WTI vs Brent Spread Explained

"Oil" does not have a single price. Two numbers move together most days - West Texas Intermediate (WTI) and Brent - and the gap between them, the Brent-minus-WTI spread, is one of the most-watched signals in energy markets. Per PetroEyes market data (last updated Nov 13, 2026), front-month Brent futures closed at $95.59 per barrel and WTI at $88.31 on November 13, 2026, leaving a spread of $7.28 - a wide reading, about 1.6 times the stored average. Earlier in the series the same spread printed $4.56 on September 21, $11.91 on September 25 and $12.68 on September 28, and it was $63.20 on April 20, 2020. That range, from a normal reading to a wide-tail reading in a few trading days and back again, is exactly why this guide exists. It explains what the spread actually measures, the freight-and-quality arithmetic that sets it, what wide or inverted spreads signal, and how to read the spread each day.

1. What the spread is

The Brent–WTI spread is simply the Brent crude price minus the WTI crude price, quoted in dollars per barrel. When commentators say "the spread is eleven dollars," they mean Brent trades $11 above WTI. It is not a separate traded commodity so much as a derived number - but futures contracts and physical trades reference it constantly, because it summarizes, in one figure, the relative balance of the Atlantic Basin market against the US inland market.

Two conventions matter. First, the sign: a positive spread means Brent is above WTI, which is the normal state. A negative spread - sometimes called an inverted or backward spread - means WTI trades above Brent, and it is rare enough that each occurrence gets its own explanation. Second, the contract: spreads are usually quoted on the front-month futures (the nearest delivery month), which is the most liquid contract and the one PetroEyes tracks on its WTI price page.

Think of the spread as the price of moving oil from where it is cheap to where it is dear. If moving a barrel from the US Gulf Coast to Northwest Europe costs a certain amount in freight, insurance, and time, then Brent should exceed WTI by roughly that cost whenever the physical market is functioning. Persistent deviations from that anchor tell you something specific is happening - a pipeline constraint, a refinery outage, a quality mismatch, or a regional supply shock. The rest of this guide builds the machinery to tell those stories apart.

2. What WTI actually measures

WTI is the US light sweet crude benchmark, priced for delivery at Cushing, Oklahoma - a landlocked pipeline hub where several major pipelines meet and where the NYMEX futures contract physically settles. Two features of that geography shape everything about WTI pricing.

First, WTI is priced inland. A barrel of WTI at Cushing still has to travel hundreds of miles to reach a coast, a refinery, or an export terminal. That journey costs money, and the cost shows up as a discount relative to waterborne crude. When pipelines from Cushing to the Gulf Coast run full, barrels get stuck, storage fills, and the discount widens - this is the inland logistics penalty in action.

Second, WTI reflects US supply and demand first. Surging Permian production, refinery maintenance season on the Gulf Coast, and weekly inventory builds or draws in PADD 3 all press on WTI more directly than on Brent. ThePermian rig count and WTI spread guide on this site walks through the related Midland–Cushing differential - the discount Permian producers accept relative to the Cushing price - which is a smaller, regional cousin of the Brent–WTI spread covered here.

One more detail: the "WTI" quoted in headlines is the front-month NYMEX futures price, which tracks the physical market at Cushing closely but not perfectly. Futures prices include expectations, storage costs, and financing; the physical differential (Midland vs. Cushing, for example) is where logistics shows up most cleanly.

3. What Brent actually measures

Brent is the benchmark for crude produced in the North Sea and, by extension, for most waterborne crude traded internationally. Unlike WTI, Brent is priced at the water - cargoes loading at North Sea terminals - so it is immediately exportable and immediately comparable to crudes from West Africa, the Mediterranean, and the Middle East delivered into Europe.

Because it sits at the crossroads of seaborne trade, Brent absorbs global signals first: OPEC+ production decisions, shipping disruptions through the chokepoints, European and Asian refinery demand, and geopolitical risk premiums. When a supply disruption hits a waterborne market, Brent typically moves before WTI, because the disrupted barrels were priced off Brent and the replacement barrels must be shipped - a process that takes weeks, during which the spread does the adjusting.

Quality plays a smaller role than many summaries suggest, but it is real. Brent blend is a light sweet crude, and WTI is lighter and sweeter still. All else equal, lighter, sweeter barrels yield more high-value products (gasoline, diesel, jet fuel) per barrel in a typical refinery, so they command a small quality premium. Quality alone cannot explain an $11 spread - that is freight, logistics, and regional balances - but it sets the baseline the other components stack onto.

4. The differential arithmetic: five components

The spread can be decomposed into five additive pieces. This is an accounting framework, not a forecasting model - it tells you where to look when the spread moves, which is the useful half of the job.

Brent − WTI ≈ freight & insurance + quality differential + inland logistics + regional balance + timing

• Freight and insurance. The cost of moving crude from the US Gulf Coast to Northwest Europe on a tanker, plus marine insurance. This is the structural core of the spread: as long as the marginal Atlantic Basin barrel is supplied from the US, Brent should exceed WTI by roughly the voyage cost. When tanker rates spike, the spread widens mechanically.
• Quality differential. The small, usually stable premium or discount for differences in API gravity and sulfur content between the benchmark blends. This moves slowly and rarely drives day-to-day spread changes.
• Inland logistics. The cost and congestion of getting barrels from Cushing to the water. Full pipelines, full storage at Cushing, or refinery outages that strand crude inland all push WTI down relative to Brent, widening the spread. This is the component most sensitive to US-specific events.
• Regional supply–demand balance. If the Atlantic Basin is short of crude (strong European/Asian refinery demand, OPEC+ restraint) while the US is well supplied (strong shale output), Brent outruns WTI and the spread widens. If the US is tight and the Atlantic Basin is long, it narrows.
• Timing and contract effects. Front-month futures for the two benchmarks roll on different calendars, and physical cargoes price over different loading windows. Around contract expiry, the spread can move for plumbing reasons that have nothing to do with physical balances. Treat single-day spikes near expiry with suspicion.

In equilibrium, arbitrage holds the spread near the cost of moving oil between the two pricing points: if Brent rose far above WTI plus transport costs, traders would buy US crude, ship it east, and sell it against Brent until the gap closed. The spread persists because shipping takes weeks, cargoes are lumpy, and pipeline and terminal capacity is finite - the gap is the market's payment for those frictions.

5. Worked example: reading a real $11.91 spread

On September 25, 2026, PetroEyes' front-month futures closes (not the EIA weekly spot series shown on the Brent and WTI price pages) were Brent at $104.32 and WTI at $92.41 per barrel - a spread of $11.91, up from $4.56 just four sessions earlier on September 21. On September 28 the futures spread was $12.68. This is a past reading chosen because it was wide; the latest reading, $7.28 on November 13, 2026, is in the first paragraph. The arithmetic below decomposes the wide $11.91 reading. The market prices are real (PetroEyes data); the component splits are illustrative allocations showing how the framework from section 4 is applied - not quoted market figures.

Use this table this way: it is a hypothesis generator, not a measurement. Each row names the evidence that would confirm or kill it. If the Midland–Cushing differential (covered in our Permian spread guide) did not widen that week, the inland-logistics row is probably wrong and the regional-balance row is probably bigger. The discipline is to check the components against independent data - weekly inventory reports on our EIA inventory page, rig counts on the rig counts page, and trade-route conditions in global oil trade routes - rather than narrating the spread after the fact.

Note the speed of both moves: $4.56 on September 21 to $11.91 on September 25, then $12.68 on September 28. Spreads can reprice faster than flat prices because both legs move and the legs can move in opposite directions - Brent catching a bid on Atlantic tightness while WTI sags on a Cushing-area build. When you see the spread move more than flat prices, look for a regional story, not a global one.

6. The spread driver framework

This is the reference table for diagnosing any spread move. Each driver lists the direction of its effect and the independent data that would confirm it - the habit that separates analysis from storytelling.

Two rows deserve emphasis because they are the most common real causes of large moves. US pipeline takeaway constraints are the classic WTI-side driver: when Permian production growth outruns pipe capacity, Midland crude discounts steeply, Cushing gets congested, and WTI sags relative to Brent. OPEC+ restraint is the classic Brent-side driver: when the producer group holds barrels off the market, the barrels withheld are disproportionately the waterborne grades that price off Brent, so Brent outruns WTI. Large spreads usually have one foot on each side.

7. What the history actually shows

PetroEyes tracks the Brent–WTI spread as a calculated series going back to January 2016 - 954 stored observations through November 13, 2026. The stored series has 954 observations: 445 weekly closes from January 7, 2016 and 509 daily closes from November 12, 2024 to November 13, 2026. It does not hold every trading day before November 12, 2024. The summary statistics below are computed directly from that series, so "average" and "median" mean the average and median of the stored observations, not of every trading day. They are useful because they replace vibes ("the spread feels wide") with a distribution.

Scope of the extremes. The maximum and minimum above are the extremes of the stored series, which is 954 observations and not every trading day. The series does not contain April 20, 2020, when the site's contango guide records the May WTI contract settling at −$37.63 (Reuters, April 20, 2020). On the same day the June Brent contract settled at $25.57, so the Brent-minus-WTI gap, comparing the two contracts quoted there (June Brent and the expiring May WTI, which fall in different delivery months), was roughly $63.20. That is arithmetic on two quoted settlements, not a stored observation, but it shows that the widest the spread has ever been was far above the $63.20 stored maximum, and that day belongs to the negative-price episode rather than to the freight-and-balance regime this guide describes.

Three things stand out. First, the spread is mean-reverting around freight economics: the median of $3.89 is roughly what it costs, most of the time, to move oil between the two pricing points plus a small quality and balance premium. Second, the extremes came in different years: the $63.20 maximum on April 20, 2020 and the −$3.68 minimum on April 7, 2026. Third, the September 25 reading of $11.91sat far above the median, in territory where the spread is doing real economic work, and it was $12.68 on September 28; the latest reading is $7.28 (wide). Whether a wide reading like that is a new regime or a regional dislocation that arbitrage and rebalancing will pull back is not something the spread alone can say; the components in section 4 are the way to tell.

8. What a wide spread signals

A wide spread - roughly speaking, anything persistently above $7–8, well clear of the $3.89 median - is the market saying that oil is worth materially more at the water than inland. Work through the three candidate stories in order:

1. US-side weakness first. Check whether WTI is falling on its own: Cushing inventories building in the weekly EIA data, the Midland–Cushing differential widening, or Gulf Coast refinery runs dropping. If the weakness is concentrated in WTI, the story is American abundance or American logistics - shale output outrunning pipes, or refineries not taking barrels.
2. Atlantic-side strength second. Check whether Brent is rising on its own: OPEC+ holding barrels back, European refinery demand strong, or shipping disruptions lifting delivered costs into Europe. If the strength is concentrated in Brent, the story is waterborne tightness.
3. Both, third. The largest spreads usually combine the two - for example, US production growing into full pipelines at the same time OPEC+ restrains output. Additive stories produce the extremes, like the $63.20 print on April 20, 2020.

For US producers, a wide spread is a mixed blessing: it signals strong global demand for the barrels they can get to water, but the barrels they cannot get to water are being discounted. For refiners, it shifts the calculus of which crudes to buy. For everyone else, it is a reminder that "the oil price" is a local phenomenon - the $11.91 gap on September 25 meant a European refiner and a Midcontinent producer were living in very different markets that day.

9. What a narrow or inverted spread signals

A narrow spread - under about $2, or near zero - says the inland and waterborne markets are nearly in balance after transport. It often appears when US logistics are running smoothly (new pipeline capacity in service, Cushing stocks low) or when the Atlantic Basin is soft (weak refinery demand, ample waterborne supply). Narrow spreads are the market's "all clear" on regional dislocation.

Inversion - WTI above Brent - is the rare event, occurring in 0.9% of the stored observations in the PetroEyes series (9 of 954). It requires something unusual: severe Atlantic Basin oversupply, extreme US tightness (Cushing stocks near tank bottoms, where operational minimums constrain outflows), or a dislocation in one benchmark's contract mechanics. The −$3.68 reading on April 7, 2026, and the other 8 negative observations (Apr 9, 2026, Apr 7, 2026, Apr 6, 2026, Apr 2, 2026, May 18, 2022, May 24, 2016, Jan 22, 2016, Jan 14, 2016), show how quickly regional balances can flip: the same spread that hit its stored-series high of $63.20 on April 20, 2020 printed its stored-series low 2178 days later. Anyone using the spread as a trading signal should internalize that whiplash before anything else.

One caution on interpreting extremes: a spread can also move because one benchmark's futures contract is misbehaving around expiry rather than because physical barrels repriced. Before treating any single-day extreme as a physical signal, check whether the move is in the front month only and whether it reverses after the roll. The driver table in section 6 lists this as the first thing to rule out, and it belongs there because expiry noise has embarrassed more than one spread narrative.

10. Five common misreads

Misread 1: "A widening spread means oil prices are going up." No. The spread is a relative price. It can widen because Brent rises, because WTI falls, or both. A widening spread on falling WTI is a story about US weakness, not global strength - and it can coincide with flat or falling headline crude prices.

Misread 2: "Brent is higher because it is better oil." Quality differences between the benchmark blends are small and stable. They explain a fraction of a dollar of the spread, not eleven. When the spread moves by dollars in a week, the cause is freight, logistics, or regional balances - never quality.

Misread 3: "The spread predicts where flat prices go next." The spread is better at describing the present than predicting the future. It tells you where barrels are stranded and where they are wanted right now. It does not tell you whether global demand will grow next quarter. Treat it as a diagnostic, not a forecast.

Misread 4: "Gasoline prices follow one benchmark." US gasoline prices track WTI more closely; European fuel prices track Brent. Neither follows either benchmark mechanically, because refining margins, taxes, and distribution costs sit between crude and the pump. A $12 spread does not mean European drivers pay $12 more per barrel-equivalent than American drivers - the product markets have their own logistics.

Misread 5: "Arbitrage will close any wide spread immediately."Arbitrage closes spreads only as fast as physical capacity allows. Chartering a tanker, loading at the Gulf Coast, sailing to Rotterdam, and discharging takes weeks; pipeline space is contracted months ahead. The spread is the price of that friction, and it can stay wide for as long as the friction binds.

11. How to read the spread: a daily checklist

When the spread moves, run this checklist before forming a view. It takes five minutes with the data pages on this site.

1. Get the number right. Brent minus WTI, front-month futures, same timestamp. PetroEyes publishes both benchmarks and the calculated spread on the WTI price page - start there, not from a headline.
2. Size it against history. Is today above or below the $3.89 median and $4.52 average? A $5 spread is a normal day; a spread like the $11.91 of September 25 is a wide-tail event that demands a physical explanation.
3. Split the legs. Did Brent move, did WTI move, or both? Check the individual benchmark charts. A one-legged move points to a regional story; a two-legged move points to something bigger.
4. Check the inland differential. If the Midland–Cushing spread (see the Permian spread guide) moved the same way, the driver is US logistics. If it did not, look east.
5. Check the weekly physicals. The EIA inventory data shows whether Cushing and total US crude stocks are building or drawing - the physical confirmation of any WTI-side story.
6. Rule out expiry noise. If the move is concentrated in the front month within a few days of expiry and the deferred spread is unchanged, wait for the roll before concluding anything.
7. Name the friction. Every persistent spread has a physical reason it is not arbitraged away: full pipes, full ships, full tanks, or sanctioned barrels. If you cannot name the friction, you do not understand the spread yet.

12. Frequently asked questions

Why is Brent usually higher than WTI?

Because Brent is priced at the water and WTI is priced inland at Cushing, Oklahoma. Moving a barrel from the US interior to a European refinery costs real money in pipeline tariffs, tanker freight, and insurance, so Brent carries roughly that transport cost as a structural premium. The average spread of $4.52 in the PetroEyes series is mostly that freight economics plus a small quality and balance premium - not a judgment about which oil is "better."

Can the Brent–WTI spread go negative?

Yes, but rarely. In the PetroEyes series back to 2016, the spread was negative in only 9 of 954 stored observations (0.9%), most recently on April 10, 2026, with the lowest reading at −$3.68 on April 7, 2026. That series is weekly before November 12, 2024, so it undercounts brief inversions. Inversion requires unusual conditions: severe Atlantic Basin oversupply, extreme tightness at Cushing, or contract-mechanics dislocation. It is the exception that confirms how strongly freight economics normally anchor the spread positive.

Does a wide spread mean crude prices will rise?

Not by itself. The spread measures the relative balance between two regional markets, not the absolute level of oil prices. It can widen while both benchmarks fall (if WTI falls faster) or while both rise (if Brent rises faster). Use the spread to diagnose where barrels are stranded or wanted; use flat-price drivers - global demand, OPEC+ policy, inventories - to think about price direction.

How does OPEC+ policy affect the spread?

OPEC+ production decisions land disproportionately on Brent, because the withheld barrels are mostly waterborne grades that price off Brent in the Atlantic Basin. When the group restrains output, Atlantic Basin crude tightens relative to the US inland market and the spread tends to widen.

Which benchmark should I watch as a US driver or investor?

For US gasoline prices and US-focused energy equities, WTI is the more relevant benchmark - it prices the barrels actually produced and refined domestically. For international exposure, shipping, or European refining, Brent matters more. Many US producers hedge with WTI-based instruments while selling into export markets priced off Brent, which makes the spread itself a direct input to their realized economics. This is educational context, not investment advice - see the disclaimer below.

Where can I see the current spread?

PetroEyes tracks WTI, Brent, and the calculated Brent–WTI spread on the WTI and Brent price pages, updated with each data refresh. The most recent reading in the PetroEyes series is $7.28 on November 13, 2026(front-month futures closes), shown in the first paragraph of this guide. The series history behind the statistics in section 7 is computed from the same data feed.

13. Related reading

• Oil Price History, Adjusted for Inflation - WTI, Brent and first purchase prices in September 2026 dollars, and days above $100.
• US Crude Oil Exports, Explained - how the spread pulls US barrels to Gulf Coast docks and on to Europe and Asia.
• Permian Rig Count vs. WTI Spread Analysis - the regional Midland–Cushing differential, the smaller inland cousin of the Brent–WTI spread.
• WTI Crude Oil Price Today - live benchmark quotes and the calculated spread series.
• EIA Crude Oil Inventory & Weekly Petroleum Status Report - the weekly physical data that confirms or kills any WTI-side spread story.
• Alberta Oil Production, the Emissions Cap, and Pipeline Limits - another case study in how pipeline constraints create regional price differentials.