From oil at sea to delivered diesel: a supply chain under strain

On 20 October, Reuters reported that two US Department of Energy officials were working with refiners to increase diesel production. The request followed a quarter in which US refineries had already operated at an average 95% of capacity, according to the Energy Information Administration. Together, those facts capture the difficulty facing the oil market: returning crude cargoes help replenish supply, while the availability of usable fuel still depends on refinery operations, shipping and delivery schedules. ^{14, 4}

Following that chain changes the way oil risk looks. A barrel can exist, have a buyer and count towards global inventories while remaining far from the refinery or depot that needs it. Its price can be hedged, even as its owner must finance the voyage and meet margin calls. The owner may have to fund hedge payments before the cargo reaches its buyer and generates cash.

This investigation brings together public material from the International Energy Agency (IEA), the US Energy Information Administration (EIA), emergency-reserve announcements and the rules governing hedging markets. Its evidence cut-off is 21 October 2026, before the US weekly release scheduled for later that day. Observations, forecasts and illustrative calculations are identified throughout. Full source URLs, relevant passages and access details appear at the end.

Inventories are changing location

The IEA’s public report of 14 October offers a revealing starting point. In September, observed on-land inventories fell by 113 million barrels, while oil on water rose by 103 million barrels. The net change in observed global stocks was therefore a decline of 10 million barrels. The IEA associates the increase at sea with a rebound in exports. ¹

For the eventual buyer, the location of those stocks matters. Material already held in a depot can respond relatively quickly to an order, subject to its specification and the available distribution network. A cargo at sea must complete its voyage, secure a discharge slot and enter the industrial supply chain. Adding both categories is useful for measuring observed inventories; assessing immediate pressure also requires knowing where the barrels are.

The figures do not identify 103 million barrels as stranded, or trace individual barrels from onshore tanks to ships. More cargoes at sea can reflect higher departures, longer journeys or a combination of the two. The aggregate publication does not separate those contributions. That distinction matters because additional oil in transit may be preparing the ground for an improvement in supply, even while usable stocks at destination are temporarily falling. ¹

A simple example illustrates the role of time. Imagine a route carrying a sustained one million barrels a day. With a twenty-day transit, roughly twenty million barrels would be at sea. At thirty-five days, the same steady flow would require thirty-five million barrels in transit. The extra fifteen million would occupy ships and tie up financing. During the transition between the two steady states, arrivals could be delayed before the new pattern settles. This is an illustration of the relationship between throughput, transit time and inventory, rather than a measurement of any route in October.

The EIA describes this type of pressure in its 6 October outlook: longer routes reduce vessel availability and, alongside insurance costs, raise the cost of delivered supplies. A fall in the price of crude at origin can consequently be partly absorbed by a more expensive voyage. For a refinery, the relevant input cost includes getting the feedstock to its plant. ²

Maritime reporting needs similar care. In its 18 October advisory, the Joint Maritime Information Center said claims that two supertankers had struck mines on 17 October were unsubstantiated. Treating those claims as confirmed losses would insert an unproven supply disruption into the analysis. Security reports, vessel positions and discharged volumes provide different kinds of evidence, each with its own limits. ⁹

Refining has its own pace

Once crude arrives, it must still become usable fuel. A refinery separates petroleum into fractions, converts some molecules and treats the resulting products to meet the required specifications. Its equipment and the composition of its feedstock shape the range of outputs it can produce. Diesel is one part of that connected production process; increasing its share depends on operational adjustments and available conversion capacity. The EIA’s technical description explains why an additional barrel of crude does not automatically yield an additional barrel of diesel. ²⁰

Trade data also show a gap between crude supply and product availability. The IEA puts Middle Eastern refined-product exports at 1.9 million barrels a day in September 2026, compared with 4.7 million before the war, a calculated decline of about 60%. The aggregate includes several products, and the public summary does not specify the exact month used for the pre-war comparison. It indicates a substantial reduction in regional product supply without, on its own, measuring the global diesel shortfall. ¹

US refinery utilisation averaging 95% in the third quarter helps explain the scope for a response. Plants already running intensively have less room to compensate quickly for disruption elsewhere. The national percentage measures the use of refining capacity across different sites. The remaining five percentage points cannot simply be treated as immediately available diesel capacity. Estimating that would require information about the units involved, their condition, maintenance requirements and suitable crude supplies. ^{4, 20}

High diesel values can encourage refiners to adjust their output, and additional supply can eventually ease the market. Industrial changes nevertheless take time to turn a price signal into delivered fuel. Risk emerges during that interval when local inventories have to bridge the gap.

Diesel can rise while crude falls

Price series make the divergence visible beyond the daily Brent headlines. Between June and July 2026, the EIA’s monthly average physical Brent price fell from $85.40 to $83.76 a barrel, a calculated decline of 1.9%. Over the same period, ultra-low-sulphur diesel quoted in New York rose from $3.401 to $3.913 a gallon, an increase of 15.1%. The two markets moved in opposite directions. ¹⁵

To make the levels comparable, the chart converts diesel into dollars per barrel using 42 US gallons to the petroleum barrel. In September, the diesel average was therefore $208.15 a barrel, against $114.16 for Brent, giving a difference of approximately $93.99. All nine months of available 2026 observations are displayed to place the summer movement in a broader context. These are monthly averages of physical spot quotations published by the EIA using Refinitiv data, rather than futures prices. ¹⁵

The gap indicates the relative value of the refined product, but it needs careful interpretation. The crude and diesel quotations refer to different markets and locations. The comparison does not follow a single cargo from its purchase through the sale of all the products made from it. It also excludes refinery energy use, operating costs, freight and other components of revenue. Treating the $93.99 difference as a refinery’s net profit would therefore misrepresent its economics. The EIA and CME explain crude–product price differences as gross margin indicators whose conventions need to be specified. ^{5, 16}

There is a practical consequence for businesses buying diesel. A hedge linked only to crude can leave them exposed to changes in that differential. Compensation may cover too little of the increase in the fuel bill; in a scenario where crude falls while diesel rises, a long crude hedge can itself lose value as the bill grows. Product quality, delivery location and timing can introduce further differences between the instrument and the actual purchase. This exposure to a mismatch, commonly called basis risk, depends on the hedge contract as well as the physical market. ¹⁶

Retail prices add more stages: distributors’ earlier purchases, transport, storage, taxes and commercial terms. Wholesale series help explain the pressure moving through the supply chain. Converting a one-dollar movement in Brent into an immediate, fixed change at the pump would require assumptions that those series alone cannot support. ⁵

Winter inventories are built locally

US inventory data provide a second test, this time of available quantities. In the 15 October release, covering the week ended 9 October, US distillate stocks stood at 102.611 million barrels, compared with 117.030 million in the corresponding reporting week of 2025, a decline of 12.3%. On the East Coast, the statistical region known as PADD 1, stocks were 21.513 million barrels, against 27.688 million, down 22.3%. ^{6, 7, 8}

The difference between those percentages helps locate the vulnerability. The EIA notes that the East Coast consumes more distillate than it produces and relies on supplies from the US Gulf Coast and on imports. More expensive or less reliable deliveries make the regional inventory buffer more significant. A relatively better national supply position can coexist with a local difficulty if the product fails to reach the right depot at the right time. ³

The distillate category in these tables includes diesel and heating oil across several sulphur categories, making it broader than road diesel alone. East Coast stocks are part of the US total, so adding the two series would count those barrels twice. The US statistical perimeter also includes certain quantities in transit and pipelines; it differs from the global on-land inventory category used in the first chart. ^{6, 7, 8}

The chart matches the same ordinal reporting weeks of 2025 and 2026, from January to early October. Its final pair compares Friday 9 October 2026 with Friday 10 October 2025. It makes no adjustment for weather, demand or capacity changes. The annual decline is an inventory observation, and the contribution of each disruption cannot be inferred from these series alone. The same discipline is needed when discussing days of supply: a stock measured in barrels can only become a measure of time after selecting a relevant consumption rate and a consistent scope.

The underlying supply mechanism is straightforward. Production and incoming deliveries must cover outflows while allowing the available buffer to rebuild. Higher production can be absorbed by stronger exports or demand before it appears as additional stocks. The EIA describes this interaction between production, trade and inventories in its diesel analysis. Monitoring refinery operations alone would consequently miss part of the pressure. ⁵

A hedged cargo can still need cash

Transit time also has a financial expression. Consider an entirely hypothetical example. A trader buys and pays for one million barrels at $100 each, committing $100 million. At the same time, the trader sells an equivalent quantity of futures at $100 to hedge a fall in the inventory’s value. Assume that the cargo and hedge match perfectly, with no costs, initial margin or delivery risk.

During the voyage, both prices rise to $120. The cargo is now worth $120 million, although it has yet to be sold. The short futures position, meanwhile, accumulates a $20 million loss that is settled in cash through variation margin. The trader must finance an additional $20 million while the gain on the physical cargo remains unrealised. When the cargo is sold, the $120 million receipt, less the $20 million paid on the hedge, leaves economic proceeds of $100 million before costs. The model fixes the selling price while retaining an interim liquidity requirement.

ICE’s Brent contract specifies daily marking to market. The Bank for International Settlements’ work on commodity markets in 2022, and the Financial Stability Board’s 2024 recommendations, explain how margin calls can draw on the liquidity of an economically hedged participant. Those documents establish the mechanism and the need to prepare financing. The example above is not an estimate of losses or financial distress at any trader in October 2026. ^{17, 18, 19}

Cash reserves, a bank facility or assets that can be used to raise funding can help bridge the mismatch. Their availability, cost and conditions then matter alongside the expected return on the transaction. In an actual trade, physical and futures prices can also diverge, bringing back the basis risk discussed earlier. The quality of a hedge therefore has to be considered together with the ability to fund it until settlement. Our guide explains how to build a usable liquidity schedule. ^{18, 19}

Even the basic carrying cost gives a sense of the importance of time. At a hypothetical annual rate of 6%, keeping $100 million financed for an extra fifteen days costs approximately $247,000, using a 365-day year. This calculation excludes the financing of margin calls, compounding, freight and insurance. It illustrates a timing cost without estimating any observed voyage or credit facility.

From reserve announcements to delivered fuel

Emergency reserves call for the same attention to product and timing. Our analysis of crude and diesel reserves explains the industrial steps between storage and delivery. The G7’s 2 October statement refers to 100 million barrels in total over four months, including an accelerated diesel component in the first twenty days. A White House fact sheet published on 5 October instead describes an agreement for 100 million barrels of refined diesel from European strategic reserves. The two formulations use different product scopes. ^{10, 12}

The IEA’s 15 October statement says around 100 million barrels remain to be released under the collective action, with plans including more than 20 million barrels of diesel as soon as possible. That diesel volume is a component of the remaining total and a lower bound, since the statement says “over”. Treating it as a ceiling, or adding it to the 100 million barrels, would change the meaning of the announcement. ¹¹

The public material examined for this investigation contains no confirmation of a separate agreement covering 100 million barrels of European diesel. That gap does not establish the authors’ intentions. It does require preserving the scope of each statement and showing readers the documentary discrepancy rather than treating the broadest formulation as an established quantity.

The economic value of a reserve release then depends on the product, its location and the actual delivery schedule. Crude still needs processing. Finished diesel can address a depot’s requirement more directly, provided transport and specifications permit. A four-month announcement, by itself, says little about the rate of deliveries in any particular week. The IEA also refers to national circumstances in implementing releases. Assessing their effect on market tightness requires tracking actual withdrawals and destinations as well as the announced total. ^{11, 20}

The conditions for relief can be tracked

Several developments could improve the balance. OFAC’s General License 135, dated 9 October, authorises certain transactions involving the sale, delivery, offloading and import of Russian-origin diesel until 12:01 a.m. Eastern Daylight Time on 7 April 2027, subject to its terms. It creates legal room for trade without determining how much fuel is produced or shipped. On 20 October, Reuters reported Russian cargo departures signalling Turkey and Brazil as destinations. That evidence documents renewed movements; the indicated destinations do not yet establish completed discharges. ^{13, 21}

The EIA’s October outlook also envisages a gradual improvement in supply and a slower drawdown of global inventories, while high prices weigh on demand. This is a forecast based on information available at the beginning of the month. Repairs, more normal shipping routes and changes in consumption could therefore relieve pressure, with their timing and execution determining how quickly the effect reaches buyers. ²

Four developments would be especially informative: arrivals of refined products that lead to a sustained rebuilding of regional inventories; a narrowing of crude–diesel price differences using consistent locations and conventions; lower delivered costs and shorter delivery times; and reserve withdrawals documented by product and destination. Taken together, they would provide stronger evidence of relief than an isolated move in Brent or a report of departing ships.

The vulnerability most clearly supported by the evidence is the need to synchronise the supply chain. More cargoes at sea can prepare the way for improvement, while refining and local inventories determine how that improvement reaches users. Financial hedges accompany the journey with payment schedules of their own. Following the product, its location and the date at which it becomes available gives an industrial buyer or lender a more useful picture of oil risk. Our investigation of energy bills and their financing adds the role of exchange rates.

Method, data and scope of the examples

This edition closes on 21 October 2026 before the EIA weekly release scheduled for 10:30 a.m. Eastern time, or 4:30 p.m. in Paris. The latest stock observations used cover 9 October and were published on 15 October. STEO forecasts were prepared at the beginning of October and are kept separate from September observations. The IEA’s public summary is accessible; its full report requires a subscription. ^{1, 2, 8}

Figure 1 is an additive decomposition of changes in observed global stocks: −113 + 103 = −10 million barrels. It describes their location, without tracking individual cargoes. Figure 2 uses EIA physical spot series Europe Brent FOB (RBRTE) and New York Harbor ULSD (EER_EPD2DXL0_PF4_Y35NY_DPG), January–September 2026. Monthly averages are unweighted means of daily closing quotations; quotation days can differ between series. Conversion: dollars per US gallon × 42 = dollars per barrel. Relative change: (final value / initial value − 1) × 100. The September difference is calculated before rounding: 4.956 × 42 − 114.16 = $93.992 a barrel. It compares different products and locations, before refinery costs and other revenues. ^{1, 15}

Figure 3 converts WDISTUS1 and WDISTP11 from thousand to million barrels and pairs the same ordinal reporting weeks in 2025 and 2026, ending on 10 October 2025 and 9 October 2026. PADD 1 is included in the US total. Distillates span several products and sulphur categories; the data are unadjusted for weather or demand. ^{6, 7, 8}

The transit and cash-flow examples are hypothetical. At constant throughput in a steady state, inventory in transit = daily flow × journey time: one million barrels × 20 or 35 days. In figure 4, one million barrels is paid for at $100 each and perfectly hedged by a futures sale at the same price; both prices rise to $120. The cumulative $20 million hedge loss is paid before the physical sale. It is counted once: $120 million from the sale − $20 million already paid = $100 million, against an initial purchase of $100 million. The illustrated peak gross funding need is $120 million, before initial margin, fees and basis risk. The separate carrying-cost example is $100 million × 6% × 15 / 365 = $246,575.34, using simple ACT/365 interest. The rate is hypothetical; the calculation excludes freight, insurance and margin funding.

Reserve statements are compared using their own products, volumes and schedules. The remaining 100 million barrels in the collective action include the component of more than 20 million barrels of diesel. Signalled vessel destinations remain distinct from completed discharges. The opening illustration is an AI-generated conceptual image. ^{10, 11, 12, 21}

Sources and documents reviewed

1. S01 · International Energy Agency · 2026-10-14 · Accessed 21 October 2026.Oil Market Report : October 2026Public page: Highlights; Fragile rebound; Gasoil and diesel market tightness set to extend into 2027. September observations and separate forecasts.
   Scope and access

   September stock changes are −113 million barrels on land, +103 million on water and −10 million overall. The increase on water also accompanies recovering exports; its causal decomposition is not published. The 1.9 versus 4.7 million barrels/day comparison concerns Middle Eastern refined-product exports; the page does not date its pre-war baseline more precisely. Public summary of the 14 October edition consulted, including Highlights, Fragile rebound and the diesel section. The full subscription report was not obtained.

2. S02 · U.S. Energy Information Administration · 2026-10-06 · Accessed 21 October 2026.Short-Term Energy Outlook : Global oil marketsOctober 2026 edition, forecast completed on 1 October. Archived PDF: table 2, page 32; table 3a, page 33.
   Scope and access

   Brent averages of $96.32/barrel in 2026 and $83.74 in 2027 are forecasts, not current quotations. The easing scenario depends in part on restored flows. EIA historical baselines and modelled balances should not be equated with IEA observed inventories. Official October-edition page and relevant passages in the archived PDF consulted. Annual averages and future paths are forecasts completed on 1 October. Archived October 2026 PDF. October-vintage data.

3. S03 · U.S. Energy Information Administration · 2026-10-06 · Accessed 21 October 2026.Short-Term Energy Outlook : Petroleum productsOctober 2026 edition: U.S. retail gasoline and diesel prices; East Coast distillate inventories. Forecast completed on 1 October.
   Scope and access

   The East Coast inventory shortfall of 32% refers to September and the 2021–2025 seasonal average. It differs from the chart’s weekly year-on-year comparison. Regional dependence on US Gulf Coast shipments and imports explains the logistics exposure; the stated future levels are forecasts. Official October page and corresponding STEO passages consulted. The regional five-year comparison and forecasts remain distinct from the weekly observations. Archived October 2026 PDF.

4. S04 · U.S. Energy Information Administration · 2026-10-05 · Accessed 21 October 2026.Crude oil prices and refinery margins generally increased throughout the third quarterPassages on refining margins and US refinery utilisation in the third quarter of 2026.
   Scope and access

   US refinery utilisation averaged 95% in the third quarter. This measures overall crude throughput, not spare diesel production capacity. Price charts partly use Bloomberg data and are not reproduced. Official 5 October article consulted. The 95% third-quarter utilisation rate is explicitly confirmed. Bloomberg series in its charts are not used in the price-chart calculations.

5. S05 · U.S. Energy Information Administration · 2026-09-18 · Accessed 21 October 2026.What goes into diesel prices?Diesel price components, gross refining-margin definition, production and exports. Data include 14 September and the week ended 11 September.
   Scope and access

   Crude prices, refining costs and margins, distribution and taxes enter at different stages. The note also explains how high output and low inventories can coexist as exports increase. Its September prices are not used as 21 October quotations. Official 18 September article consulted for price components, the gross price-gap definition and the relationship between production, trade and stocks. September point quotations are not presented as 21 October prices.

6. S06 · U.S. Energy Information Administration · 2026-10-15 · Accessed 21 October 2026.U.S. Ending Stocks of Distillate Fuel OilWeekly series WDISTUS1, thousand barrels. 2025–2026 observations; latest included week: 9 October 2026.
   Scope and access

   102.611 million barrels on 9 October 2026 versus 117.030 on 10 October 2025; calculated change −12.3%. Distillates cover all sulphur levels and uses including heating and transport. The scope includes some pipeline or in-transit stocks; it is not identical to IEA global on-land inventories. Official history consulted and 2025–2026 observations checked directly. Latest week in the 15 October release: 9 October 2026. Cross-checked against dated table 6 CSV and PDF; accessed before the 21 October release scheduled for 10:30 Eastern. Dated table 6 : CSV. Dated table 6 : PDF. Weekly release schedule.

7. S07 · U.S. Energy Information Administration · 2026-10-15 · Accessed 21 October 2026.East Coast (PADD 1) Ending Stocks of Distillate Fuel OilWeekly series WDISTP11, thousand barrels. 2025–2026 observations; latest included week: 9 October 2026.
   Scope and access

   21.513 million barrels on 9 October 2026 versus 27.688 on 10 October 2025; calculated change −22.3%. PADD 1 covers the East Coast. The annual comparison differs from the STEO five-year comparison. Seasonal curves align Fridays of the same ordinal rank, with a one-day calendar difference. Official history consulted and 2025–2026 observations checked directly, then cross-checked against table 6 dated 15 October. Weeks are paired by ordinal rank, without interpolation or seasonal adjustment. Dated table 6 : CSV. Dated table 6 : PDF.

8. S08 · U.S. Energy Information Administration · 2026-10-15 · Accessed 21 October 2026.Weekly Petroleum Status Report : 15 October 2026Dated report archive; tables 1 and 6. Inventories for the week ended 9 October 2026.
   Scope and access

   Table 1 separates commercial crude inventories excluding the strategic reserve from the strategic reserve; table 6 details distillates. Published changes use unrounded data. Both dated CSVs were cross-checked against the official PDF tables. Official table 1 and table 6 CSVs and PDFs dated 15 October obtained and checked. The archive HTML page could not be opened during this verification. Table notes specify reserve exclusions and the use of unrounded data for changes. Table 1 : CSV. Table 1 : PDF. Dated table 6 : CSV. Dated table 6 : PDF.

9. S09 · Joint Maritime Information Center; distributed by UKMTO · 2026-10-18 · Accessed 21 October 2026.JMIC Advisory Note : Update 106Bulletin cutoff: 18 October, 13:00 UTC; especially page 2, claims dated 17 October and transit statistics.
   Scope and access

   JMIC describes the 17 October claim of mine strikes against two supertankers as unsubstantiated. UKMTO, US NCAGS and commercial-provider counts cover different populations. Ship transits do not establish the volume of oil transported. Text of the official 11-page PDF consulted, particularly pages 1 and 2 and the 18 October 13:00 UTC cutoff. JMIC describes the 17 October claims as unsubstantiated. No oil volume is inferred from vessel counts.

10. S10 · G7 leaders; published by the Council of the European Union · 2026-10-02 · Accessed 21 October 2026.G7 Leaders’ Statement on Global Energy Security and Market StabilityParagraphs on 100 million barrels over four months, accelerated diesel releases and refinery coordination.
    Scope and access

    The statement addresses existing stock commitments totalling 100 million barrels over four months, with accelerated diesel releases. It does not identify the entire total as 100 million barrels of European diesel. Detailed allocation by product, country and delivery remains incomplete in this text. Official 2 October statement consulted. It specifies 100 million barrels in total over four months and a front-loaded diesel component in the first twenty days, without identifying the whole total as European diesel. Élysée communication of 2 October.

11. S11 · International Energy Agency · 2026-10-15 · Accessed 21 October 2026.IEA Governing Board Statement on Energy Markets and SecurityBullet points on volumes already released, remaining commitments and the priority for diesel.
    Scope and access

    Approximately 330 million barrels have been released and around 100 million remain; the total exceeds the original 400 million commitment. Acceleration includes more than 20 million barrels of diesel. “More than 20” is a lower bound. These announcements neither set a cap of 20 nor justify mechanically adding 100 or 20 to the original commitments. Official statements of 15 and 7 October consulted. The 15 October text distinguishes volumes already released, the remaining balance and plans including over 20 million barrels of diesel. Announced intentions remain distinct from completed deliveries. IEA statement of 7 October.

12. S12 · The White House · 2026-10-05 · Accessed 21 October 2026.Fact Sheet: President Donald J. Trump Promotes Diesel AffordabilityFinal fact-sheet bullet: a stated European commitment of 100 million barrels of refined diesel over four months.
    Scope and access

    Primary source for the US administration’s claim, with an explicit political interest. Its scope differs from the G7/IEA wording. No distinct, public and sufficiently detailed agreement confirming 100 million barrels of European diesel was found. Lack of confirmation does not prove that no agreement exists. Official 5 October fact sheet consulted, particularly its final bullet. The European diesel commitment is attributed to the White House and compared with the G7/IEA wording; no detailed separate agreement was obtained in this investigation.

13. S13 · U.S. Treasury, Office of Foreign Assets Control · 2026-10-09 · Accessed 21 October 2026.Russian Harmful Foreign Activities Sanctions Regulations : General License No. 135Single-page PDF: paragraph (a), authorisation and expiry; paragraph (b), exceptions.
    Scope and access

    Authorises specified transactions involving Russian-origin diesel until 12:01 a.m. EDT on 7 April 2027, subject to the stated regimes and exceptions. It concerns permitted transactions; it establishes no production or delivery volume and does not remove all Russian sanctions. Official one-page PDF read in full. Date, authorisation, expiry and paragraph (b) exception checked. The licence supplies no volume actually delivered.

14. S14 · Reuters · 2026-10-20 · Accessed 21 October 2026.US coaxing refiners to produce more diesel as prices surge, energy officials say20 October dispatch; remarks by Chris Wright and Kyle Haustveit about discussions with refiners.
    Scope and access

    The administration’s efforts are reported by Reuters and attributed to their speakers. They show attempts to secure more supply without establishing that output has already increased. Private-party estimates cited in the dispatch were not checked against proprietary datasets. Direct opening of the Reuters original failed. The reported statements were checked in indexed text and accessible reports; no direct full-text Reuters access or proprietary industrial figures are claimed.

15. S15 · U.S. Energy Information Administration; underlying data from Refinitiv, an LSEG business · 2026-10-15 · Accessed 21 October 2026.Spot Prices for Crude Oil and Petroleum Products : MonthlyMonthly series Europe Brent Spot Price FOB (RBRTE) and New York Harbor Ultra-Low Sulfur No. 2 Diesel Spot Price (EER_EPD2DXL0_PF4_Y35NY_DPG), January–September 2026.
    Scope and access

    Values are unweighted monthly averages of daily closing prices. Diesel conversion: dollars per gallon × 42. The gap subtracts separately published averages; no daily alignment is reconstructed. It compares markets with different locations and qualities and does not measure net profit. The final point is September, never a 21 October quotation. Official monthly table, both exact histories and EIA definitions consulted. All nine pairs of January–September averages were checked directly. The underlying provider is Refinitiv/LSEG; its private database was not obtained. Exact monthly history : Europe Brent. Exact monthly history : New York Harbor ULSD. Definitions, method and provider.

16. S16 · CME Group · Publication date not displayed · Accessed 21 October 2026.Trading Crack SpreadsSection 1) 1:1 Crack spread; product quotations in dollars per gallon, conversion and subtraction of the crude price.
    Scope and access

    The method supports the conversion of 42 US gallons per barrel and explains a gross gap between reference prices. CME’s example uses WTI/ULSD futures; the l0g chart uses clearly identified Brent/ULSD spot averages. CME’s illustrative values are not October 2026 prices. Official CME page consulted, particularly the 1:1 crack-spread section, units and conversion. Its WTI/ULSD futures example remains distinct from the chart’s physical Brent/ULSD averages.

17. S17 · ICE Futures Europe · Current specification : page date not stated · Accessed 21 October 2026.Brent Crude Futures : Contract SpecificationsContract Size; Daily Margin; Settlement. Contract size of 1,000 barrels and daily marking to market.
    Scope and access

    The specification supports variation payments on a futures hedge. No current initial-margin level, futures curve or actual trader contract is used. The cash-flow figure’s amounts are l0g assumptions. Current official specification consulted: contract size, daily marking to market and settlement terms. No current initial-margin level or market price is inferred from it.

18. S18 · Bank for International Settlements: Fernando Avalos and Wenqian Huang · 2022-09-19 · Accessed 21 October 2026.The financial implications of volatile commodity marketsBox A in Commodity markets: shocks and spillovers, BIS Quarterly Review, September 2022; passages on margining and hedgers’ liquidity.
    Scope and access

    Historical analysis of 2022: margin payments can create a cash need before the corresponding physical gain is received. The mechanism is transferable; 2022 events do not establish a widespread liquidity crisis in October 2026. Box A consulted and the 19 September 2022 date confirmed on the Quarterly Review edition page. Used only for the margining and liquidity mechanism, without applying historical figures to October 2026. Article and publication date.

19. S19 · Financial Stability Board · 2024-12-10 · Accessed 21 October 2026.Liquidity Preparedness for Margin and Collateral Calls: Final reportFinal report: executive summary, printed pages 1–2; preparedness and liquidity framework, pages 5–8 and 15–19.
    Scope and access

    The report supports preparation for margin calls, liquidity stress and mobilisable resources. It does not supply the l0g model parameters or identify any company currently in distress. Publication page and relevant passages in the final 10 December 2024 PDF consulted. Liquidity recommendations are distinguished from observations about participants in October 2026. Final report : PDF.

20. S20 · U.S. Energy Information Administration · Educational page : update date not established · Accessed 21 October 2026.Refining crude oil : the refining processSections Separation, Conversion, Treatment and Storage.
    Scope and access

    The description of distillation, conversion, treatment and storage supports the path from crude to products. No universal crude-to-diesel yield is assumed. Plant and crude characteristics can change the product slate. Official educational page consulted, including separation, conversion, treatment and storage. The access date is not treated as a publication date. No universal diesel conversion yield is inferred.

21. S21 · Reuters: Robert Harvey, Enes Tunagur and Ahmad Ghaddar; reproduced by EnergyNow · 2026-10-20 · Accessed 21 October 2026.Russian diesel returns to Turkey, Brazil after export ban lifted, shipping data shows20 October dispatch; Leruo departure on 16 October and Dolunay departure on 14 October, signalled destinations and Kpler/LSEG data.
    Scope and access

    The dispatch provides a counterpoint to the scarcity scenario: Russian cargoes are resuming some routes. Destinations signalled by ships do not establish completed arrivals. Data are attributed to Kpler and LSEG through Reuters; their raw datasets were not obtained. Full Reuters reproduction consulted at EnergyNow. The Reuters original could not be opened directly. Departures and signalled destinations remain attributed to Kpler/LSEG data cited by Reuters; no arrival is established. EnergyNow reproduction of 20 October.