge port is exactly the arithmetic the headline cannot do for you. The official leg is fact; both spot legs are dated indications, and yours to replace.

Run the same logic against ESPO and the honest answer remains: blocked. The freshest widely reported ESPO range dates from mid May, before the strait reopened, and using it would manufacture a conclusion. Against Murban, the working file is illustrative rather than blocked: the Arab Light side moves with the Oman/Dubai proxy, Murban is fixed off its exchange mark, and on Tuesday’s trader-indicated freight the inside-Gulf lift cost pushes term Arab Light above delivered Murban - a freight-regime read, not a grade call, and quality is still yours. Different alternatives fail or resolve on different inputs, which is why this is parcel arithmetic and not a headline read.

A footnote from Monday’s feed, and one more reason to run your own numbers: misread versions of the cut circulated within hours of the print at 1.10 dollars. The print is 11.00. The error is a factor of ten. (Screenshot archived, 6 July.)

What happens next

SOMO, ADNOC and KPC print in the coming days. Who follows Aramco under the benchmark, on which grades, and how deep, will show who is defending volume rather than price. The risk leg is live too: Reuters carried an Axios report of missiles fired at two commercial ships in the strait overnight, the ships reported damaged, and ANZ notes transit recovery has stalled in single digits - the inside-versus-outside lift wedge that decides these comparisons is not a settled number. ADNOC’s answer carries an extra wrinkle: its offshore grades are in transition from Murban-linked to Dubai-linked formulas, so even the shape of its sheet is information.

The paid annex carries the working file: a parcel input sheet, the full source log with print dates and status flags on every number, the worked cases above with their status gates, sensitivity grids, and the trigger list for the rest of the round. It runs on your inputs, not on assumed ones. As SOMO, ADNOC and KPC print, the file updates, and annex subscribers receive each update without re-purchase. The annex is for desks that need the hurdle by parcel, not by headline. Subscribers from the February note: this is the update that note promised.

Data note. August and July OSP sheets: Aramco pricing statements via Argaam, 6 July 2026 (argaam.com/ar/article/articledetail/id/1918113) and 6 June 2026 (argaam.com/en/article/articledetail/id/1910967). May and June differentials: IDNFinancials citing Reuters and the Aramco statement, 6 June 2026. Records claim and pre-announcement expectations: Reuters, 6 July 2026 (reuters.com/business/energy/oil-slips-after-opec-agrees-raise-output-targets-2026-07-06). Upper Zakum and Das indications, Sohar STS basis, inside-versus-outside freight quotes, and refiner and trader color: Reuters, “Saudi oil price cut unlikely to convince sated Asia buyers, traders say,” 7 July 2026, screenshot filed. Overnight strait incident and transit-recovery stall: Reuters market report, 7 July 2026, citing Axios and ANZ. Price-war counter-view: WSJ Energy and Utilities Market Talk, 6 July 2026. China-Saudi flow estimates: Reuters Open Interest column citing Kpler, 7 July 2026. Chinese purchase level, trader color and the Renaissance Energy Advisors comment: Bloomberg, “Saudis Make Biggest Oil Price Cut in Decades as Market Weakens,” 6 July 2026, primary verified, screenshot filed. Brent and Murban front-month marks of 6 July and the August Brent/Dubai swap spread: The Officials (Onyx Capital Advisory), Euro Edition, 6 July 2026, screenshot filed. The 3 July settlements per Trinity Securities’ daily (citing Aspen) and Investing.com remain logged in the working file. ADNOC tender levels: OilPrice.com, 3 July 2026. ESPO range: Reuters via Hydrocarbon Processing, mid May 2026, flagged stale in the working file. Where no print is in hand, the file says user input required rather than inventing one.

Gyula Toth | Physical Constraint Desk

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The returning Gulf barrel is the most crowded headline of the week, so here is what happened before we get to what it costs.

Aramco resumed loadings at Ras Tanura on June 27 after a halt of nearly 4-months, put at least 5 laden VLCCs through the strait carrying around 10 million barrels, and switched to spot pricing to move them into Asia, some on a delivered basis on its own Bahri tonnage.

Kuwait lifted all force majeure notices on June 19 and ran June at 1.65 million bpd, up from roughly 580,000 in May and still well short of the pre-war level near 2.5 million.

SOMO offered term buyers 14 to 16 dollars a barrel off OSP on Basrah Medium and 16.80 to 18.80 on Basrah Heavy for July loading, tiered by loading window.

Bloomberg reported on July 3 that TotalEnergies is offering millions of barrels of Iraqi crude for prompt delivery into Asia; no second outlet has printed that one yet, so treat it accordingly.

A desk skimming those headlines sees one story: supply is back, buy the dip.

A desk taking title sees four offers with four different risk owners, and the difference is worth real money.

The sharpest contrast is between the delivered Aramco parcel and the FOB Basrah parcel. On the delivered cargo, Aramco owns the vessel nomination, the freight, the war-risk cover and the corridor problem; the buyer’s residual exposure is delay and whatever regime greets the next cargo. On the FOB Basrah cargo the buyer inherits all of it, and SOMO’s own framing gives the game away: trade sources describe the discounts as compensation for chartering costs into Hormuz. A week earlier a SOMO spot tender failed outright because buyers could not book tankers into the Gulf. Fifteen dollars is not generosity. It is a price tag on a bundle of route risks, and the only question worth asking is whether the tag covers the bundle.

The bundle repriced violently in both directions inside two weeks. Reported VLCC fixtures through Hormuz to China printed at 439,000 to 469,000 dollars a day in late June, against 220,000 to 230,000 for Gulf of Oman loadings that avoid the strait entirely. By July 1, reporting around the SOMO discounts referenced Middle East Gulf to China time charter near 300,000. Hull war cover has come off its wartime range of roughly 4.5 to 6 percent of vessel value to somewhere between 2 and 4 percent after discounts, depending on the broker, against about 0.25 percent before the war. Both curves are falling. Neither is normal. A screen quoting the June peak as live overstates the route cost; a screen ignoring it forgets how fast this market gaps.

Then the clock, which almost nobody is pricing as a dated field. The reported interim framework is being treated as a 60-day free-transit window from June 17, which puts expiry on or about August 16. What follows is openly contested between the two states that would administer it. Iran and Oman have put a proposal for jointly collected fees in front of Washington. Iranian officials say payment would be compulsory. Oman’s foreign minister says Oman does not support imposing fees. The White House position is that Iran cannot toll an international waterway at all. The revenue expectations alone measure the distance between the parties: the Malacca cooperative fund collected about 23 million dollars over fifteen years, while figures circulating on the Iranian side run to tens of billions annually.

None of that gets resolved from a trading desk. What a desk can do is price each cargo against one hard question: does this parcel arrive before, near, or after August 16? A cargo discharging in late July lives in a different regime than the same cargo slipping two weeks. And fee exposure cannot honestly be quantified as a fixed number yet, because the voluntary versus compulsory question is unresolved; an offer that hands you a settled fee line today is making it up.

So I built the screen and ran it.

Below the paywall: the per-barrel arithmetic on whether the 15-dollar Basrah discount clears the full bundle at current prints and at the late-June stress prints, with the two answers several dollars apart; the four fee scenarios and how each one is priced; the timing rule; a worked delivered-Aramco example with the specific contract terms a buyer should ask for; the source list with verification status; and the downloadable

Excel screen with the scenario toggle, the arrival-vs-expiry check and a decision output per cargo, so you can run your own parcels rather than mine.

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FREE PREVIEW

South Korea-linked resin pricing has moved from a policy headline into a negotiation issue.

The naphtha export restriction remains the legal reference point. MOTIR has not confirmed early abolition, and the official position still depends on Middle East conditions, Hormuz passage, and naphtha and petchem supply-demand.

The operating picture has also changed. Korean reporting points to improved naphtha availability and higher cracker run rates. Crude procurement held up better than a pure disruption story would suggest. Late-June price references have moved away from the March stress window.

That creates a cleaner buyer question. A supplier can still point to the active rule, but a buyer can ask whether today’s offer reflects current feedstock, resin replacement value, and spread logic.

LG Chem is the useful supplier-side marker. The company has announced targeted delivery-price support for selected SME customers using government naphtha support funds. That does not settle the wider market, though it changes the conversation with suppliers that still defend offers using March-May disruption language.

Procurement teams need the current basis. Distributors need to check inventory marks. Credit and LC desks need to look at collateral value and tenor.

The paid screen gives the full price anchors, supplier pass-through test, inventory markdown thresholds, credit review logic, wording to use with suppliers, and the full source list.

Subscribe to continue. The full screen is for paid subscribers.

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Russia has not announced a producer-level diesel export ban. The question that matters is who any restriction reaches.

A non-producer restriction mainly affects traders, resellers and non-integrated exporters.

A producer-level ban is a different market. It reaches the part of the system that carries most of the export flow and makes replacement barrels, origin wording and credit terms the binding constraints.

The domestic pressure is real: pump-level shortages, regional sales limits and refinery disruption. The official line is not “no fuel,” though. Novak has described sufficient volumes, a diesel surplus, a logistics rebalancing and demand inflated by panic buying.

Both pictures can hold at once, but the surplus needs a caveat. Russian diesel output fell roughly 10% in May after a comparable April drop, with refineries accounting for close to a quarter of capacity halted or running cut after drone strikes (Reuters), while seaborne exports held steady on released inventories. Read that way, the surplus is a stock being drawn down against falling production, not a standing excess. A producer ban in that setting looks closer to inventory defense than to surplus redistribution.

That sharpens the live question. Does Moscow leave producers outside the diesel restriction, or pull them in for a short window to hold more volume at home while output is impaired?

The Brent-gasoil crack stays firm enough to keep the question commercial. It has to be read with care: it can carry Russia policy risk, Hormuz risk, freight stress and broader distillate fundamentals at the same time.

For buyers, the practical task is to separate three things: the policy wording, the market price, and their own route exposure. Brazil and Turkey are the routes the Reuters flow trail supports. Everything else stays watchlist until separate flow data backs it.

The free read: the diesel issue is live because producer wording has not changed while distillates still carry stress, and because the “surplus” is thinner than the official framing suggests.

Paid section: I size the producer-ban ceiling, separate confirmed buyer routes from watchlist exposure, give the crack trigger bands with a Russia-versus-Hormuz driver check, and set out what each desk checks before paying for cover.

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Korea’s cracker problem is no longer only a weak-spread story.

The public debate is still focused on China oversupply, delayed naphtha cracker cuts and whether Korea can force restructuring quickly enough. Those issues still matter. They are just too broad for the next desk decision.

S-Oil’s latest naphtha contract with Korea Petrochemical gives that decision a harder edge.

At the same time, Korean naphtha crackers are moving into reverse-lag pressure: higher-cost feedstock entering production while product prices face renewed downside.

Early market signals already point to margin pressure; for desks, the question is when to act.

Procurement, naphtha trading and olefins market-intelligence teams need to test whether their baseline assumptions still hold before the next contract window closes.

The paid brief separates near-term margin pressure from the contract-timed feedstock question, and tracks how a new Ulsan asset changes the supply structure.

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