Мұнай бағасын белгілейтін WTI нақты мұнайының сипаттамасы

Grade of crude oil used as a benchmark in oil pricing

West Texas Intermediate (WTI) is a grade or mix of crude oil; the term is also used to refer to the spot price, the futures price, or assessed price for that oil. In colloquial usage, WTI usually refers to the WTI Crude Oil futures contract traded on the New York Mercantile Exchange (NYMEX). The WTI oil grade is also known as Texas light sweet. Oil produced from any location can be considered WTI if the oil meets the required qualifications. Spot and futures prices of WTI are used as a benchmark in oil pricing. This grade is described as light crude oil because of its low density and sweet because of its low sulfur content. The price of WTI is often included in news reports on oil prices, alongside the price of Brent crude from the North Sea. Other important oil markers include the Dubai crude, Oman crude, Urals oil, and the OPEC reference basket. WTI is lighter and sweeter, containing less sulfur than Brent, and considerably lighter and sweeter than Dubai or Oman.

Unlike Brent Crude, WTI crude oil is not from any specific oil fields. Rather, WTI is described (for example by the Alberta Government) as "light sweet oil traded and delivered at Cushing, Oklahoma" (with WTI Midland and WTI Houston crude oil defined similarly for Midland, Texas, and Houston, Texas respectively). Historically, local trade between oilfield production and refineries around Midland, Texas, and Cushing, Oklahoma, could be said to define WTI oil, but as local production declined, pipelines into those areas began to deliver crude oil of other grades, produced and blended elsewhere, which were also accepted as WTI. The WTI futures contract formalized this relationship by specifying that the deliverable asset for the contract could be a blend of crude oil, as long as it was of acceptable lightness and sweetness. Crude oil lightness is characterized by oil gravity, and crude oil sweetness by sulfur content. Measurements of lightness and sweetness of WTI changes depending on the particular light and sweet oil traded at Cushing at the time of the measurement, and even the particular measurement methodology. +WTI crude oil lightness and sweetness characterizations Characteristics NYMEX WTI futures contract (May 2020) Platts WTI assessment (May 2020) Argus WTI Assessment (Mar 2020) Lightness Between 37 and 42 degrees API gravity 41.4 degrees API gravity 40 degrees API gravity Sweetness Below 0.42% sulfur content 0.37% sulfur 0.40% sulfur

The Platts and Argus API and sulfur measurements are descriptions of WTI as assessed, while the NYMEX WTI futures contract characterization is a requirement for WTI crude oil delivery to the contract. WTI crude oil will typically satisfy the WTI futures contract requirements and be close to the Platts and Argus assessed values at the time. while the adoption of the WTI futures contracts as hedging tools by producers and refiners worldwide lead to the worldwide adoption of assessed physical WTI spot prices as benchmark prices for crude.

Price Reporting Agencies (PRAs), such as Platts and Argus Media, compiled assessment prices of WTI based on prices of spot transactions starting in 1981. Subsequently, Saudi Arabia, Kuwait, and Iraq started using the Argus Sour Crude Index (ASCI) as their price index in 2009, but the ASCI index itself is priced in relation to WTI futures with a differential, which imply those countries still effectively benchmark their crude oil selling prices to WTI.

The volatility of crude oil prices after the US oil price decontrol led to the development of the NYMEX WTI Light Sweet Crude Oil futures contract in 1983.

Cushing, Oklahoma is a major trading hub for crude oil and has been the delivery point for crude contracts and therefore the price settlement point for West Texas Intermediate on the New York Mercantile Exchange for over three decades. The town of Cushing, Oklahoma is a small, remote place with only 7,826 inhabitants (according to the 2010 Census). However, it is the site of the Cushing Oil Field, which was discovered in 1912, and dominated U. S. oil production for several years. The area became a "vital transhipment point with many intersecting pipelines, storage facilities, and easy access to refiners and suppliers," infrastructure which remained after the Cushing field had declined in importance. Crude oil flows "inbound to Cushing from all directions and outbound through dozens of pipelines". It is in Payne County, Oklahoma, United States.

Starting in 2003, an influx of traders from outside of the oil industry begun to participate in oil futures and other commodities futures markets. These market participants, which includes hedge funds, pension funds, insurance companies, and retail investors, were motivated by the increasing acceptance of oil futures contracts and related derivatives as financial assets. Demand from these investors and general financial innovation created inexpensive access to financial instruments related to oil futures contracts, such as options, index funds, and exchange traded funds. As part of wave of investor interest, WTI crude oil futures prices (as well as Brent Crude oil prices) are included in both the Bloomberg Commodity Index and the S&P GSCI commodity index, which are benchmark indices widely followed in financial markets by traders and institutional investors. Its weighting in these commodity indices give LME Nickel prices non trivial influence on returns on a wide range of investment funds and portfolios.

For financial investors without oil storage, purchasing the shortest maturity futures contract and then rolling to the next contract priory to expiry offered the closest approximation to investing in physical oil prices. However, financial markets are much larger than oil markets, and investor flows began to dominate oil producers' hedging needs and moved the oil futures market into contango, where futures prices are greater than spot prices. Contango imposes a roll cost on investors who must roll futures contracts, as they must pay a relatively higher price for those contracts to get the same underlying spot price exposure as their previous expiring contract. These roll costs could be viewed as compensation, purchased virtual storage, or an indirect subsidy for storage owners to provide the service of storing crude on behalf of financial investors. In the WTI context, storage owners would include most participants in the physical WTI market. Beyond the need by financial investors in oil, oil storage is also valuable because it provides insurance against supply disruptions or unexpected increases in demand. Refiners who wish to avoid carrying real physical oil inventories can purchase futures contracts as virtual storage as an alternative. Oil producers wishing to maintain real physical oil inventories similarly could lower the cost of those inventories through selling futures contracts. Index fund participation in the crude oil market is also associated with lower price volatility. WTI futures contracts are tied to physical deliveries into the physical spot WTI market, so WTI futures contract prices should converge to physical spot WTI market conditions and prices. But since deliveries made to settle an expiring WTI futures contract are also physical spot WTI transactions that can be included into PRA assessed prices, abnormal futures contract transactions could drive WTI spot prices and assessed prices. This was the case on April 20, 2020, when WTI futures contract trading drove both assessed WTI and ASCI prices to negative territories. Prices mainly dropped due to the COVID 19 pandemic, which reduced demand, with storage issues and the expiration of the May contract on the following day resulting in reduced trading. For the first time ever, the reduction in trading shut down the Trade at Settlement (TAS) mechanism of the May 2020 WTI contract 30 minutes before the end of trading due to a lack of buyers. The TAS shutdown signaled to market participants that all remaining open May 2020 WTI contracts that have to be sold, either outright or for the purposes of rolling to the June 2020 contract, to the open market in the next twenty minutes. The speed at which the contracts had to be sold, and the closeness of that time to contract expiry meant that large physical oil traders, who could have transported and stored oil elsewhere given a low enough price, could not buy contracts due to operational, risk management, and position limit constraints. Any remaining traders who were willing to buy contracts gained enormous market power and pushed prices downwards into negative territory. At the same time, Mars crude oil produced in the US Gulf Coast (USGC) settled at $26.63, and Middle East exporters who uses ASCI (of which Mars is a component) as the selling price benchmark had to settle for negative prices that day. against Brent crude oil. Both the volatility of the WTI/Brent premium/discount, as well as its reversal from premium to discount in 2011, are studied and monitored by market participants as indicators for the functioning of WTI and Brent Crude as oil price benchmarks.

In February 2011, WTI was trading around $85/barrel while Brent was at $103/barrel. The reason most cited for this difference was that Cushing had reached capacity due to a surplus of oil in the interior of North America. At the same time, Brent moved up in reaction to civil unrest in Egypt and across the Middle East. Since WTI priced stockpiles at Cushing could not easily be transported to the Gulf Coast, WTI crude was unable to be arbitraged in bringing the two prices back to parity. Oil prices at coastal areas of the United States were closer to Brent than to WTI. In June 2012, the Seaway Pipeline, which had been transporting oil from the Gulf Coast to Cushing, reversed its flow direction, to transport WTI priced crude to the Gulf Coast, where it received Brent prices. The price difference persisted, however, and was large enough that some oil producers in North Dakota put their oil on tanker cars, and shipped it by rail to the Gulf and East Coast, where it received Brent prices. Brent continued to trade $10–20 higher than WTI for two years, until June 2013.

To the extent that price difference between WTI and Brent crude entice traders to ship WTI to North Sea refineries or ship Brent to US Gulf Cost refineries, the premium/discount between WTI and Brent crude must reflect oil tanker freight costs. Oil tanker freight cost rates could be highly volatile, due to circular dependence on fuel oil prices and ultimately crude prices, to demand for oil tankers to serve non USGC non North Sea trade routes (especially to China), and to demand for using oil tankers as floating storage for crude oil. From 2000 to 2009, oil tanker freight rates represented a substantial contributor to the WTI premium over Brent crude.

Premiums/discounts between WTI and Brent crude also reflects declining crude oil production priced under Brent crude prices. As crude production declines from depletion in Brent crude associated North Sea oilfields (Brent, Forties, Oseberg, Ekofisk, and Troll; also referred to as BFOET), a higher proportion of that oil production is consumed by local European refiners, and both a lesser proportion and a lesser absolute amount of that oil production can be exported to the US. During periods when WTI trades at a premium to Brent crude, declining Brent crude production pushes up that premium as traders cannot source supplies to sell into the US for a profit. These quality changes to Brent Crude oil directly affect the premium or discount between what refiners would pay for WTI and Brent crude oil.