Brent Crude Oil Price Today (USD/bbl) — Live Chart & Analysis

Live Brent Crude Oil Price Chart

The interactive chart below displays the Brent Crude Oil spot price in US dollars per barrel in real time. Brent futures trade primarily on the Intercontinental Exchange (ICE) in London, with the ICE Brent Crude Futures contract (ticker: B) serving as the global benchmark. Standard contracts cover 1,000 barrels and settle in cash against the ICE Brent Index rather than through physical delivery, which makes them highly liquid and accessible to institutional and sophisticated retail traders. CME Group’s NYMEX also lists Brent-linked contracts. Brent trades nearly 24 hours a day, five days a week, with price discovery occurring continuously across London, New York, Singapore, and Dubai sessions. Use the timeframe selectors to view price movements from intraday trading through multi-decade trends.

Brent in 2026: The Hormuz Crisis

Brent Crude entered 2026 trading in the low $70s, roughly where it had been for most of the second half of 2025. OPEC+ output discipline was fraying, US shale production continued to grow, and the IEA projected a comfortable supply surplus for the year. Goldman Sachs had forecast a 2026 average Brent price of $56 per barrel, reflecting expectations of oversupply and weakening demand from China. Every major bank’s oil outlook published in December 2025 assumed that the geopolitical risk premium was low and manageable.

That assumption lasted until February 28. When the United States and Israel launched coordinated strikes against Iran, Brent gapped higher at the Monday open on March 3 and never looked back. Within the first week, the metal had posted its biggest weekly gain since Russia’s invasion of Ukraine. Iran’s Revolutionary Guard declared the Strait of Hormuz closed to vessels linked to the US and its allies. Major insurers pulled war risk coverage for tankers transiting the strait, which effectively shut down commercial passage for any vessel without sovereign backing or a direct arrangement with Tehran.

By the second week of March, Brent closed above $100 for the first time since August 2022. The IEA responded with the largest coordinated strategic reserve release in its history, 400 million barrels from 32 member countries. The market ignored it. Brent continued to rise because the release addressed stocks, not flows. Gulf producers had lost 6.7 million barrels per day of export capacity that could not reach global markets while Hormuz remained closed. Four hundred million barrels at that rate of consumption provides roughly 60 days of coverage.

The volatility became extreme. Brent touched $120 and crashed to $86 in a single session when a false ceasefire rumour swept through the market before being denied by Tehran. The intraday range was the widest since 2008. The paper market and the physical market diverged, with spot premiums for actually delivered crude exceeding futures prices by margins not seen in decades. Refiners in Asia, who depend on Gulf supply for the majority of their crude intake, were paying whatever the market demanded for any cargo that could actually reach them.

As of late March, Brent trades around $104 per barrel. The Strait of Hormuz remains effectively closed to most commercial traffic, though Iran has converted the strait into a selective toll road, allowing passage for vessels from countries it considers neutral or friendly while charging fees of up to $2 million per transit. President Trump extended a deadline for strikes on Iranian energy infrastructure to April 6, and Iran’s parliament is reportedly preparing legislation to formalise transit fees. The US has proposed a 15-point peace plan; Iran has countered with demands that include sovereignty over the strait and war reparations. The distance between these positions is measured in years, not weeks.

For the oil market, the question is no longer whether the supply disruption will affect prices. It already has. The question is whether the market should price Hormuz as a temporary blockade with an expiry date that keeps getting extended, or as a permanent rearrangement of global shipping routes that carries a lasting cost premium. The answer to that question determines whether Brent returns to the $70s after a ceasefire or whether the $90-to-$110 range becomes the new normal.

Latest Crude Oil News & Analysis

Stay ahead of the market with our latest coverage of crude oil price movements, Hormuz shipping disruptions, OPEC+ policy decisions, IEA reserve releases, and expert energy market analysis from Finonity’s commodities desk.

How to Invest in Brent Crude Oil

Unlike precious metals, crude oil cannot be held physically by retail investors. Every access route involves financial instruments or equity stakes in oil companies, each with distinct cost structures, risk profiles, and suitability for different investment horizons. The 2026 Hormuz crisis has added a layer of complexity: oil ETFs that track front-month futures are experiencing elevated roll costs as the forward curve steepens, while oil major stocks are benefiting from high margins but facing uncertainty about the duration of the supply disruption.

Crude Oil ETFs and ETNs

Oil-linked exchange-traded funds and notes are the most accessible route for retail investors seeking direct commodity exposure. Most hold front-month or near-month futures contracts and are subject to roll costs, a structural drag that can cause performance to deviate significantly from the spot price over time. Understanding contango (when futures prices exceed spot, creating negative roll yield) and backwardation (when spot exceeds futures, creating positive roll yield) is essential before investing in these instruments. During the 2026 Iran crisis, the Brent curve has been in steep backwardation, meaning ETF holders are currently benefiting from positive roll yield as they sell expensive near-month contracts and buy cheaper deferred ones. This is the opposite of the 2020 contango environment where ETF investors suffered persistent losses from negative roll.

Brent Crude Futures

Brent Crude futures trade primarily on the Intercontinental Exchange (ICE) in London. The standard ICE Brent contract (ticker: B) covers 1,000 barrels and settles in cash against the ICE Brent Index. At current prices near $104 per barrel, a single contract controls approximately $104,000 worth of crude with initial margin requirements typically around $8,000 to $12,000 depending on exchange and broker policies. Front-month open interest typically exceeds 300,000 contracts, making ICE Brent one of the most liquid commodity futures in the world. Trading runs nearly 24 hours from Sunday evening through Friday afternoon. The cash settlement mechanism means there is no physical delivery risk, unlike WTI futures which settle at Cushing, Oklahoma. This distinction became critically important during the April 2020 WTI collapse when physical storage constraints pushed WTI futures negative while Brent, being cash-settled, maintained a floor above zero. The Brent-WTI spread (typically $2 to $5 per barrel, with Brent at a premium) is itself an actively traded instrument that reflects transatlantic supply-demand dynamics.

Oil Major Stocks

Integrated oil majors and pure-play upstream producers offer leveraged exposure to the crude oil price, supplemented by dividends, share buybacks, and operational hedging. Unlike direct commodity instruments, oil stocks carry company-specific risks including management execution, regulatory exposure, and capital allocation decisions. But they also provide advantages that commodity ETFs cannot: dividends that generate income regardless of the oil price direction, downstream refining margins that can partially offset upstream losses when crude falls, and the ability of well-managed companies to grow production volumes over time. During the 2026 Hormuz crisis, oil majors with diversified production bases outside the Gulf have outperformed those with concentrated Middle Eastern exposure. Companies with significant North Sea, Permian Basin, or deepwater Gulf of Mexico assets have benefited from both higher prices and uninterrupted production, while Gulf-dependent producers have seen volumes curtailed.

Historical Brent Crude Oil Prices

Brent Crude’s price history is a record of geopolitical shocks, demand cycles, and supply wars that have produced some of the most dramatic moves in commodity history. The modern era begins in 1983 when Brent futures were first listed on the International Petroleum Exchange (now ICE). Since then, the price has ranged from $10 per barrel during the post-Asian crisis oversupply of 1998 to $147.27 during the 2008 supercycle peak, a range of more than 14:1 that dwarfs the volatility of most other major commodities.

The price history reveals a pattern: every major spike has been driven by a supply disruption that the market believed was temporary, and every major crash has been driven by a demand collapse that the market underestimated. The 2008 supercycle peak was followed by a crash to $36 as the financial crisis destroyed demand. The 2014 cycle top at $115 gave way to the OPEC price war that sent Brent to $27 by January 2016 as Saudi Arabia flooded the market to crush US shale. The COVID pandemic triggered the sharpest demand collapse in oil history, with WTI futures briefly going negative in April 2020. Russia’s invasion of Ukraine in 2022 produced a near-record spike to $139 before markets adapted to sanctions and alternative supply routes.

The 2026 Iran war represents a different kind of supply shock. Unlike previous disruptions that affected production (Iraqi invasions, Libyan civil war, Russian sanctions), this one affects transit. The oil is still in the ground, the wells are still producing, but 20 percent of the world’s seaborne crude cannot reach its customers because the strait through which it must pass is closed. This distinction matters because it means the disruption could end overnight if the strait reopens, but it could also persist indefinitely if the geopolitical conditions prevent reopening. The market is pricing that ambiguity as a premium of roughly $30 to $40 per barrel above pre-war levels, a premium that will either collapse on a ceasefire or solidify if the conflict extends through the second quarter.

Brent Crude Price History Chart

Key Brent Crude Price Milestones

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Brent Crude Oil Key Statistics

The Strait of Hormuz handles approximately 21 million barrels per day of crude oil and condensate flow under normal conditions, representing roughly 20 percent of global seaborne oil trade. Since the strait’s effective closure in early March 2026, Gulf producers including Saudi Arabia, the UAE, Kuwait, Qatar, and Iraq have lost the ability to export the majority of their output through their primary route. Saudi Arabia and the UAE have limited alternative pipeline capacity (the East-West Pipeline and the Abu Dhabi Crude Oil Pipeline to Fujairah, respectively), but these alternatives can handle only a fraction of total Gulf output. The IEA’s 400 million barrel release was designed to bridge a temporary disruption, but at the rate of 6.7 million barrels per day of lost Gulf exports, those reserves cover approximately 60 days. The market has priced this arithmetic accordingly.

What Drives the Brent Crude Oil Price?

Crude oil is one of the most complex and politically sensitive commodities in the world. Its price reflects the interplay of global macroeconomics, geopolitics, industrial demand cycles, and the supply decisions of sovereign producers. The drivers below are the primary factors analysts and traders monitor, updated to reflect the 2026 Hormuz crisis.

• OPEC+ production decisions — The OPEC+ alliance controls approximately 40 percent of global supply. Coordinated output cuts or increases are the single most powerful lever affecting Brent prices under normal conditions. However, the 2026 crisis has rendered OPEC+ production quotas largely irrelevant because member states physically cannot export their oil while Hormuz is closed. Saudi Arabia, the alliance’s swing producer with roughly 2 million barrels per day of spare capacity, cannot deploy that capacity if the crude has no route to market. This is a structural change from every previous OPEC+ episode where the constraint was willingness to produce, not ability to ship.
• Strait of Hormuz and geopolitical risk — Roughly 20 percent of global oil supply passes through the Strait of Hormuz, a 33-kilometre-wide channel between Iran and Oman. The strait’s closure is now the dominant driver of Brent pricing, overriding all other factors. Iran has converted the strait into a selective access route, allowing passage for vessels from neutral or friendly countries while charging transit fees and blocking allied shipping. The war risk premium embedded in Brent is estimated at $30 to $40 per barrel above the pre-war price level of roughly $70.
• Global economic growth and China demand — China accounts for roughly 15 percent of global oil consumption. Any significant slowdown in Chinese industrial output, construction, or vehicle sales directly reduces crude demand. The 2026 war has complicated this picture: higher oil prices are inflationary and dampen demand, but China has been among the countries granted passage through Hormuz for some of its vessels, giving it preferential access to Gulf crude at a time when competitors are shut out.
• US shale production — The United States produces approximately 13 million barrels per day, primarily from the Permian Basin. Rising US output structurally constrains OPEC+’s pricing power by competing for global market share. During the Hormuz crisis, US production has become even more strategically important because it is one of the few major supply sources unaffected by the transit disruption. However, US producers cannot increase output fast enough to offset the loss of 6.7 million barrels per day of Gulf exports.
• Strategic Petroleum Reserve releases — The IEA coordinated a 400 million barrel release from 32 member countries in March 2026, the largest in the agency’s history. The release was designed to stabilise prices, but it failed to prevent Brent from breaking $100 because the market recognised that reserves are a finite buffer, not a substitute for continuous supply. The IEA has confirmed that 80 percent of member stockpiles remain available, but each additional release depletes the buffer further and raises questions about what happens when reserves run out.
• EIA weekly inventory reports — The US Energy Information Administration publishes weekly crude oil inventory data every Wednesday at 10:30 AM Eastern. Builds in US crude stocks typically pressure prices lower; draws support prices. During the Hormuz crisis, US inventories have drawn sharply as domestic crude replaces lost Gulf imports, and each weekly draw reinforces the market’s assessment of supply tightness.
• US dollar strength — Brent is priced in US dollars globally. A stronger dollar makes oil more expensive in other currencies, dampening international demand. The DXY dollar index has risen above 100 during the crisis on safe-haven flows, which partially offsets the supply disruption premium by reducing non-US purchasing power.
• Energy transition and EV adoption — The long-term outlook for oil demand is increasingly shaped by electric vehicle adoption, particularly in China and Europe. The IEA projects global oil demand will peak sometime in the mid-2020s. However, the 2026 war has temporarily silenced the peak demand narrative: when 20 percent of seaborne oil stops flowing, the conversation shifts from “when will demand peak” to “where will supply come from tomorrow.”
• Insurance and shipping costs — War risk insurance premiums for tankers transiting the Gulf have risen to levels that effectively prohibit commercial passage without sovereign backing. This adds a cost layer to every barrel that does manage to reach market, pushing the delivered price of crude above the benchmark futures price. The gap between paper market prices and physical delivered prices is now wider than at any point since the 2008 financial crisis.
• North Sea production and the BFOET basket — Since the original Brent field is in decline, the Brent price benchmark tracks a basket of five North Sea crude streams: Brent, Forties, Oseberg, Ekofisk, and Troll (BFOET). Changes in the quality and volume of these fields affect the benchmark’s composition. The North Sea production base is unaffected by the Hormuz closure, which means the benchmark crude itself continues to flow normally even as the majority of Middle Eastern crude it prices does not.

Brent Crude vs WTI Crude — Key Differences

Brent Crude and WTI (West Texas Intermediate) are the two dominant global oil benchmarks. While closely correlated under normal conditions, the 2026 Hormuz crisis has widened the spread between them as Brent has absorbed the full geopolitical premium while WTI, reflecting US domestic supply that is insulated from the strait closure, has risen less sharply. The spread, which typically fluctuates between $2 and $5 per barrel, has at times exceeded $10 during the crisis as international buyers competing for non-Gulf crude bid up Brent-linked cargoes.

The Brent-WTI spread is itself an actively traded instrument on both ICE and NYMEX. When US shale production surges and Cushing inventories build, WTI can discount heavily to Brent. When Middle Eastern supply is disrupted, as it is now, Brent spikes relative to WTI because Brent is the benchmark that directly prices the affected cargoes. Traders who want to express a view on the duration of the Hormuz closure without taking a directional bet on the absolute oil price can trade the spread directly.

Understanding the Oil Market Structure

Contango vs Backwardation

The shape of the crude oil futures curve provides crucial information about the current supply-demand balance. During the 2026 Hormuz crisis, the Brent curve has been in steep backwardation, with prompt-month contracts trading at a significant premium to deferred months. This is the market’s way of saying that oil is needed now, not later, and that buyers are willing to pay a premium for immediate delivery. For ETF investors, backwardation creates a positive roll yield that partially offsets the fund’s expense ratio. For physical traders, it signals urgency and tightness in the delivered market.

Frequently Asked Questions