Viewpoint: US crude flows to southeast Asia to grow

: Crude oil
19/12/27

Light sweet US crude volumes heading to southeast Asia are poised to increase in the coming year amid growing appetite for the grades from smaller refiners in the region, partly to comply with the International Maritime Organisation (IMO) 2020 regulations cutting sulphur in marine fuels.

Buyers are also eyeing US cargoes as they anticipate US light sweet crude prices on the US Gulf coast (USGC) to fall because of increasing supplies, with new pipelines that move crude from the Permian basin to the US export terminals boosting operations in 2020. But freight rates could be the wild card and could scupper US crude flows to Asia-Pacific, as sellers offering US cargoes on a delivered basis will raise prices to pass on to buyers the higher freight costs from IMO 2020 compliance.

WTI on a delivered northeast Asia basis fell below the price of light sour Abu Dhabi Murban crude on delivered northeast Asia basis several times in 2019, although a rise in freight rates late in the year lifted WTI to near parity to Murban on a delivered basis.

Refiners that currently buy US crude on a spot basis, such in those in Thailand, Singapore and Australia, often revert to short-haul supplies when rising freight costs curb the economics of taking long-haul cargoes. Lump-sum freight rates for very large crude carriers from the USGC to northeast Asia have already risen to $12.75mn compared with about $8mn in late September 2019.

Southeast Asia's refiners have increasingly turned to US crude in the past year in a bid to diversify supply sources as increasing tensions in the Middle East and the fallout from a protracted US-China trade war heightened the risk of supply disruptions. Demand for low-sulphur grades ahead of the IMO 2020 regulations and falling Asia-Pacific production of low-sulphur crude, especially from Australia and Vietnam, also drew arbitrage US cargoes to the region.

New buyers emerge

South Korea and Taiwan remain the main Asia-Pacific buyers of US crude, taking 395,000 b/d in October 2019 and 170,000 b/d during January-October 2019 respectively, with their import volumes likely to remain steady. But refiners such as Indonesia's state-owned Pertamina also emerged earlier this year as a US crude buyer for the first time. Pertamina has signed a deal to buy US term crude for 2020. It will receive from Total 950,000 bl of US WTI crude a month from February to June 2020 at its Cilacap port. Pertamina operates all of Indonesia's refineries and has typically bought Nigerian and Algerian light sweet grades to run at its plants along with domestic sweet crude.

Vietnam state-owned Binh Son Refining and Petrochemical has also signed a term deal to buy a total of 5mn bl of WTI crude for delivery to the 145,000 b/d Dung Quat refinery from January to May 2020. Dung Quat imported its first WTI crude cargo in May 2019 and bought another 2mn bl of WTI on the spot market for October and December 2019 delivery before the term deal.

Malaysia's state-owned Petronas bought Bakken crude for the first time for its new 300,000 b/d Pengerang refinery and petrochemicals complex in southern Malaysia. A 1mn bl Bakken cargo arrived at the refinery in mid-December 2019 with a similar size cargo due to arrive in mid-January 2020.

Other Asia-Pacific refiners are also potential US crude buyers. Sri Lankan state-controlled refiner Ceypetco issued a spot tender to buy WTI crude for the first time, for December 2019 delivery to its 50,000 b/d Kelaniya refinery, but it did not award the tender as surging freight rates pushed up offered prices. Ceypetco was likely looking at WTI as replacement for the light sour Murban volumes that it runs at Kelaniya.

Taiwan's private-sector refiner Formosa Petrochemical also issued a spot tender to buy US crude but decided not to award it because of high offers. Formosa had sought 1mn-2mn bl of crude to be delivered to Mailiao port from 20 February to 20 March in the tender. It listed WTI, Light Louisiana Sweet and medium sour Mars, Southern Green Canyon and Poseidon as acceptable grades. Formosa's only US crude purchase so far was a Mars cargo it took in late 2018.

US crude exports reached a record high of 3.38mn b/d in October as more pipelines have started service moving Permian crude to the USGC. The 670,000 b/d Cactus 2 pipeline and the 400,000 Epic crude line, moving crude to Corpus Christi, Texas increased operations from August 2019.

But exports are expected to rise further as the 900,000 b/d Gray Oak pipeline from the Permian basin to Corpus Christi hits full service. Phillips 66 started initial service at Gray Oak in November 2019 with full service on the line expected in the first quarter of 2020, which should provide Asia-Pacific refiners with even more WTI availability in the coming year.

By Yvette Choo

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24/11/05

Voting set to conclude in race for White House

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US railroad-labor contract talks heat up

24/11/04

US railroad-labor contract talks heat up

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Canada advances oil and gas GHG cap

24/11/04

Canada advances oil and gas GHG cap

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Mexico GDP outlook dims in October survey

24/11/04

Mexico GDP outlook dims in October survey

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Oil use still flat to 2030 in TotalEnergies scenarios

24/11/04

Oil use still flat to 2030 in TotalEnergies scenarios

Edinburgh, 4 November (Argus) — TotalEnergies continues to see oil demand plateauing until 2030, and then to decrease slower than natural field decline even in a scenario limiting global warming below 2°C. In its annual energy outlook released today, TotalEnergies updated two different scenarios for energy demand to 2050. The 'Momentum' scenario assumes countries with 2050 net zero targets reach their goals and China hits its 2060 target, with low carbon energy meeting half of developing countries' needs. It has temperature rising by 2.2-2.3°C by 2100, compared with 2.1-2.2°C in the same timeframe last year. The Paris climate agreement seeks to limit global warming to "well below" 2°C above the pre-industrial average and preferably to 1.5°C. "In this scenario, fossil fuels still cover half of the growth in energy demand in the Global South, due to insufficient low-carbon investment," TotalEnergies said. The 'Rupture' scenario assumes global co-operation supports net-zero development in India and developing countries, with energy demand growth met by low-carbon energies and efficiency gains. It has temperature rising by 1.7-1.8°C in 2100, unchanged from last year. "Beyond 2040, all decarbonisation levers are applied globally, in particular the deployment of new energies and carbon capture, use and storage (CCUS)," TotalEnergies said. TotalEnergies still sees oil demand plateauing until 2030 in Momentum and Rupture, reaching around 70mn b/d in the former and 44mn b/d in the latter in 2050. This compares with 63mn b/d in the Momentum scenario and 41mn b/d in the Rupture scenario by 2050 in last year's report. Around 25pc of oil demand stems from the petrochemical sector in 2025 in the Rupture scenario, according to the firm. Oil demand starts decreasing around 2035 in Momentum, but slower than the 4-5pc natural decline of existing fields, requiring new developments. It decreases faster in Rupture — by 3.9pc per year over 2030-50 — but still more slowly than natural decline, the firm said. In the Rupture scenario, the aviation and shipping sector need sustainable liquid fuel supply to rise four-fold compared with today. But a higher EV penetration rate in this scenario reduces biofuels requirements for road transportation, freeing up more supply for aviation and shipping, according to the firm. By Caroline Varin Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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