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Viewpoint: India bitumen demand growth prospects mixed

  • Spanish Market: Oil products
  • 03/01/25

Prospects of India's 2025 bitumen consumption growth are mixed, as state governments' delayed disbursement of project funds are likely to persist and weigh on demand while the many incomplete projects could boost consumption.

India is a net bitumen importer and the biggest consumer of Middle East origin bitumen, especially from Iran. India's bitumen consumption had touched record highs in 2022 and 2023 and surpassed 8mn t/yr, despite prolonged payment delays, as importers had offered atypically longer credit terms to road contractors.

All importers and traders are "struggling with payment recovery", an Indian importer said. Many contractors are demanding credit as several state governments have not released funds, the importer added. "Demand is not bad, but it really depends on funding. Demand won't increase by a lot [next year], but it should be quite stable [to 2024]."

High inventory pressure forced importers to offer atypically bigger discounts to liquidate cargoes, which squeezed their profit margins, especially as import costs increased given a supply crunch in Iran. But there is no dearth of projects as many were delayed because of funding constrains, importers said.

Some state-controlled refiners anticipate consumption to grow next year, albeit marginally. Refiners were previously forced to offer larger discounts against listed values to attract more customers, which weighed on their profit margins this year. This could continue into 2025 would ultimately pressure refiners to reduce bitumen output and increase production of other higher valued oil products. Indian refiners typically produce around 5mn t/yr, which accounts for around 55-60pc of total bitumen consumption.

"We are only expecting a 3-4pc increase in demand on year as no new major road projects have been announced, so it is hard to see a larger growth," a source close to a state-refiner said. "But imports will increase if we reduce production, given growth will still be in [the] positive. So next year will not be that fantastic in comparison and there would not be any capacity augmentation for bitumen."

This indicates that the central government's expectation that Indian bitumen consumption will rise by 14pc on the year to 10mn t during the ongoing financial year ending March 2025 could be at risk.

Limited Middle East exports

Vacuum bottom feedstock supply has been erratic in Iran, and feedstock transportation from national refineries to private bitumen producers has also been delayed this year, which market participants expect to persist in the coming year. This will limit feedstock availability and in turn bitumen output, increasing export cost especially for higher priced VG40 grade, which is imported by India.

Tight supply has also increased congestions at the Bandar Abbas port, forcing vessel owners and importers to incur higher demurrage, increasing costs and weighing on import appetite. There are also fears that the new Trump administration may impose more sanctions and other political measures on Iran next year, further clouding the export outlook.

Iranian central bank's recent announcement to phase out the Nima foreign exchange platform has increased uncertainty on the rials' value against the US dollar as importers and exporters will now have to trade based on mutually agreed exchange rates, with the free market rate still depressed.

Meanwhile, Baghdad's recent directive to stop oil and other oil products from entering Iran, unless the exports are licensed by state-owned Somo, could also limit drummed bitumen exports as bitumen producers do not typically possess a Somo licence. Iraqi drums are generally transshipped out of Bandar Abbas.

The recent upgrade of Bahrain's state-owned Sitra refinery to 380,000 b/d from 267,000 b/d will primarily boost middle distillate and naphtha output, weighing on bitumen production.

Middle East cargoes are also typically exported to southeast and east Asia during low demand periods in India. Seaborne prices in Asia rose to multi-year highs in 2022 and import appetite for relatively cheaper Middle East-origin bulk cargoes increased, which continued in 2023. Appetite from Asia this year was mostly from China and Vietnam, as other buyers preferred Asia-origin cargoes because of compatible specifications and proximity.

"The Middle East-Asia arbitrage is closed, and we will see very little-to-no cargoes from the UAE to Asia," a southeast Asia-based trader said. This is because Middle East-origin cargo cfr prices are not likely to be competitive to Asian cargoes, with supply and loading constraints in Iran adding to the uncertainties.


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06/03/25

Iraq eyes gasoil imports to alleviate power shortage

Iraq eyes gasoil imports to alleviate power shortage

Dubai, 6 March (Argus) — Iraq's electricity ministry has asked the government to raise gasoil imports as a precautionary measure to ensure the country has enough fuel for power generation head of the peak demand summer months. The request is pending the oil ministry's approval. If authorised, Iraq's gasoil imports could shortly ramp up to 100,000 b/d, almost three times the 35,000 b/d that was imported last month, the oil ministry told Argus . Iraq typically relies on imported natural gas from Iran to generate electricity for its national grid. But Tehran cut gas supplies to its western neighbour in the last quarter of 2024 because of its own power shortages. Insufficient gas from Iran forced Iraqi power plants to switch to burning gasoil, while private consumers generated power from diesel-run units, further exacerbating fuel shortages. Iraq's power generation shortage could soon become more acute as gas imports from Iran are at risk of stopping completely. The waivers that allow Iraq to import Iranian electricity and gas without falling foul of US sanctions are unlikely to be renewed given President Donald Trump's "maximum pressure" policy against Tehran. The latest 120-day waiver is due to expire on 7 March. Meanwhile, Iraq's domestic gasoil production is being curtailed by constraints on crude supply to refineries. Baghdad's commitment to rein in crude production to compensate for past breaches of its Opec+ target has cut available supply for domestic refineries, lowering oil product output, the oil ministry said. Iraq is seeking to address its electricity issues by looking for investment for new power generation infrastructure. The country plans to build new steam and gas plants that could produce up to 35,000MW of electricity, which would bridge the gap between current electricity supply and demand. Baghdad has approached international engineering companies including GE and Siemens to partner in these projects, according to electricity minister Ahmed Moussa, but the government has not disclosed a clear timeline for implementation. By Ieva Paldaviciute and Bachar Halabi Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

UK govt consults on ‘clean energy future’ for North Sea


05/03/25
05/03/25

UK govt consults on ‘clean energy future’ for North Sea

London, 5 March (Argus) — The UK government has launched a consultation on the North Sea's "clean energy future", seeking to balance "continued demand for oil and gas" with the natural decline of the North Sea basin, the country's energy security and climate science. The government has proposed an end to new onshore oil and gas licences in England — as onshore licensing is a devolved matter — and once again confirmed its manifesto pledge for no new oil or gas licences for North Sea exploration. It also confirmed a previous commitment to end the so-called windfall tax on oil and gas producers in 2030. Further oil and gas licences "would not meaningfully increase UK production levels, nor would they change the UK's status as a net importer of oil and gas", the government said. It flagged the North Sea basin's maturity, which means that an absence of new licences makes only "a marginal overall difference to future North Sea production". The "vast majority of future production is expected to come from producing fields or fields already being developed on existing licences", the government said. It noted that while offshore licensing rounds have resulted in up to 100 permits each time, under 10pc of recently issued licences "have progressed to active production". But its halt on new exploration licences would not preclude any licence extensions being granted, the government said. It aims to provide "certainty to industry about the lifespan of oil and gas projects by committing to maintain existing fields for their lifetime". The decision does not affect the issuing of new gas or carbon storage licences, it added. Focus on 1.5°C The consultation also doubles down on the government's previous commitments to "clean power" by 2030 — which would entail a small role for gas-fired power generation, of under 5pc — and its determination to be a leader in climate action. "The science is clear that the world needs to take urgent action and that current plans for global production of oil and gas are not compatible with limiting global warming to 1.5°C," the government said. The Paris climate agreement seeks to limit global warming to "well below" 2°C above pre-industrial levels and preferably to 1.5°C. The government has requested views on its plans to ensure a "prosperous and sustainable transition for oil and gas" and to make the UK a "clean energy superpower", focused on technologies such as offshore wind, hydrogen and carbon capture, use and storage (CCUS). This will boost the UK's economy and energy security, the government said. "Clean energy" is key for energy security, as a reliance on fossil fuels leaves the UK at "the mercy of global energy markets", it added. "CCUS will be a critical component of the UK's energy transition," the government said. It also noted the geological advantage the UK holds for CO2 storage. There is "significant potential for CO2 import", likely from Europe, it said. The government has also sought extensive feedback on the transition for the country's oil and gas workforce. An "offshore renewables workforce" could stand at between 70,000 and 138,000 in 2030, it said, while oil and gas jobs are set to decrease, alongside the North Sea's fossil fuel production. Today's consultation will close on 30 April. And the government will publish its final guidance on an updated environmental framework for oil and gas "in good time", it said. By Georgia Gratton Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Vietnam's bitumen imports from Middle East rise in 2024


05/03/25
05/03/25

Vietnam's bitumen imports from Middle East rise in 2024

Mumbai, 5 March (Argus) — Vietnam's bitumen imports from the Middle East surged in 2024 because of competitive offers against Asian cargoes. Overall imports rose on the year, supported by increased demand from unfinished projects. Vietnam, a net importer of the road paving material, imported 1.14mn t of bitumen in 2024, up by 10pc from 1.04mn t in 2023, GTT data show. Imports from the Middle East totalled 382,000t, up by 49pc on the year, the data show. The rise in imports can be directly attributed to the increase in the number of ongoing projects in the second half of 2024, especially highways, some market participants said. "[But] price factor at the moment is what is determining the trade flows and where the imports are coming from," a Vietnamese importer said. Argus- assessed fob Iran bulk bitumen cargoes traded at a discount of $131/t on an average to fob Singapore ABX 1 in 2024. The discounts widened to as high as around $160-180/t in August-October, when tight supply caused by production cuts kept Singapore seaborne prices elevated. The freight cost between the Middle East and Vietnam was estimated at around $120/t, according to some market participants. But prolonged inclement weather in Vietnam weighed on consumption until the last quarter of 2024, which prevented the domestic selling prices from increasing. This pushed Vietnamese importers to seek relatively cheaper Middle East origin cargoes in 2024. Importers did not have any reason to seek cargoes from other sources unless they needed certain specifications, an importer said, indicating that importers sought Asia-origin cargoes only for projects with specific requirements. Imports from Singapore totalled 383,000t in 2024, up by 13pc from 2023, GTT data show. But imports from China and South Korea fell on the year by 44pc and 60pc respectively. Seaborne prices and freight costs from China and South Korea to Vietnam were also relatively higher, further weighing on imports from those origins, some importers said. Meanwhile, market participants expect consumption to be stable to high in 2025 compared with 2024 because of pent-up demand. Imports are anticipated to be in the 1mn-1.3mn t range. Disbursement of project funds have also relatively improved, which will encourage contractors to accelerate road works, a Singapore-based trader said. The inter-regional price arbitrage between Singapore and the Middle East was not open as Middle East-origin bulk cargoes were trading at a discount of only about $100/t to ABX 1. But the price gap is expected to widen in the coming months and more shipments from the Middle East will enter the region, importers said. By Sathya Narayanan and Chloe Choo Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Indonesia plans to build new 500,000 b/d oil refinery


05/03/25
05/03/25

Indonesia plans to build new 500,000 b/d oil refinery

Singapore, 5 March (Argus) — Indonesia plans to build an oil refinery with a planned capacity of approximately 500,000 b/d, as part of the country's push to develop its downstream sectors to ensure energy security. The refinery will be able to process domestic and imported crude oil, and will produce up to about 532,000 b/d of various oil products, according to the ministry of energy and mineral resources (ESDM). The construction of the refinery will require investments of up to $12.5bn, and it will help to reduce Indonesia's dependence on imports, said the ESDM. No details on timeline or location were provided. It is unclear how the new refinery fits with Indonesia's existing downstream expansion plans, many of which have stalled. The country has not built a new refinery since 1994, leaving it reliant on imports to meet demand for oil products, notably gasoline. Several new projects have been touted in recent years, including a joint venture between state-owned Pertamina and Russian firm Rosneft for a 300,000 b/d refinery and petrochemical plant at Tuban in east Java, but have yet to reach a final investment decision. The country's president Prabowo Subianto has set a target for reviving Indonesia's oil output to 900,000-1mn b/d by 2028-29. "We still have a lot of oil," said energy minister Bahlil Lahadalia last month, encouraging the use of enhanced oil recovery and urging exploration wells to be upgraded to production wells. The country's oil production currently stands at around 600,000 b/d , with state-owned refiner Pertamina accounting for 400,000 b/d of this, while the country's consumption amounts to more than 1.5mn b/d. Developing DME Another downstream initiative that the ESDM is planning is the acceleration of the development of dimethyl ether (DME) through coal gasification, to use it as a substitute for LPG and reduce imports. The development of the DME industry will "no longer depend on foreign investors," said Bahlil, adding that it will instead rely on domestic resources and capital, "which will be implemented through government policies." Indonesia already has the raw materials as well as the offtakers, while the technology, money and capital expenditure can all come from the government and domestic private sector, said Bahlil, so Indonesia does not have to be "dependent on other parties." Indonesia has agreed to provide $40bn worth of funding to 21 first-phase downstream projects. By Prethika Nair Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

US tariffs prompt Canada to eye Europe's diesel market


04/03/25
04/03/25

US tariffs prompt Canada to eye Europe's diesel market

London, 4 March (Argus) — Washington's 10pc tariff on energy imports from Canada has prompted Canadian refiners to consider selling diesel to Europe, according to a source with knowledge of the matter. The 10pc tariff came into effect on 4 March, alongside 25pc tariffs on non-energy imports from Canada and 25pc tariffs on all goods from Mexico. Some market participants suggest the need to adjust Canadian diesel quality could hinder exports to Europe. Canadian specifications are more lax than EU specifications in some respects, but comparable challenges are overcome as a matter of routine when the EU imports from the US. Canada exported 350,000t of diesel and other gasoil to Europe in 2024, according to Vortexa. This accounted for 8pc of the country's total exports, whereas 73pc went to the US. European market participants note that US importers could look to Europe to replace Canadian gasoline — but price signals are muddied by a seasonal shift in specifications this week. Front-month Nymex Rbob futures surged to a $10.47/bl premium to Eurobob oxy barges on 3 March, from only 77¢/bl on 28 February, but this largely reflects the switch to stricter evaporability rules. Canada is the primary supplier of seaborne gasoline and diesel to the US — especially to the Atlantic coast. Cargoes loading from US Gulf coast refiners are disadvantaged competitively by the Jones Act, which puts strenuous rules around the vessels that can transport cargoes from one US port to another. One indirect impact on European product markets could follow if US Gulf coast refineries cut crude runs in response to higher prices for Mexican and Canadian crude. Valero and PBF have both indicated they would consider run cuts. If the US Gulf coast refined less crude, European traders would likely find stronger arbitrage economics to export gasoline to the US but a weaker arbitrage to import diesel from the US. By Benedict George, George Maher-Bonnet and Josh Michalowski Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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