Not all crude oil is the same. The crude you see priced on financial news — typically Brent or WTI — represents just two of approximately 160 distinct crude oil grades traded globally. Each grade has specific characteristics of density, sulfur content, and other chemical composition that determine which refineries can process it efficiently, what products it yields, and therefore what price it commands.

For any investor, trader, or observer of oil markets, understanding crude grade differences is essential to interpreting price movements, refining economics, and producer-country dynamics. This article provides the complete guide to the major global crude grades in April 2026: their specifications, their pricing, their regional roles, and why the differences matter.

The Two Key Specifications: API Gravity and Sulfur Content

Every crude oil grade is characterised primarily by two measurements: API gravity (how dense the oil is) and sulfur content (how chemically complex refining will be). These two dimensions create a matrix that places every crude somewhere between “light sweet” and “heavy sour.”

API gravity. American Petroleum Institute gravity is an inverted measurement — higher numbers mean lighter oil. The scale is calibrated so that water has API of 10; crude oils lighter than water have API above 10. Light crudes (API 31+) flow easily at ambient temperature, are easier to transport through pipelines, and yield more light petroleum products (gasoline, jet fuel, diesel) when refined. Heavy crudes (API below 22) are viscous at room temperature, often require heating in pipelines, and yield more residual fuel oil, coke, and bitumen.

Sulfur content. Sulfur is the single most important impurity to remove during refining. Higher sulfur crude requires more complex refining processes and more sulfur-removal equipment. Crudes with less than 0.5% sulfur are classified as “sweet.” Crudes with more than 0.5% sulfur are “sour.” The threshold is important because refineries designed for sweet crude cannot efficiently process sour crude without modifications. Environmental regulations on finished fuels (particularly on ultra-low-sulfur diesel) have made sweet crude increasingly valuable relative to sour over the past two decades.

The combination produces four general categories:

Brent: The Global Benchmark

Brent crude is the most important global oil price benchmark. Named for the North Sea Brent oilfield, the current Brent benchmark is actually a blend of crudes from five North Sea fields: Brent, Forties, Oseberg, Ekofisk, and Troll (collectively “BFOET”). The diversified sourcing provides more stable supply than any single field would offer.

Specifications: API gravity approximately 38 degrees, sulfur content approximately 0.37%. Classification: light sweet. The balance of density and low sulfur makes Brent ideal for producing transportation fuels — gasoline, diesel, jet fuel — that command premium prices in global markets.

Production: Current North Sea production of Brent-type crudes runs approximately 900,000 barrels per day from the five combined fields. Production has been declining since its 1999 peak near 3 million barrels per day. Despite declining production, Brent’s role as global benchmark has grown as it represents light sweet crude delivered to major consuming markets.

Pricing role: Approximately two-thirds of global internationally-traded crude is priced relative to Brent. This includes oil from West Africa, the North Sea, Russia (as Urals differential), parts of the Americas, and many other sources. Specific long-term contracts between producers and buyers use Brent as the pricing reference with specific differentials for grade quality and delivery logistics.

Futures trading: Brent crude futures trade on Intercontinental Exchange (ICE) and represent one of the most liquid energy derivatives globally. Average daily volume exceeds 1 million contracts (1 million barrels per contract equals 1 billion barrels daily notional). The prompt-month contract typically has the highest volume.

WTI: The American Benchmark

West Texas Intermediate (WTI) is the primary American crude oil benchmark. WTI originates from the Permian Basin, Eagle Ford Shale, and other US oil-producing regions. The benchmark grade delivered at Cushing, Oklahoma, reflects blended specifications from multiple source fields.

Specifications: API gravity approximately 40 degrees, sulfur content approximately 0.42%. Like Brent, classified as light sweet. Slightly lighter than Brent (higher API), which makes WTI even more favoured for gasoline production.

Production: US crude production has grown dramatically since the 2008-2010 shale revolution. Currently US production runs approximately 13.3-13.6 million barrels per day, making the US the world’s largest oil producer. Much of this production is WTI-grade or similar. Our oil price history discusses the trajectory of US production growth.

Pricing role: WTI prices crude produced in North America and substantially influences prices for exports from the US to international markets. Since the 2015 lifting of US crude export restrictions, WTI-priced crude now reaches global markets in meaningful volume.

WTI-Brent spread: The differential between WTI and Brent has averaged approximately -$3.50 per barrel (WTI below Brent) over the past five years. The spread widens (WTI trades further below Brent) when US production growth creates local oversupply. The spread narrows when US demand exceeds supply or when pipelines to coastal export terminals are constrained. Current spread around -$3.50 is typical.

Futures trading: WTI crude futures trade on NYMEX (now part of CME Group). WTI and Brent together account for approximately 80 percent of global crude oil derivatives trading.

Dubai and Oman: The Middle Eastern Benchmark

Dubai crude and Oman crude (combined in the Dubai DME Oman benchmark) are the primary Middle Eastern crude oil benchmarks. These grades are critical for pricing Middle Eastern crude exports to Asian markets, which represent the majority of Middle Eastern oil flows.

Specifications: Dubai API approximately 31 degrees, sulfur content approximately 2.0%. Oman API approximately 36 degrees, sulfur content approximately 1.1%. The DME combined benchmark represents a practical Middle East crude benchmark. Both are classified as sour (high sulfur) with moderate density.

Production: Dubai crude production is modest (under 50,000 barrels per day currently) but its benchmark role far exceeds its physical volume. Oman produces approximately 800,000 barrels per day, most of which is exported. Other grades priced relative to Dubai include Iranian Light, Iraqi Basrah, Kuwaiti KEC, UAE Murban, and specific Saudi grades.

Pricing role: Middle Eastern crudes bound for Asia are typically priced as Dubai benchmark plus/minus specific differentials for each grade and destination. This pricing system makes the Dubai benchmark critical for over 20 million barrels per day of oil flows to Asian markets.

Dubai Mercantile Exchange: DME Oman futures provide a specific Middle East crude benchmark with financial settlement. DME Oman has become increasingly liquid over the past decade as Middle East pricing has gained prominence. Volume remains below Brent and WTI but is growing.

Arab Light: The Saudi Standard

Arab Light is the largest single grade of Saudi Arabian crude oil and the most important individual Middle Eastern crude grade by volume.

Specifications: Arab Light API approximately 33 degrees, sulfur content approximately 1.8%. Classification: light sour. The combination of moderate density with significant sulfur content is characteristic of Middle Eastern conventional crudes.

Production: Saudi Arabia produces approximately 9 million barrels per day total across all grades. Arab Light accounts for approximately 5.4 mbd (60 percent). Other Saudi grades include:

• Arab Extra Light: API 38, sulfur 1.1%, production approximately 800 kbd
• Arab Medium: API 30, sulfur 2.5%, production approximately 1.5 mbd
• Arab Heavy: API 27, sulfur 2.9%, production approximately 1.0 mbd
• Arab Super Light: API 40, sulfur 0.5%, production approximately 150 kbd

Pricing role: Aramco publishes Official Selling Prices (OSPs) monthly for each Arab grade to each destination (Asia, Europe, Mediterranean, US). OSPs set effective prices for long-term Saudi contracts and heavily influence spot market pricing for comparable grades. The Arab Light OSP to Asia is one of the most closely-watched monthly announcements in the oil industry.

Refining value: Arab Light’s specific composition yields strong gasoline production potential combined with meaningful diesel and jet fuel yields. Its sour classification requires refineries with appropriate desulfurisation equipment. Asian refiners in particular have invested heavily in the capability to process Arab Light efficiently.

Russian Urals: The Sanctioned Benchmark

Russian Urals is a major global crude grade that has experienced dramatic pricing changes since 2022. Urals is a blended export grade representing crude from Russia’s European Urals region mixed with supplies from Siberia.

Specifications: API approximately 32 degrees, sulfur content approximately 1.7%. Classification: light sour. Very similar specifications to Arab Light, which means it competes in similar refining applications.

Production: Russia produces approximately 10 million barrels per day total, with exports around 5 mbd. Urals export volumes typically run 2.5-3.5 mbd. Other Russian grades include ESPO (Asian-delivered, lighter and lower sulfur than Urals), Sokol, and Vitol.

Pricing impact of 2022 sanctions: Following Russia’s invasion of Ukraine, Urals crude traded at a substantial discount to Brent. Peak discount reached $40+ per barrel in 2022. Current discount in April 2026 has narrowed to approximately $10-12 per barrel as trading patterns normalised. The G7 price cap of $60 per barrel on Russian oil established in December 2022 has produced partial but imperfect enforcement.

Market access: Following Western sanctions, Russian crude has been redirected predominantly to Indian and Chinese refineries. Our analysis of Iran dark fleet covers the broader sanctions-evading oil trade infrastructure. Indian private refiners (Reliance, Nayara) have been particularly large Urals buyers.

Nigerian Bonny Light: The African Premium

Nigerian Bonny Light is the most important African crude oil grade and a valuable light sweet crude for global markets.

Specifications: API approximately 36 degrees, sulfur content approximately 0.15%. Classification: light sweet. Particularly low sulfur makes Bonny Light one of the sweetest crudes globally, commanding premium prices.

Production: Nigerian production has declined dramatically due to infrastructure problems, theft, and security issues. From peak 2.5 mbd a decade ago, Nigeria currently produces approximately 1.3-1.5 mbd, with Bonny Light representing about 250 kbd of that total.

Pricing: Bonny Light typically trades at a $0.50 to $2.00 premium to Dated Brent reflecting its superior specifications. The premium widened during 2022 when sweet-sour spreads expanded globally.

Main customers: European and Indian refiners have historically been major Bonny Light buyers. US refiners took Bonny Light before shale displaced the need. Currently Asian demand is growing as specific refineries have been configured for African sweet crude.

Mexican Maya: The Heavy Sour Benchmark

Mexican Maya is the leading heavy sour crude benchmark globally and represents a different end of the crude oil spectrum from the light sweet grades.

Specifications: API approximately 22 degrees, sulfur content approximately 3.3%. Classification: heavy sour. Viscous, high-sulfur composition requires specialized refining.

Production: Mexico’s state oil company Pemex produces Mexican crude grades including Maya, Isthmus (medium), and Olmeca (light). Mexican crude production has declined from peak 3.4 mbd in 2004 to approximately 1.7 mbd currently. Maya represents approximately 60 percent of Mexican production.

Pricing: Maya trades at substantial discount to Brent, typically $10-15 per barrel. The discount reflects both density (lower quality products yielded) and sulfur (higher refining cost). US Gulf Coast refineries configured for heavy sour crude are the primary Maya customers.

Strategic role: Maya’s specific role is feedstock for complex US Gulf Coast refineries that were built specifically to process heavy sour crudes at profit margins from cracking residual fuel oil into higher-value products. These refineries have substantial capital investment in coking, hydrocracking, and sulfur removal equipment.

Canadian Western Canadian Select (WCS)

Canadian oil sands production is represented in global markets primarily through the Western Canadian Select (WCS) blend.

Specifications: API approximately 21 degrees, sulfur content approximately 3.5%. Heavy sour, similar to Maya but even heavier in some cases.

Production: Canadian oil sands production is approximately 3.2 million barrels per day. Total Canadian production including conventional crude reaches approximately 4.7 mbd. Most Canadian oil flows via pipeline to US Midwest and Gulf Coast refineries.

Pricing: WCS typically trades at $15-25 per barrel discount to WTI. The deep discount reflects quality differential plus pipeline constraints that periodically limit export capacity. The 2013-2018 period saw WCS discounts exceed $35 per barrel during pipeline shortages.

Future outlook: Canadian oil sands production is sustained by existing infrastructure investment. New growth is limited. The TMX (Trans Mountain Expansion) pipeline completed in 2024 improved export access to Pacific markets, narrowing WCS discount somewhat.

Iranian Crude Grades

Iranian crude represents a significant but sanctioned oil source. Our Iran dark fleet analysis provides detail on current Iranian oil trade dynamics.

Iranian Light: API approximately 33, sulfur approximately 1.4%. Similar to Arab Light specifications. Primary export grade.

Iranian Heavy: API approximately 30, sulfur approximately 1.7%. Medium sour equivalent to Arab Medium. Second-largest Iranian export grade.

Iranian Forozan Blend and Soroush: Additional grades for specific customer markets. Forozan is medium sour; Soroush is heavier.

Pricing: Due to sanctions, Iranian crude trades at $10-15 discount to Brent. Buyers are predominantly Chinese teapot refineries. Specific pricing varies based on delivery arrangements and counterparty relationships.

Grade-Specific Refining Yields

Different crude grades yield different product mixes when refined. Understanding these yields is essential for appreciating why grade differentials exist and how refining value is calculated.

A typical barrel of crude oil (42 US gallons or 159 litres) yields approximately 42-45 gallons of finished products due to volume gains from refining processes. The specific product mix varies dramatically by crude grade:

The gasoline yield differential — WTI at 45% versus Maya at 28% — is the single most economically significant difference between light and heavy crudes. Gasoline commands premium pricing in most markets, so high gasoline yield translates to high refining value. This is why light sweet crudes command premium pricing despite being geologically less abundant than heavy sour crudes.

Regional Grade Flow Patterns

The global oil trade flows reflect specific grade-region matching dynamics. Understanding these flows provides deeper context for grade pricing:

Middle East to Asia. The largest single oil trade flow. Middle Eastern sour crudes (Arab Light, Dubai, Kuwaiti, Iraqi) flow to Asian refineries configured for sour processing. Approximately 15 mbd of Middle Eastern crude flows east to Asian markets.

Americas inter-regional. Canadian heavy to US Gulf Coast, US shale to East Asia, Venezuelan to China when sanctions permit, Mexican to US and Europe. Total Americas crude flows involve approximately 8 mbd of cross-border trade.

Russia East and South. Post-2022, Russian crude flows dramatically redirected from European to Asian and Indian buyers. Approximately 3 mbd of Russian crude now flows east versus historical westbound flows.

West Africa to Atlantic markets. Nigerian, Angolan, Equatorial Guinea crudes flow to European and (historically) US refineries. Asian demand has grown for West African crudes with specific specifications.

North Sea to global. Brent and other North Sea grades flow to European, US, and Asian markets depending on arbitrage economics.

Grade Pricing Methodology

Specific pricing methodologies govern different crude grades. Understanding these methodologies helps interpret grade prices accurately.

Physical assessment agencies. Platts (part of S&P Global), Argus Media, and OPIS provide daily assessments of physical crude prices. These assessments drive the underlying price discovery for most international crude trade.

Futures market settlement. Brent and WTI futures provide financial benchmarks. Prompt-month futures often anchor broader market pricing discussions.

Official Selling Prices (OSPs). National oil companies publish monthly OSPs for their crude grades. Saudi Aramco, Iraqi SOMO, Kuwait KPC, UAE ADNOC, and others publish OSPs that effectively set prices for long-term term contracts.

Spot market pricing. Occasional spot transactions provide additional price discovery, particularly for smaller grade volumes not covered by major term contracts.

Specialized Grade Considerations

Several specialized grade-related topics deserve specific attention for professional market participants:

Wellhead versus delivered pricing. Crude price at wellhead versus delivery point reflects transportation differential. This is particularly important for US shale (Permian wellhead versus coastal export point) and Canadian oil sands.

Time spreads and contango/backwardation. Different grades can have different time structure patterns. Contango (forward months priced above prompt) or backwardation (forward below prompt) affects storage economics and trading strategies.

Quality arbitrage. When grade differentials move outside historical ranges, quality arbitrage opportunities emerge. Specialized traders monitor these for commercial opportunities.

Seasonal patterns. Some grades have seasonal demand patterns (heating oil demand affecting sour crude preference during winter, for example). Sophisticated analysis incorporates these seasonal dimensions.

Grade Spread Economics

For traders and refiners, the differentials between grades are as important as the absolute price level. Several specific spreads are actively traded and monitored:

Brent-WTI spread. Indicates global-to-US price relationship. Affects US import/export economics.

Brent-Dubai spread. Reflects Atlantic basin versus Middle East benchmark relationship. Typically positive (Brent above Dubai) reflecting quality differential.

Sweet-sour differentials. Reflect refining value of sulfur. Wider spread indicates refining tightness or environmental regulation impact.

Heavy-light differentials (Maya-Brent, WCS-WTI). Reflect refining complexity preference and product demand patterns.

Regional benchmark spreads. Spread between Brent and Dubai affects cross-regional oil arbitrage.

Implications for Producers

For major oil producing countries, grade mix affects revenue substantially. Saudi Arabia benefits from having multiple grades covering the spectrum from super-light to heavy. Russia’s Urals-dominated export mix has been affected by Western sanctions. Iran operates under sanctions discount. Nigeria’s quality advantage has been partially offset by production challenges.

For individual companies, grade mix similarly matters. Aramco’s Arab Light-heavy mix provides specific refining value. ExxonMobil’s Permian-Guyana-Canada grade mix spans multiple specifications. Our Aramco vs ExxonMobil comparison discusses these different grade portfolio positions.

Implications for Refiners

Refineries are optimised for specific crude slates. Changing the crude slate substantially requires capital investment in additional refining equipment. Specific refineries are designed around specific grade preferences:

US Gulf Coast complex refineries. Optimised for heavy sour crudes (Maya, Canadian oil sands blends). Substantial coking and hydrocracking capacity. Cost $15-25 billion to build over decades.

European complex refineries. Mixed slate capability. Historically processed light sweet crudes but many have added sour processing capability over past two decades.

Asian refiners. Large modern capacity optimised for Middle Eastern sour crudes (Arab Light, Dubai) plus Russian Urals since 2022. Asian refining capacity has grown dramatically over past decade.

Simple refineries. Older facilities with limited desulfurisation capacity. Restricted to sweet crude processing. Declining economic competitiveness given sulfur regulation.

Grade Differentials and Oil Price Forecasting

For forecasting purposes, understanding grade differentials is essential. Our Brent Q2 2026 forecast discusses headline price forecasts. But specific trade flows are priced in specific grades, and forecast accuracy requires tracking grade relationships.

Specific forecasting considerations:

Environmental regulation impact. IMO 2020 sulfur regulations significantly affected sweet-sour differentials. Future tightening of environmental rules can produce similar shifts.

Refining capacity investment. New refinery projects specify particular crude slates. Shifts in capacity building patterns affect grade demand.

Geopolitical sanctions. Sanctions on specific producers (Russia, Iran, Venezuela) affect grade-specific pricing. Changes in sanctions regimes materially shift grade economics.

Transportation bottlenecks. Pipeline capacity (Keystone XL historical example) and port capacity can widen or narrow grade spreads independent of fundamental quality differences.

Specific Market Developments 2020-2026

The oil market from 2020 to 2026 saw specific grade-related developments worth noting:

IMO 2020 implementation. International Maritime Organization’s January 2020 sulfur cap (0.5% sulfur in marine fuel) created structural demand shift from heavy residual fuel to low-sulfur fuels. Sweet crude premium expanded.

Russia redirection post-2022. Russian Urals export pattern shifted from European buyers to Asian buyers. This created new Urals pricing patterns and trade flows.

Saudi OSP methodology. Saudi Aramco’s official selling prices became increasingly watched as a leading indicator of Saudi view on market tightness.

Strategic petroleum reserve composition. US SPR releases and refills through 2020-2026 affected specific grade availability on US Gulf Coast.

Mexican Pemex decline. Continuing Mexican production decline reduced Maya availability to US Gulf Coast refiners, tightening heavy sour spreads.

Grade Selection for Specific Applications

Refiners select crude grades based on multiple criteria beyond simple price. The configuration of the refinery — hydroskimming, cracking, or full conversion — determines which grades generate the best economics. A simple hydroskimming refinery in a market with strong gasoline demand benefits most from light sweet crudes like WTI or Brent that yield naphtha and gasoline with minimal processing. A full conversion refinery with cokers and hydrocrackers can accept heavy sour grades like Maya or Urals because the coking and hydrocracking units convert the residual fractions into lighter products.

Beyond refinery configuration, product market dynamics matter substantially. When diesel prices are strong relative to gasoline, grades with higher middle distillate yields become more attractive. When jet fuel demand is exceptional — as during recovery periods — grades yielding kerosene and jet receive premium bids. Seasonal patterns also shift grade economics: summer gasoline demand makes light grades more valuable, while winter heating oil demand pulls for diesel-rich grades. Refiners optimize their crude slate continuously based on these evolving product spreads.

Export decisions face similar optimization. A Saudi producer exporting Arab Light to multiple destinations must decide how to allocate barrels between Asia (where the grade trades against Dubai/Oman), Europe (where it competes against North Sea and Russian grades), and the Americas (where it faces WTI and Maya). The Saudi official selling prices reflect these arbitrage considerations and effectively ration supply across regions based on where the grade generates highest netback value.

Grade Transportation Economics

The transportation cost structure significantly affects realized grade economics. VLCCs (Very Large Crude Carriers) carrying 2 million barrels are the dominant long-haul shipping mode for Middle East to Asia flows, and their freight rates can shift grade preferences substantially. When VLCC rates spike — as they did in late 2024 following Red Sea disruptions — Middle East grades become relatively more expensive to deliver to Western markets compared to Atlantic Basin grades like WTI or North Sea grades. This freight premium adjustment shifts regional grade demand in predictable ways.

Pipeline economics operate differently. Pipeline-delivered grades like WTI to Cushing or Canadian WCS to Gulf Coast refiners have stable, predictable transportation costs that don’t fluctuate with tanker markets. This stability is valuable to refiners building long-term supply contracts. The recent expansions of pipeline infrastructure — the Trans Mountain expansion delivering Canadian crude to West Coast, the continued development of Permian takeaway capacity — reshape regional grade economics on multi-year timeframes by altering which grades can reach which markets at what cost.

Rail transportation plays a secondary but important role for stranded production. Canadian crude without pipeline access moves by rail at higher cost, creating locational discounts for those grades. When pipeline capacity tightens, rail differentials widen significantly, discounting affected grades until relief arrives via new pipeline capacity or production adjustments.

Grade Chemistry Deep Dive

Beyond API gravity and sulfur, crude grade chemistry involves numerous other factors that affect refining economics. Nitrogen content affects catalyst poisoning in hydrotreating and hydrocracking units. Metals content — particularly nickel and vanadium concentrated in heavy grades — deactivates catalysts and requires removal before further processing. Asphaltene content in heavy crudes like Maya and Canadian grades affects compatibility with other crudes in blended slates and can cause precipitation problems in storage and processing.

Total acid number (TAN) measures naphthenic acid content that can cause corrosion in refinery equipment, particularly in heated vacuum distillation units. Grades with TAN above 0.5 mg KOH/g require special metallurgy or corrosion inhibitor programs, limiting which refineries can process them. Several West African grades like Doba and Dalia have elevated TAN that restricts their refiner base and creates persistent discounts to nominal quality peers.

Pour point — the temperature at which crude stops flowing — affects logistics. Waxy crudes like some Indonesian grades and certain North Sea grades have high pour points requiring heated storage and pipelines in cold climates. This limits their marketability in winter to specific destinations with appropriate infrastructure, creating seasonal grade differentials that wouldn’t be predicted from simple quality metrics alone.

Historical Grade Spread Evolution

The relative positioning of global crude grades has evolved dramatically over recent decades. The Brent-WTI spread — historically near zero when both were easily fungible — widened to over $25 during 2011-2013 when US shale production overwhelmed takeaway infrastructure at Cushing. The spread normalised after US export restrictions were lifted in late 2015 and remained relatively tight until 2022 Russia sanctions reshaped global flows again. By 2026 the spread is typically in the $2-5 range reflecting equilibrium between Atlantic and Inland US basins.

Light-heavy spreads have been particularly volatile. The heavy crude discount — measured by Maya minus WTI or Urals minus Brent — fluctuates based on heavy refining capacity utilization globally. When complex refineries run hard, heavy discounts compress; when simple refineries carry the marginal barrel, heavy discounts widen. The gradual global addition of coking and hydrocracking capacity over the past two decades has structurally compressed heavy discounts compared to historical norms, but individual year variations remain significant.

Sweet-sour spreads similarly depend on sulfur processing capacity utilization. The International Maritime Organization’s 2020 sulfur cap rules (IMO 2020) initially widened sweet-sour spreads by boosting demand for low-sulfur crudes. The spread has since partially normalized as refiners adapted their configurations and as marine gasoil and very low sulfur fuel oil (VLSFO) markets matured. These structural shifts take years to fully play out and continue to affect grade economics through 2026.

The Bottom Line

Understanding crude oil grades is foundational for anyone working in, trading, or investing in oil markets. The differences between Brent, WTI, Dubai, Arab Light, and other major grades affect pricing, refining economics, and producer-country dynamics in ways that headline oil price numbers do not capture.

For investors and traders, specific grade-related considerations matter for portfolio construction and risk management. For refiners and industrial consumers, grade choice affects operational economics substantially. For producing countries, grade mix determines export revenue trajectory.

As the oil market continues evolving through 2026 and beyond, grade differentials will remain an important dimension of oil market analysis. Our ongoing oil market coverage tracks these dynamics. External resources from EIA, Reuters, Bloomberg, and industry data providers provide detailed grade-specific data and analysis for professional users.