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Syria issues crude, products tenders: Correction

  • : Crude oil, LPG, Oil products
  • 25/01/30

Corrects quality of gasoil sought in paragraph 4, from 10ppm to 50ppm. This story was originally published on 22 January

The new administration in Syria has issued its first tenders to buy crude and refined products since the fall of Bashar al-Assad's regime in December, as acute fuel shortages continue to cause lengthy blackouts in the country.

Tenders seeking 3mn bl of light crude for the 140,000 Banias refinery and 1.2mn bl of heavy crude for the 110,100 b/d Homs refinery close for bidding on 27 January. They have a 10pc flexibility either way on the volumes.

The Banias refinery is undergoing maintenance at several of its production units after being taken offline last month because of a lack of crude feedstock.

Syria's new administration has also issued its first import tender for refined products — 80,000t of 90 Ron gasoline, 100,000t of 50ppm sulphur gasoil and 100,000t of fuel oil — commencing as soon as possible for delivery over a 30-day period. Offers must be delivered by hand to the oil ministry in Damascus by 14:30 local time on 27 January.

A tender seeking 66,000t of LPG has been issued as well. A previous tender for 20,000t of LPG was awarded at mid-teen $/t premiums to fob Lavera west Mediterranean prices.

Before Assad was toppled, Syria relied heavily on Iran for its oil supplies, as international sanctions imposed in the wake of the 2011 civil war left the country critically short of feedstock for its refineries. Iran's crude exports to Syria averaged around 55,000 b/d in January-November 2024 and around 80,000 b/d in 2023, according to trade analytics firm Kpler. Iran was also sending around 10,000-20,000 b/d of oil products to Syria in recent years, according to consultancy FGE.

But Tehran has halted crude deliveries to Syria since the Islamist group Hayat Tahrir al-Sham took control last month, leaving the new transitional government under pressure to find alternative suppliers. Government-to-government deals are a potential option.

"Recent political developments have indicated that Qatar, Saudi Arabia and Turkey could play a role in solving Syria's crude and refined products shortage," FGE analyst Palash Jain said.

Saudi Arabia is willing to help for a limited period, but discussions remain in a preliminary phase and are light on details, a source with knowledge of the matter told Argus. Riyadh is waiting to hear more from the Syrians on their energy needs and requirements, the source added.

The latest tenders come just two weeks after the US waived sanctions that had previously prohibited energy trade with Syria. The waiver, issued on 6 January, is valid until 7 July.


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25/03/03

German diesel demand rises with farming activity

German diesel demand rises with farming activity

Hamburg, 3 March (Argus) — Consumer diesel demand increased in the week ending 28 February, with higher consumption from the agricultural sector and stable filling station demand. Rising temperatures dampened heating oil sales. Sellers in agricultural regions reported rising diesel demand. Farmers have been able to spread manure since early February and are now tilling their fields again. Traded diesel spot volumes reported to Argus rose by almost 25pc week on week. Volumes increased by 74pc in Emsland, an especially farming-heavy area in northwest Germany. Stable demand at filling stations has also been supporting overall demand, traders said. Current school holidays in two German states, and holidays starting in Bavaria today, are further supporting demand from filling station operators. Spot gasoline sales remained little changed from the previous week, with an increase of 3pc. The situation is different for heating oil, with many traders reporting that rising temperatures across Germany are noticeably dampening demand for the product. The nationwide average price reductions for heating oil compared with the week ending 21 February have not stimulated buying interest. Traded heating oil spot volumes fell by 16pc. Maintenance work that began on 2 March at the 125,000 b/d Vohburg plant of the Bayernoil refinery, and the closure of the 147,000 b/d Wesseling plant at Shell's Rheinland refinery from mid-March, could reduce supply in the coming weeks. By Johannes Guhlke Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Looming tariff war adds to US refiner headwinds


25/03/03
25/03/03

Looming tariff war adds to US refiner headwinds

Houston, 3 March (Argus) — US independent refiners, already facing weaker margins, falling demand and regulatory uncertainty in their burgeoning renewables businesses, are braced for another imminent headwind from US tariffs. The US may impose a 10pc tariff on energy from Canada and a 25pc tariff on all imports from Mexico starting on 4 March. Refiners are scrambling to find alternative supplies, including switching to lighter crude slates, but this will come at a cost. Although short-term margins are due to improve with refinery closures and maintenance, a sustained tariff war could add another long-term problem. The potential tariffs come as US independent refiners including Marathon Petroleum, Valero and Phillips 66 are coming out of a rough fourth-quarter earnings season, with lower margins cutting into profits year on year. The tariffs have already caused problems in North American oil markets as trading desks struggle to understand how they would work in practice and some buyers hold off from committing to taking March cargoes until details are clarified. But one thing is becoming clear — tariffs will lead to higher feedstock costs and will cause some refiners to reduce runs, cutting further into profits. US independent refiner PBF Energy chief executive Matthew Lucey says tariffs on Canadian crude would cause US midcontinent refineries to cut throughputs, even if they find alternative crudes. Marathon Petroleum, the largest US refiner by volume, says it could pivot some of its midcontinent refineries to run domestic crude slates such as Bakken from North Dakota and Montana, crude from the Rockies, or crude from the Utica and Marcellus shale regions in the northeast US. Tariffs would lead to price increases, but most of it "will ultimately be borne by the producer" and to a lesser extent the consumer, Marathon chief executive Maryann Mannen predicts. Smaller refiner HF Sinclair also says it could switch to alternative, lighter crudes at its refineries if tariffs are implemented. Several refiners agree with Marathon that producers would bear the brunt of the tariff costs, but the impact on oil prices will have repercussions throughout the industry. US bank TD Cowen expects US refiners that run Canadian crude on the margin to switch to light sweet crude, increasing WTI and Brent prices. Meanwhile, inland refiners that run Canadian crude as a core part of their slate are likely to continue to do so, the bank says. Phillips 66's executive vice-president of commercial Brian Mandell agrees with that assessment, saying that Western Canadian crude will continue to flow to US refiners, but at a greater discount. Sour taste Meanwhile, US Gulf coast refiners will be likely to replace Mexican and Canadian heavy crude with crude from other heavy sour producers such as Iraq, TD Cowen says. The switching will be likely to tighten medium and heavy sour differentials already tight from Opec+ curtailments and US sanctions against Russia. If it becomes too expensive to switch to heavy sour crudes, refiners could run less-efficient crude slates, reducing product supplied. Despite the headwinds, US refiners have expressed optimism that margins will improve in 2025 as a result of a heavy spring maintenance season and expected capacity closures. Two large US refineries are shutting down this year — LyondellBasell's 264,000 b/d Houston, Texas, refinery is in the process of closing, and Phillips 66's 139,000 b/d Los Angeles refinery is planned to be shut by the end of the year. Marathon says it expects the US refining industry to remain structurally advantaged over the rest of the world in the long term "mainly due to the availability of low-cost energy". But US tariffs — and the increase in prices that is likely to follow — could challenge that notion. By Eunice Bridges Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Brazil’s new Atlanta FPSO exports first crude cargo


25/03/03
25/03/03

Brazil’s new Atlanta FPSO exports first crude cargo

Singapore, 3 March (Argus) — Brazil's newly commissioned Atlanta floating, production, storage and offloading (FPSO) unit has loaded its first cargo of Atlanta crude aboard the Sonangol Namibe in end-February, data from global trade analytics platform Kpler show. This marks the unit's first shipment since achieving first oil in late 2024. Trading firm Trafigura is likely the charterer of the vessel, according to Kpler data. Brava Energia previously announced in February that it sold 6mn bl of oil from its Atlanta field to Singapore-based commodity trader Trafigura. The contract's price is linked to Singapore VLSFO benchmark prices. But the specific price could not be confirmed. Atlanta crude is classified as a heavy sweet crude and is primarily exported to the Singapore straits region, where it is highly valued for very-low-sulphur fuel oil (VLSFO) blending because of its low sulphur content and relatively heavy API content of about 14-16. The FPSO Atlanta unit is operated by independent producer Brava Energia, a Brazilian oil and gas firm created from the merger of oil companies 3R Petroleum and Enauta, with the FPSO chartered from Malaysia's Yinson Production. The unit operates in the Atlanta field in the Santos Basin offshore Brazil, and achieved first oil on 31 December 2024, according to Yinson. Heavy sweet Atlanta crude oil was previously produced from the Petrojarl I FPSO, which was decommissioned in late 2024. This is in line with the last observed export of Atlanta crude in early November, with no shipments recorded until the latest loading in February, according to data from Kpler. The newer Atlanta FPSO can process up to 50,000 b/d of oil, 70pc higher compared to the Petrojarl I, and has a storage capacity of 1.2mn bl, more than a sixfold increase, according to a document from Yinson. This latest development is likely to further pressure the Asian VLSFO market, which is already grappling with ample supplies in Singapore that have weighed on prices. Increased supplies from Brazil, Kuwait's KPC and Nigeria's Dangote are expected to discharge in the region this month, with March arrivals forecast to be over 1mn t higher than in February. But the latest shipment will likely spill over into April's supply and demand balance, given the typical 45–60 day voyage from Brazil to Singapore. By Asill Bardh Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Ecuador awards Sacha field to Sinopec, Petrolia


25/03/02
25/03/02

Ecuador awards Sacha field to Sinopec, Petrolia

Quito, 2 March (Argus) — Ecuador will transfer operation of its highest-producing oil field, the 74,600 b/d Sacha, to a consortium of China's Sinopec and Canada-based Petrolia under a production-sharing contract aimed at increasing output, the energy ministry said today. The consortium, in which Sinopec as operators hold a 60pc share and Petrolia the remainder, committed to investing $1.7bn in the next six year to reach peak production of 100,000 b/d by 2028, up by 33pc compared with current output. State-owned Petroecuador currently operates the field in block 60 in the Orellana province in the Amazonian region. Energy minister Ines Manzano authorized the deal through a resolution, and vice minister of hydrocarbons Guilhermo Ferreira was charged with signing the 20-year contract. Most terms have already been negotiated and final signature should not take more than a few weeks, the ministry said. The consortium had proposed keeping from 80pc-87.5pc of production, depending on the price of WTI crude, Petrolia's general manager Ramiro Paez previously told Argus . If the WTI price is below $30/bl, the consortium will take 87.5pc of the production. But its production sharing will decrease on a sliding scale to a minimum of 80pc when the WTI price is $120/bl or above. Ecuador's government will keep 80pc of profits, when taxes and other fees are taken into account, the consortium has said. Transitioning operations from Petroecuador to Sinopec will take about six months, said Paez. Opposing forces Ecuador's oil workers' unions have rejected the plan as unconstitutional because it passes control of the field from the state-owned company, as have opposition legislators with the citizens' revolution party that holds a majority in congress. The deal will cost Ecuador's government $8bn, the party claims. They also complained that the government announced the decision at the start of a holiday weekend. Manzano defended the deal as constitutional as the hydrocarbons law allows the government to delegate crude field operations. The energy ministry will provide additional details about the deal on 5 March after the 3-4 March holiday for Carnival. From 1-27 February 2025, Sacha produced an average of 74,680 b/d, down by 4pc compared with 77,884 b/d in February 2024, according to the data published by the hydrocarbons regulatory agency (Arch) and Petroecuador. Ecuador produced 474,860 b/d in January. By Alberto Araujo Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Weak Canadian dollar may offset US tariffs: MEG


25/02/28
25/02/28

Weak Canadian dollar may offset US tariffs: MEG

Calgary, 28 February (Argus) — The impact of the US' planned 10pc tariff on Canadian energy imports is likely to be "relatively muted" with a weaker Canadian dollar helping to cushion the impacts on US dollar-denominated Western Canadian Select crude, according to Canada's largest pure-play oil sands producer today. "You might see a $2-4/bl widening in the WCS diff, but we're also seeing a weakening in the Canadian dollar at the same time. That's going to offset that," MEG Energy chief financial officer Ryan Kubik told analysts. The Canadian dollar, on average, was worth C$1.37 to the US dollar in 2024, weakening from C$1.35 to the greenback in 2023 and the weakest since 2003, according to the Bank of Canada. The Canadian dollar has since depreciated further to C$1.43 to the US dollar in February, a benefit to Canadian producers selling crude in US dollars. Heavy sour Western Canadian Select (WCS) in Alberta was under pressure in early February when tariffs looked likely, but were subsequently postponed to 4 March. WCS trades at a discount to the US light sweet benchmark and this week has been hovering around a $13/bl discount, roughly $2/bl narrower than before the tariff threat nearly one month ago. US president Donald Trump said he plans to impose a 10pc tariff on energy, and a 25pc tariff on all other imports from Canada, next week. That has caused confusion for the market with little details on how it would work. Additionally, it is unclear who may bear the brunt of the added tax, but Canadian producers seem likely to share in that cost along with refiners and consumers, to a varying degree. Kubik discussed the prospect of hedging more volumes at current WCS prices, but said participants are limited by the "very illiquid" nature of the market. "There's not a lot of appetite to get out there and put a position on because it's just not that meaningful," said Kubik. "And when you consider the impact of tariffs, we actually think it may be relatively muted." For the moment, most of the volume moving westbound on the 890,000 b/d Trans Mountain system, which enables Canadian producers to bypass the US entirely by exporting to the Pacific Rim, is on existing contracts, according to MEG's senior vice president of marketing Erik Alson. "I think where you're likely to see spot shipments moving would be more around the time when, if, tariffs come into effect," said Alson. "That's when you'd see the extra incentive to move a significant amount of spot capacity." MEG is a committed shipper on TMX but also routes crude through the US Gulf coast, and more than half of MEG's sales could be non-tariffed, depending on the details in the executive order. MEG reported Friday its bitumen output fell to 100,100 b/d in the fourth quarter , down from 109,100 b/d in the fourth quarter of 2023. The Calgary-based company posted a profit of C$106mn ($73mn) in the fourth quarter, up from C$103mn in the fourth quarter of 2023. By Brett Holmes Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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