West Texas Intermediate, almost always abbreviated WTI, is the dominant crude oil benchmark for the United States and the second-most-watched oil price in the world after Brent. It is the underlying grade for the NYMEX light sweet crude futures contract, the most heavily traded oil futures contract on any exchange, and its daily settlement price is what most American financial news outlets mean when they refer to "the price of oil."
This guide explains what WTI actually is — the geology and geography behind the name, the contract that turned a regional grade into a global financial instrument, the structural quirk of its delivery point, and why its relationship to Brent has been one of the most-studied spreads in commodity markets for the past two decades.
What "WTI" Refers To
WTI is not a single oilfield. It is a grade specification — a quality standard — that several streams of crude produced in the Permian Basin and other U.S. mid-continent regions can meet. The name dates to a period when most of the qualifying crude originated in the Permian, the prolific oil-producing area straddling West Texas and southeastern New Mexico. Today, the Permian still dominates, but production from the Bakken in North Dakota, the Eagle Ford in South Texas, and the SCOOP/STACK plays in Oklahoma can also flow into the WTI pool as long as the resulting blend meets specification.
The defining characteristic of WTI is its quality. It has an API gravity of approximately 39.6°, making it slightly lighter than Brent's 38°. Its sulfur content is around 0.24% by weight, considerably lower than Brent's 0.37%. By the technical definitions of the refining industry, WTI is "light sweet" — and by a meaningful margin, lighter and sweeter than Brent. In a vacuum, this means WTI yields slightly more gasoline and middle distillates per barrel and is marginally easier to process to low-sulfur fuel specifications.
The Cushing Delivery Point
The single most important fact about WTI as a financial instrument is that the NYMEX contract is physically settled at Cushing, Oklahoma. Cushing is a small town of around 8,000 people that sits at the crossroads of the U.S. crude pipeline system. Pipelines from the Permian, the Bakken, the Gulf Coast, and Canada all converge there, terminating at a tank farm with storage capacity of roughly 90 million barrels.
Each NYMEX WTI futures contract represents 1,000 barrels of light sweet crude delivered to specified pipelines or storage facilities at Cushing during the delivery month. A trader who holds a contract to expiry is contractually obligated to either deliver or take delivery of physical crude at Cushing — which is why almost all financial traders close their positions before expiration.
This design has consequences. Because settlement happens at one specific landlocked location, WTI prices reflect supply-demand conditions at Cushing as much as they reflect the global oil market. When pipelines from the Permian or Canada deliver more crude to Cushing than the outbound pipelines to the Gulf Coast can drain, inventory builds up and WTI weakens versus Brent — sometimes dramatically. The April 2020 episode in which front-month WTI settled at minus $37.63 a barrel was, fundamentally, a Cushing storage crisis: traders holding long positions could not find anywhere to put the physical oil they were obligated to receive.
The U.S. Crude Export Ban
From 1975 until December 2015, the United States prohibited the export of domestically produced crude oil except under narrow exemptions. The ban was introduced in response to the 1973 oil shock as part of a broader policy of conserving domestic supply. It mattered enormously for WTI pricing.
Because U.S. crude could not freely flow to international markets, WTI prices reflected only U.S. domestic supply-demand balance. When the U.S. shale revolution accelerated after 2010, surging Permian and Bakken production overwhelmed Cushing's outbound capacity. WTI traded at deep discounts to Brent — at one point in 2011, the Brent-WTI spread exceeded $25 a barrel. This was not a quality discount or a transport differential; it was a regulatory dislocation. American producers were trapped with crude they could not legally sell to the highest bidder.
The ban was lifted in December 2015. U.S. crude exports have since grown from essentially zero to over 4 million barrels per day, making the United States one of the world's largest crude exporters. The Brent-WTI spread has compressed sharply and now mostly reflects the cost of moving WTI from Cushing to the Gulf Coast and across the Atlantic — generally $3 to $7 a barrel in normal conditions. Our detailed guide to the Brent-WTI spread covers the trading mechanics and current drivers in depth.
WTI Midland vs. WTI at Cushing
An important refinement: not all "WTI" trades at Cushing. A large and growing share of physical Permian crude is sold as "WTI Midland," priced at the pipeline origin in Midland, Texas, rather than at Cushing. WTI Midland is the grade that actually reaches international refiners after being piped to the Gulf Coast and loaded onto tankers.
In 2023, S&P Global Platts began including WTI Midland in the Dated Brent benchmark assessment — a landmark change that effectively globalized the Brent reference and acknowledged that Atlantic-basin oil trade is now dominated by U.S. light sweet crude. For most retail data displays, however, "WTI" still means the NYMEX Cushing contract, and that is what most charts (including ours above) show.
The NYMEX Futures Contract
The NYMEX light sweet crude futures contract launched in 1983 and is now the most heavily traded energy derivative on the planet. Each contract is for 1,000 barrels. Trading runs nearly 24 hours a day across the CME Globex electronic platform. Front-month volume routinely exceeds 1 million contracts per day, representing more than a billion barrels of notional exposure.
The contract supports a deep forward curve extending years into the future, allowing producers, refiners, airlines, and financial speculators to hedge or take positions on long-dated oil prices. NYMEX also lists a wide range of options on WTI futures, calendar spreads, crack spreads against gasoline and heating oil, and WTI-Brent inter-commodity spreads — the last being one of the most popular relative-value trades in commodities.
Who Uses WTI
Despite WTI's regional pricing peculiarities, it functions as a global reference for an enormous range of contracts and decisions:
- U.S. producers hedge future output against NYMEX WTI futures. The depth of the WTI options market is the single most important enabler of the U.S. shale industry's ability to lock in revenue years in advance.
- U.S. refiners price feedstock contracts off WTI-linked formulas and hedge crack spreads using NYMEX gasoline (RBOB) and heating oil futures alongside WTI.
- International refiners increasingly price U.S. crude imports off WTI Midland, given the scale of post-2015 American exports.
- ETF investors gain WTI exposure through funds like the United States Oil Fund (USO), which holds front-month NYMEX WTI futures and rolls them periodically.
- Macro traders use WTI as the most liquid expression of a view on global oil prices, even when their underlying thesis concerns Brent or global demand.
What Drives the WTI Price
WTI responds to the same global supply-demand forces as Brent, with a few U.S.-specific overlays:
Cushing inventory. The weekly U.S. Energy Information Administration (EIA) petroleum status report includes Cushing-specific crude stocks. Surges or drawdowns at Cushing directly affect the WTI-Brent spread. Watch the Wednesday 10:30 a.m. Eastern release.
U.S. shale production. Permian, Bakken, and Eagle Ford output, tracked monthly in the EIA's Drilling Productivity Report and weekly via the Baker Hughes rig count, determines how much crude arrives at Cushing each week.
Pipeline capacity. The Cushing-to-Gulf-Coast pipeline system (Seaway, Marketlink, and others) sets the ceiling on how fast Cushing inventory can drain. Pipeline outages or expansions move the WTI-Brent spread sharply.
U.S. refinery demand. Seasonal refinery maintenance (typically February–March and September–October) reduces crude takeaway and tends to widen the WTI discount to Brent.
SPR activity. Strategic Petroleum Reserve releases and refills affect U.S. domestic balance and can move WTI more than Brent.
Global macro drivers. OPEC+ decisions, geopolitical risk premia, the U.S. dollar, and global demand all affect WTI in line with Brent, with the spread absorbing U.S.-specific deviations.
WTI in One Sentence
WTI is a light sweet U.S. crude grade whose NYMEX futures contract — physically settled at the Cushing, Oklahoma pipeline hub — became the world's most liquid oil derivative despite being priced from a single landlocked location.
Continue Reading
- What is Brent crude — the global counterpart to WTI
- Trading the Brent-WTI spread — mechanics and current drivers
- Brent oil price history — major moves from 1988 to today
- Oil market glossary