What Is WTI Crude Oil? The Storage & Infrastructure Guide
West Texas Intermediate (WTI) is a light, sweet crude oil grade that serves as the primary pricing benchmark for the North American petroleum market and the underlying commodity for the world’s most actively traded crude oil futures contract on the New York Mercantile Exchange (NYMEX). With an API gravity of approximately 39.6° and sulphur content of around 0.24–0.34%, WTI is slightly lighter and sweeter than Brent crude — making it one of the highest-quality benchmark crudes in the world for gasoline and distillate refinery yield.
For storage professionals and terminal operators, understanding what WTI crude oil is means understanding a benchmark whose price is physically anchored to a single inland hub — Cushing, Oklahoma — and how that landlocked infrastructure constraint creates pricing dynamics, storage economics, and supply chain vulnerabilities that no seaborne benchmark faces.
What Is WTI Crude Oil Made Of
WTI crude oil is not produced from a single oilfield. It is defined as light sweet crude oil traded and delivered at Cushing, Oklahoma — meaning any crude stream that meets the NYMEX contract’s lightness and sweetness specifications qualifies as WTI at the point of delivery. The NYMEX WTI futures contract specifies crude between 37° and 42° API gravity with sulphur content below 0.42%.
Historically, WTI was sourced primarily from fields around Midland, Texas, and Cushing, Oklahoma. The US shale revolution transformed this supply base: today the dominant source is the Permian Basin in West Texas and southeastern New Mexico — the world’s most prolific crude producing basin — with additional volumes from the Bakken formation in North Dakota, the Eagle Ford in south Texas, and the Niobrara in Colorado. These streams flow via pipeline to Cushing, where they are blended and stored before onward delivery to Gulf Coast refineries or export terminals.
A distinct sub-grade, WTI Midland, is assessed at Midland, Texas, rather than Cushing. WTI Midland was added to the Brent BFOET pricing basket in 2023, reflecting the scale of Permian Basin production and its integration into global crude trade flows — a development that directly links US inland production to the world’s dominant benchmark.
Cushing, Oklahoma: The Pipeline Crossroads of the World
No understanding of what WTI crude oil is can be separated from Cushing, Oklahoma — the small town of approximately 8,000 people that is simultaneously the physical delivery point for the NYMEX WTI futures contract and the most strategically important crude oil storage hub in North America.
The Cushing Oil Field was discovered in 1912 and dominated US production for several years. As local production declined, Cushing’s value shifted from extraction to logistics: its position at the intersection of multiple pipeline corridors made it the natural settlement point for crude flows from the Midcontinent, the Permian Basin, Canada, and the Gulf Coast. Today, crude oil flows into Cushing from all directions via dozens of inbound pipelines, and flows outbound to Gulf Coast refineries and, since 2012, to export terminals via reversed and expanded pipeline capacity.
Cushing storage capacity — currently estimated at approximately 90 million barrels across tank farms operated by Magellan Midstream (now ONEOK), Plains All American, Enbridge, and other midstream operators — is published weekly by the US Energy Information Administration as part of the weekly Petroleum Status Report. These inventory figures are among the most closely watched data releases in global commodity markets: rising Cushing stocks signal oversupply and exert downward pressure on WTI prices; falling stocks tighten the market and support prices.
What Is WTI Crude Oil: The Landlocked Pricing Problem
WTI crude oil’s most significant structural characteristic — and its primary disadvantage relative to Brent as a global benchmark — is that it is landlocked. Unlike Brent, which is produced offshore and loaded directly onto ocean tankers at Sullom Voe and Hound Point, WTI can only reach export markets via pipeline to Gulf Coast terminals and then onto tankers. This creates an infrastructure bottleneck that Brent does not face.
When US shale oil production surged after 2010, outpacing pipeline capacity to carry crude from the Midcontinent to the Gulf Coast, Cushing inventories built rapidly. WTI could not be arbitraged to global markets efficiently, causing WTI to trade at a sustained discount to Brent — reaching over $23/bbl in August 2012. The spread only narrowed after significant pipeline infrastructure investment: the reversal of the Seaway Pipeline in 2012, the expansion of Keystone capacity, and the construction of new Permian Basin export pipelines connecting Midland to Gulf Coast terminals at Corpus Christi and Houston.
This episode demonstrated a fundamental principle for storage operators: when pipeline capacity is the binding constraint, regional crude prices can diverge dramatically from global benchmarks, and storage at the constrained hub becomes extraordinarily valuable. Cushing tank farm operators captured significant storage lease rate premiums during the 2011–2013 period of maximum WTI/Brent spread.
The April 2020 Event: What WTI Crude Oil Storage Constraint Looks Like at Extremes
The most dramatic illustration of WTI’s landlocked vulnerability came on 20 April 2020, when the NYMEX WTI May 2020 futures contract settled at minus $37.63 per barrel — the first negative crude oil price in the contract’s history. Brent settled at positive $26.21 on the same day.
The cause was a collision between two forces: the COVID-19 demand collapse had reduced global crude consumption by an estimated 25–30 million barrels per day, while Cushing storage was approaching physical capacity. Holders of expiring May WTI futures contracts — who faced mandatory physical delivery at Cushing — could find no buyers willing to take the oil, because there was nowhere at Cushing to put it. The absence of accessible marine storage or alternative delivery points meant the price had to fall far enough to incentivise someone to take delivery and find storage. Negative prices were the market’s mechanism for rationing the last available Cushing ullage.
Brent’s relative resilience on the same day reflected its structural advantage: Brent futures contracts can access the storage capacity of all shore tanks across Northwest Europe and available floating storage on tankers — a global pool of potential ullage that dwarfs the fixed capacity at a single Oklahoma pipeline junction. The April 2020 event is the defining case study in how physical storage infrastructure determines crude benchmark behaviour under stress.
WTI Crude Oil Storage Economics: Contango and the Cushing Inventory Cycle
Under normal market conditions, WTI storage economics follow the same contango/backwardation logic as other crude benchmarks. When the WTI forward curve is in contango — with futures prices for future months above spot — the spread between prompt and forward prices can exceed the all-in cost of Cushing tank storage, creating a commercial incentive to buy physical WTI, store it at Cushing, and sell forward at a higher price.
This contango storage trade drives Cushing inventory builds during periods of oversupply and depressed prompt prices. Cushing tank farm operators benefit from elevated storage lease rates during these periods, as traders compete for available ullage. When the market moves into backwardation — spot prices above forward — the storage incentive reverses, Cushing inventories draw down rapidly, and spot ullage demand falls as traders minimise carry costs.
The weekly EIA Cushing inventory data — released every Wednesday as part of the Petroleum Status Report — directly signals these dynamics to the market. A larger-than-expected build is typically bearish for prompt WTI prices; a larger-than-expected draw is bullish. No other single weekly data release has a comparable direct impact on a global crude benchmark price.
Current WTI benchmark prices are tracked on our WTI crude price page. For the global crude pricing context, see our crude oil price page and Brent crude price page. Crude storage infrastructure is covered in our oil storage terminals guide and our ranking of the top 10 crude oil storage companies.
WTI futures contract specifications and Cushing inventory data are published by the U.S. Energy Information Administration (EIA).
WTI Crude Oil in the Global Supply Chain
WTI crude oil moves from Permian Basin and other US producing regions through a network of gathering pipelines to Cushing and then via trunk pipelines to Gulf Coast refining and export infrastructure. The major pipeline corridors include the Keystone system from Canada, the Longhorn and BridgeTex pipelines from the Permian, and the Seaway and Flanagan South systems connecting Cushing to the Gulf Coast.
Since the lifting of the US crude oil export ban in December 2015, WTI-priced crude has entered global trade in significant volumes. Gulf Coast export terminals at Corpus Christi, Houston, and the Louisiana Offshore Oil Port (LOOP) load WTI Midland and other US grades onto VLCCs for delivery to European and Asian refiners. This export infrastructure growth has progressively reduced the Brent-WTI spread, as the ability to arbitrage WTI to global markets limits how far the two benchmarks can diverge.
The tank terminals global guide covers crude storage and export terminal infrastructure in the context of the global liquid storage sector, including US Gulf Coast terminals active in WTI-priced crude exports.
What is WTI crude oil?
West Texas Intermediate (WTI) is a light, sweet crude oil grade with an API gravity of approximately 39.6° and sulphur content below 0.34%. It serves as the primary North American crude oil benchmark and the underlying commodity for NYMEX crude oil futures contracts. Its price is physically anchored to the storage and pipeline hub at Cushing, Oklahoma, where WTI futures contracts require physical delivery.
What is the difference between WTI and Brent crude?
Both are light sweet crude benchmarks, but WTI is landlocked — priced and delivered at Cushing, Oklahoma — while Brent is produced offshore in the North Sea and loaded directly onto ocean tankers. WTI is slightly lighter and sweeter than Brent but typically trades at a discount because its landlocked delivery point limits access to global storage and export infrastructure. Brent prices approximately 80% of internationally traded oil; WTI is the North American regional benchmark.
What is Cushing Oklahoma and why does it matter for WTI crude oil?
Cushing, Oklahoma is the physical delivery and price settlement point for NYMEX WTI futures contracts, and the largest crude oil storage hub in North America with approximately 90 million barrels of tank capacity. Weekly EIA inventory data from Cushing is one of the most closely watched indicators in global commodity markets — rising stocks exert downward pressure on WTI prices, while draws are bullish. When Cushing storage approaches capacity, WTI prices can diverge dramatically from global benchmarks, as demonstrated in April 2020 when WTI briefly settled at minus $37.63 per barrel.
What does WTI crude oil contango mean for storage operators?
When the WTI forward curve is in contango — future prices above spot — the spread between prompt and forward prices can exceed the cost of Cushing tank storage, creating a commercial incentive to buy physical WTI, store it, and sell forward. This drives inventory builds at Cushing and elevated storage lease rates as traders compete for available ullage. When the market moves into backwardation, the storage incentive reverses and inventories draw down as traders minimise carry costs.
Why did WTI crude oil go negative in April 2020?
On 20 April 2020, the NYMEX WTI May 2020 futures contract settled at minus $37.63 per barrel — the first negative crude oil price in the contract’s history. The cause was a combination of COVID-19 demand collapse and Cushing storage approaching physical capacity. Holders of expiring contracts faced mandatory physical delivery at Cushing but could find no buyers willing to take oil because available tank space was exhausted. Negative prices were the market mechanism for rationing the last available Cushing ullage. Brent settled at positive $26.21 on the same day, insulated by its broader access to global seaborne storage.