The Spot Price Was Not the Price Your Contract Used.
Quote from chief_editor on June 12, 2026, 5:30 pmPhysical commodity contracts reference specific published indices, not the generic 'spot price.' The index and the spot price can diverge significantly, especially for niche grades.
When a buyer says they purchased crude oil "at spot," they mean the price was set based on the current market price for crude oil. What they mean by "current market price" turns out to be a reference to a specific price assessment for a specific grade at a specific delivery point — the Platts Dated Brent, the Argus WTI Cushing, or another specific published assessment.
The difference between "spot" as a concept — the market price today — and a specific published index — a price assessed by a specific price reporting agency for a specific product specification at a specific location — can be material for grades or locations that are not the primary benchmark.
A buyer contracting for Angolan Cabinda crude against a Dated Brent reference is paying Brent plus or minus the Cabinda differential — the market's assessment of how Cabinda crude trades relative to Brent. That differential reflects quality differences, freight positioning, and market supply and demand for West African crude specifically. When they later describe the trade as having been done "at Brent," they are omitting the differential that determined their actual cost. If the Cabinda differential moved from Brent plus $2 to Brent minus $3 during the pricing period, the contract price changed by $5 per barrel — around $350,000 on a 70,000-barrel cargo — independent of any movement in Brent itself.
The Benchmark Is Not the Price. The Differential Is the Risk.
In physical crude oil and refined product trading, prices are expressed as benchmark plus or minus differential. The benchmark — Dated Brent, WTI, Dubai/Oman, ESPO — provides the directional reference. The differential reflects everything about the specific grade, location, and timing that is not captured by the benchmark.
Traders who hedge their price risk by trading benchmark derivatives — Brent futures, WTI futures — are hedging the benchmark component of their price. They are not hedging the differential. A trader who is long Cabinda crude and has sold Brent futures is hedged against Brent price direction risk. They are exposed to Cabinda-Brent differential risk — which is the risk that the specific market for West African crude moves differently from the global benchmark.
In a normal market, grade differentials are relatively stable — the quality and supply characteristics of each crude do not change rapidly, so their relative values tend to be mean-reverting around long-term averages. But during market disruptions — sanctions on specific origins, regional refinery capacity changes, seasonal demand shifts — grade differentials can move dramatically. During periods when European refineries have reduced their appetite for specific grades due to regulatory or commercial reasons, the differential for those grades can fall sharply even if the Brent benchmark is stable.
Industry estimates for differential volatility in global crude oil markets suggest that major crude grade differentials — Brent/WTI spread, Dubai/Brent spread, and major export blend differentials — have historically shown annual volatility of $3 to $10 per barrel for each major differential. For a trader holding significant physical position in a specific grade, unhedged differential exposure of this magnitude on a large volume book is material.
The Price Assessment That Governs Your Contract Is Specific
Physical commodity contracts reference specific price assessors — Platts, Argus, ICIS — and specific assessment times and methodologies. Platts Dated Brent is assessed daily by S&P Global Commodity Insights based on specific criteria for physical cargo trades. The assessment is constructed from reported and assessed cargo transactions meeting specified criteria, using a methodology that is published but that market participants do not always read in detail.
When the physical market for the relevant benchmark crude is thin — few qualifying transactions occurring in the assessment window — the assessed price is more influenced by assessed, non-reported prices and by the methodology's rules for handling sparse data. In these periods, the assessed price may reflect the assessor's methodology rather than a direct market clearing price, creating uncertainty about whether the assessed price represents the actual market.
For physical commodity contracts where the governing price is a specific published assessment, understanding how that assessment is constructed — what transactions count, how assessed prices are determined when transactions are sparse, and what the market's criticism of specific methodology elements is — is part of understanding the price risk in the contract.
Physical commodity contracts reference specific published indices, not the generic 'spot price.' The index and the spot price can diverge significantly, especially for niche grades.
When a buyer says they purchased crude oil "at spot," they mean the price was set based on the current market price for crude oil. What they mean by "current market price" turns out to be a reference to a specific price assessment for a specific grade at a specific delivery point — the Platts Dated Brent, the Argus WTI Cushing, or another specific published assessment.
The difference between "spot" as a concept — the market price today — and a specific published index — a price assessed by a specific price reporting agency for a specific product specification at a specific location — can be material for grades or locations that are not the primary benchmark.
A buyer contracting for Angolan Cabinda crude against a Dated Brent reference is paying Brent plus or minus the Cabinda differential — the market's assessment of how Cabinda crude trades relative to Brent. That differential reflects quality differences, freight positioning, and market supply and demand for West African crude specifically. When they later describe the trade as having been done "at Brent," they are omitting the differential that determined their actual cost. If the Cabinda differential moved from Brent plus $2 to Brent minus $3 during the pricing period, the contract price changed by $5 per barrel — around $350,000 on a 70,000-barrel cargo — independent of any movement in Brent itself.
The Benchmark Is Not the Price. The Differential Is the Risk.
In physical crude oil and refined product trading, prices are expressed as benchmark plus or minus differential. The benchmark — Dated Brent, WTI, Dubai/Oman, ESPO — provides the directional reference. The differential reflects everything about the specific grade, location, and timing that is not captured by the benchmark.
Traders who hedge their price risk by trading benchmark derivatives — Brent futures, WTI futures — are hedging the benchmark component of their price. They are not hedging the differential. A trader who is long Cabinda crude and has sold Brent futures is hedged against Brent price direction risk. They are exposed to Cabinda-Brent differential risk — which is the risk that the specific market for West African crude moves differently from the global benchmark.
In a normal market, grade differentials are relatively stable — the quality and supply characteristics of each crude do not change rapidly, so their relative values tend to be mean-reverting around long-term averages. But during market disruptions — sanctions on specific origins, regional refinery capacity changes, seasonal demand shifts — grade differentials can move dramatically. During periods when European refineries have reduced their appetite for specific grades due to regulatory or commercial reasons, the differential for those grades can fall sharply even if the Brent benchmark is stable.
Industry estimates for differential volatility in global crude oil markets suggest that major crude grade differentials — Brent/WTI spread, Dubai/Brent spread, and major export blend differentials — have historically shown annual volatility of $3 to $10 per barrel for each major differential. For a trader holding significant physical position in a specific grade, unhedged differential exposure of this magnitude on a large volume book is material.
The Price Assessment That Governs Your Contract Is Specific
Physical commodity contracts reference specific price assessors — Platts, Argus, ICIS — and specific assessment times and methodologies. Platts Dated Brent is assessed daily by S&P Global Commodity Insights based on specific criteria for physical cargo trades. The assessment is constructed from reported and assessed cargo transactions meeting specified criteria, using a methodology that is published but that market participants do not always read in detail.
When the physical market for the relevant benchmark crude is thin — few qualifying transactions occurring in the assessment window — the assessed price is more influenced by assessed, non-reported prices and by the methodology's rules for handling sparse data. In these periods, the assessed price may reflect the assessor's methodology rather than a direct market clearing price, creating uncertainty about whether the assessed price represents the actual market.
For physical commodity contracts where the governing price is a specific published assessment, understanding how that assessment is constructed — what transactions count, how assessed prices are determined when transactions are sparse, and what the market's criticism of specific methodology elements is — is part of understanding the price risk in the contract.