Soaring Freight Rates Give US Refiners Edge As Crude Discounts Widen

Soaring tanker rates made imported heavy crude much more expensive for Asian refiners. At the same time, heavy crude available from Canada and Venezuela became cheaper relative to US benchmark WTI. US Gulf Coast refiners therefore gained on both transport costs and feedstock prices. Their refining margins more than doubled in the third quarter.

The key mechanism was location and refinery design. Shipping crude from the US Gulf Coast to Asia rose to $30–$35 a barrel, compared with about $5 a year earlier. US refiners could instead buy Canadian heavy crude, including Western Canadian Select, through shorter routes. Phillips 66 said every $1 widening in the WCS-WTI differential was worth about $140 million in gains.

The advantage also extended into Latin American export markets, where Valero mainly competes with European barrels. Advance vessel contracts protected several refiners from spot-rate increases. Executives expect wider crude discounts to support US refining through at least 2027.

Crude-oil freight rates are the charges for moving crude from a loading port to a refinery or another market. They matter because transport is part of a refinery’s feedstock cost and can determine which suppliers remain competitive. A sharp rate increase can make a distant barrel uneconomical, even when its headline crude price looks attractive.

The article reports that shipping crude from the US Gulf Coast to Asia rose from about $5 to $30–$35 a barrel. Security threats around the Strait of Hormuz disrupted tanker traffic. War-risk insurance premiums also increased. Ships faced longer and riskier routes, adding time, fuel, insurance, and vessel costs to each cargo.

Asian refiners importing similar heavy grades therefore faced a much larger delivered cost. US Gulf Coast refiners were less exposed because they could use nearby Canadian and Venezuelan supplies. Some also had time-charter vessels secured before the conflict, reducing their exposure to suddenly higher spot tanker rates.

Before the war started, about one-fifth of the world’s oil and liquefied natural gas supplies passed through the Strait of Hormuz. The strait is a key maritime chokepoint, meaning a narrow route with outsized importance for shipping. Any security problem there can affect tanker movements and the cost of moving energy supplies.

The article links security threats around Hormuz to disrupted tanker traffic. It also reports higher war-risk insurance premiums and longer voyages. Those pressures pushed crude freight costs sharply higher. Shipping crude from the US Gulf Coast to Asia reached $30–$35 a barrel, compared with about $5 a year earlier.

The consequences differed by region. Asian refiners faced higher costs for similar imported heavy crude. US Gulf Coast refiners could rely more on nearby Canadian and Venezuelan supplies. Their location, refinery configurations, and advance shipping arrangements helped them benefit while competitors absorbed greater transport and insurance costs.

The WCS-WTI price gap widened because Canadian heavy crude faced abundant supply while transport conditions became more expensive and difficult. WCS typically trades below WTI, but elevated freight costs increased the discount needed to keep heavy crude competitive in distant markets. Canada and Venezuela supplied ample heavy crude during the disruption.

The mechanism was especially useful to Gulf Coast refiners. They could buy Canadian heavy crude closer to home instead of importing similar grades through longer, riskier routes. Asian refiners faced sharply higher freight and insurance costs. To compensate buyers for those costs, Canadian heavy crude prices weakened relative to WTI, widening the differential.

That discount reduced US refiners’ feedstock expense. Phillips 66 said each $1 widening in the WCS-WTI differential was worth about $140 million in gains. Executives expected wider differentials to remain supportive in the near term, with HF Sinclair seeing them stay wider at least through 2027.

US Gulf Coast refiners are especially well positioned because their facilities are built to process heavier crude. More than 70% of their facilities are configured for heavier crude, according to the article. This means discounted heavy grades from Canada and Venezuela fit the equipment and supply needs of many Gulf Coast plants.

The advantage grew during the tanker disruption. Canadian Western Canadian Select and other heavy grades became cheaper relative to WTI as freight costs rose. Gulf Coast refiners could source these barrels closer to home. Asian competitors faced higher freight, insurance, and route risks when importing similar crude through longer shipping lanes.

Their position also supported exports. Valero said higher freight rates gave it an advantage in typical Latin American markets, where it mainly competes with European barrels. Some refiners had also secured vessels before the conflict. Together, suitable refinery equipment, nearby supply, and planned shipping reduced costs and strengthened margins.

A time-charter agreement reserves a vessel for a set period at agreed terms. It can protect a shipper from having to hire a tanker immediately in the spot market when prices are unusually high. For refiners, that provides more predictable transport capacity and costs while moving crude or products.

Phillips 66 had secured more than 40 time-charter vessels before the Iran conflict. Those ships covered about 40% of its asset-based shipping needs. Valero, PBF, Marathon, and Canada’s Suncor also secured chartered fleets before the war began. Their arrangements reduced the amount of shipping they needed to obtain after tanker rates surged.

The protection was not total. Refiners still faced broader market disruption and higher costs on uncovered voyages. However, advance charters insulated part of their operations from the spot-rate jump. Combined with cheaper nearby heavy crude and stronger fuel margins, the arrangements helped keep US refiners profitable while Asian rivals faced greater shipping exposure.

Crude oil is the unprocessed petroleum feedstock bought by a refinery. Refined fuel is the set of usable products made from it, such as gasoline and diesel. A refining margin is the spread between the value of those products and the cost of crude and other operating expenses. It shows how profitable the conversion process can be. These definitions use standard industry usage; the article focuses on margins rather than explaining them.

A refinery heats and separates crude into different components, then processes those components into fuels with suitable properties. It can blend and sell the resulting products. Profit depends on buying crude cheaply, producing fuels that command strong prices, and controlling transport and operating costs. Heavy-crude discounts can therefore improve margins when a refinery is designed to handle those grades.

In this episode, US refining margins more than doubled in the third quarter. Freight costs rose, but stronger fuel margins more than offset them. Delia He said diesel margins grew by at least eight dollars for every extra dollar of freight, helping refiners remain profitable despite disrupted shipping.