Latest market news

Tanker supply running thin: Panel

  • Market: Biofuels, Crude oil, Oil products
  • 26/06/24

The global tanker fleet may be unable to effectively keep pace with demand in the coming years as few new oil tankers are being built while crude demand is expected to rise, according to a panel of shipowners at the Marine Money convention in New York.

The construction of commercial vessels takes years to complete, and most shipyards around the world are booked well into the late 2020's building containerships ordered during the height of the Covid-19 pandemic, when port congestion combined with a rise in consumer purchasing to skyrocket container freight rates.

"We're looking at a low orderbook stretching into 2028 through 2029, and by 2031 by normal metrics, we need a lot of replacement in tankers," shipowner Frontline's chief executive Lars Barstad said. "Unless we can gradually reduce oil consumption, we have a structural problem here."

The Covid-19 lockdowns also contributed to a drop in operational shipyards in countries like South Korea in the post-pandemic landscape.

"We don't have half the building capacity we had in 2011," Barstad said.

Asked by moderator Omar Nokta from research firm Jefferies if any meaningful amount of capacity was set to come online from shipyards looking to capitalize on the high price of newbuilds, all the shipowners on the panel responded with an emphatic "no".

The aging global tanker fleet will struggle to meet demand if newbuilds remain low, shipowner Hafnia chief executive Mikael Skov said.

"We still see [oil] growth ahead of us," Skov said. "My biggest worry is we're going to run out of tankers too soon."

Slow fleet replenishment amid limited shipyard availability and high costs is being compounded by indecision among shipowners on what kind of vessels to purchase. Concerns of building up a fleet centered on one of the potential next-generation propulsion fuels, like ammonia, and winding up with a stranded asset once another fuel becomes the new industry standard is keeping many shipowners wary of investing too early, even as the time available to receive delivery of a newbuild within this decade begins to wind down.

"Unfortunately, at least for the next generation of ships, the fuel of the future is probably fuel oil," shipowner Ardmore chief executive Anthony Gurnee said. "There are technological issues with ammonia. We have to be realistic about that."

"What we think is very actionable today is both technical and operational fuel efficiency utilizing conventional fuel with some kind of a dual fuel component," Gurnee said.


Sharelinkedin-sharetwitter-sharefacebook-shareemail-share

Related news posts

Argus illuminates the markets by putting a lens on the areas that matter most to you. The market news and commentary we publish reveals vital insights that enable you to make stronger, well-informed decisions. Explore a selection of news stories related to this one.

News
30/12/24

Viewpoint: European diesel to stay under pressure

Viewpoint: European diesel to stay under pressure

London, 30 December (Argus) — The European diesel market appears to be in a period of transition defined by economic headwinds, a decline in structural demand and anticipated refinery closures in the new year. These factors are exerting downward pressure on diesel refining margins, with the IEA forecasting no return to the high margin environment experienced immediately after the Covid-19 pandemic. Margins in Europe have been trending downwards in 2024 to below $17/bl, lower by a third from $28.53/bl in 2023 and less than half the heady levels of $37.27/bl in 2022. The economic rebound experienced in the immediate aftermath of the pandemic bequeathed a high inflationary environment, and this became a significant headwind in Europe going into 2024. Central banks tightened monetary policy to counteract this, dampening economic activity and as a consequence demand for diesel, the primary fuel grade powering transport fleets, construction equipment and manufacturing. European demand has been notably lacklustre. The largest economies in the region, Germany and France, saw diesel consumption decline by 4pc and 3pc respectively in 2024, according to the most recent published data. The former's loss of cheap Russian gas has undermined its economic model, which appears to have had a structural effect on national diesel demand. Any improvement in European economic fortunes in 2025 will likely provide a tailwind for outright diesel values. Driving issues Europe is also experiencing a systemic decline in diesel vehicle usage as electric and hybrid vehicles take up an ever increasing share. Newly-registered diesel passenger vehicles made up 14.9pc of the German market and 6.1pc of the UK market in November, according to SMMT and KBA data, compared with 31.6pc and 45.8pc for pure gasoline vehicles. New hybrid vehicles claimed a 38.7pc market share in Germany. Delays to outright national bans on new diesel or gasoline vehicle sales may stem the decline in popularity for diesel vehicles, but the trend is unlikely to be reversed. European refinery closures could serve to rebalance the market next year. Petroineos' 150,000 b/d Grangemouth refinery in Scotland will become an import terminal. In Germany, Shell will cease crude processing at its 147,000 b/d Wesseling refinery and BP plans to permanently shut down a crude unit and a middle distillate desulphurisation unit at its 257,000 b/d Gelsenkirchen plant. The degree to which these capacity losses are baked into market pricing is debatable, as the refiners could decide to delay closures in the event that diesel margins recover. But the limited effect of recent unscheduled refinery outages in the Mediterranean region illustrates how Europe can bear to lose two crude units, at least in the short term. In 2025, European diesel prices may again take direction from developments outside the region, particularly the profitability of key arbitrage routes from the US Gulf coast, the Mideast Gulf and India. European diesel values and margins were affected by refinery turnarounds in supplier regions in 2024. Prices may come under further pressure in 2025 from the start of 10ppm diesel production this month at Nigeria's 650,000 b/d Dangote refinery, which could completely offset the loss in European refining capacity. Any easing in Yemen-based Houthi militant aggression in the Red Sea may encourage diesel cargoes back through the Suez Canal, cutting down delivery times and weighing on supply volatility. Price-supportive developments may come from the EU tightening sanctions on Russia's 'dark fleet', which could weigh on global supply, and an upcoming US refinery maintenance season that is is touted to be disruptive. Two US refineries will close in 2025. By George Maher-Bonnett Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Find out more
News

Viewpoint: Consolidation looms in US methanol


27/12/24
News
27/12/24

Viewpoint: Consolidation looms in US methanol

Houston, 27 December (Argus) — The sale of Netherlands-based OCI's methanol production assets to rival producer Methanex is set to shift the market, with US methanol production most affected by the move. Methanex in the third quarter of 2024 announced the $2bn acquisition, which is expected to close in the first half of 2025. The boards of directors of both companies and OCI's shareholders approved the transaction, but it is subject to regulatory approvals. OCI operates the 1mn t/yr OCI Beaumont plant and is a 50:50 partner in Natgasoline, a 1.7mn t/yr joint-venture plant between OCI and Proman. Methanex operates three plants in the US, all in Geismar, Louisiana. These plants carry a collective 4mn t/yr capacity and represent one-third of total US methanol capacity. At front and center of the acquisition is the Natgasoline plant in Beaumont. Natgasoline, when operational, represents 14pc of domestic production. The plant opened in 2018, and throughout those six years, the plant has seen its share of operational issues. The most recent was a fire at the reformer unit in early October, resulting in a complete shutdown lasting nearly three months. When the deal was announced, Methanex made it clear that the transaction was subject to approvals by OCI shareholders, as well as a pending legal decision between OCI and Proman. "If it is not settled within a certain period, Methanex has the option to carve out the purchase of the Natgasoline joint venture and close only on the remainder of the transaction," the company said in September. Methanex and OCI declined to give further details, as the deal is still pending. Proman did not respond to a request for comment. If it goes through, the acquisition would result in the exodus of OCI from the US methanol market. But the issue of liquidity in the US spot barge market is also looming. Market participants said OCI is a frequent buyer when the Natgasoline plant goes down. In October, when Natgasoline was completely shut down, 340,000 bl of methanol moved for delivery at ITC, the terminal on the Houston Ship Channel where methanol is exchanged, according to Argus data. Market participants expect liquidity to be about the same until some time after the deal closes. When a plant goes down, a producer will emerge in the spot market for purchases. In the longer term, there are some questions around international distribution and where US methanol exports find a home. Methanex is a major exporter to Asia, whereas OCI sells into the European market. The low-carbon methanol sector will also experience some shakeup. OCI is a major participant in the bio-methanol space, selling volume into Europe. Methanex produces carbon-captured methanol, also known as blue methanol, which has not penetrated the EU market. By Steven McGinn Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Viewpoint: Trump tariffs may inflate midcon fuel costs


27/12/24
News
27/12/24

Viewpoint: Trump tariffs may inflate midcon fuel costs

Houston, 27 December (Argus) — President-elect Donald Trump's threat to impose tariffs on all Canadian imports would increase costs for producing US midcontinent road fuels, which are largely refined from Western Canadian Select (WCS) crude. Trump said in November that he plans to impose a 25pc tariff on all imports from Mexico and Canada after he takes office on 20 January. Canadian crude is the top feedstock for Midwest refiners, accounting for 66pc of the region's crude runs in September, according to US Energy Information Administration (EIA) data. Parts of the Midwest — as well as California and the northeast US — lack sufficient pipeline capacity to process domestic crude or to receive refined products from elsewhere in the country, according to the American Fuel and Petrochemical Manufacturers (AFPM), which represents many US refiners. So AFPM wants Trump to exclude crude and refined products from his proposed tariffs. Most refiners in the US midcontinent depend on heavy sour crudes, with over 20 marketers and refiners importing crude from Canada in September, including BP's 435,000 b/d Whiting, Indiana, refinery; Cenovus' 151,000 b/d Toledo refinery in Ohio; Marathon Petroleum's 140,000 b/d Detroit, Michigan, refinery; and Phillips 66's 356,000 b/d Wood River refinery in Roxana, Illinois. Generally, heavier sour crudes are less expensive than lighter, sweeter crudes like WTI. The US in September imported 4mn b/d of crude from Canada, accounting for 62pc of total US crude imports and a record high for the month, according to EIA data. The US midcontinent imported 2.6mn b/d of Canadian crude in the month, also a record high for September. In 2023, the region imported 2.7mn b/d of Canadian crude, the highest annual imports recorded for the region, according to the EIA. Canada could move more of its crude through its 590,000 b/d Trans Mountain Expansion (TMX) pipeline to the Pacific coast, where it would head to international markets. US importers could also take more from countries like Saudi Arabia and Venezuela , which produce the heavy, sour crudes favored by refiners in the upper US midcontinent. Each supplied more than 200,000 b/d to the US in September, the largest exporters after Canada and Mexico, according to the EIA. Pipeline movements from the US Gulf coast to the US midcontinent would likely increase if the upper US midcontinent refiners try to replace Canadian heavy sour crude. The region received 23.5mn b/d of crude from the Gulf coast, as the southern US midcontinent processes WTI. But the region would probably face higher landed costs for crude originating from overseas. Refineries would have to be more disciplined with the increased feedstock costs that the threatened tariffs would impose, according to one market participant. The region would still have to rely on Canadian crude because US Gulf coast crude barrels would still cost more, and midcontinent refiners would have difficulty finding alternative sources. WCS Hardisty crude prices have averaged a discount of $17.08/bl to WTI Houston so far in the fourth quarter. For road fuel prices during the fourth quarter to date, Chicago gasoline prices averaged a 1.33¢/USG discount to the US Gulf coast and Chicago ultra low sulphur diesel averaged a 1.34¢/USG discount. But regional spreads between Chicago and the US Gulf coast could continue to narrow if midcontinent refiners reduce operating rates. By Hunter Fite Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Shell shuts oil unit at Singapore refinery


27/12/24
News
27/12/24

Shell shuts oil unit at Singapore refinery

Singapore, 27 December (Argus) — Shell has shut an oil unit at the 237,000 b/d Pulau Bukom refinery in Singapore to investigate a "suspected leak", said the Maritime and Port Authority of Singapore (MPA) and National Environment Agency (NEA) today. Shell informed the government agencies that they will have to shut one of its "oil processing units" at Pulau Bukom to facilitate investigations into a suspected leak. The exact oil processing unit cannot be confirmed, but it is a unit "used to produce refined oil products such as diesel". This means it is likely a crude distillation unit or a hydrocracking unit. Shell's initial estimates show that a few tonnes of oil products were leaked, together with cooling water discharge. Sea water is typically drawn to aid in the cooling process, according to the media release. This came after the 20 October leak at a pipeline at Pulau Bukom, when 30-40t of "slop" — or a mixture of oil and water — leaked into the sea, according to Shell. The gasoline market has shown little reaction so far with spreads being "stagnant" and "range bound", said a Singapore-based gasoline broker. But this could be because of a lack of market activity, with many traders away for holidays at the end of the year. The gasoil January-February spread last traded at $0.58/bl in backwardation at around 6:30pm Singapore time on 27 December, according to a Singapore-based gasoil broker. This marks a slight increase from an assessment of $0.55/bl in backwardation on 26 December, according to Argus pricing data. By Aldric Chew Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

News

Viewpoint: SE Asian IMO2 MRs to rise on EU policy


27/12/24
News
27/12/24

Viewpoint: SE Asian IMO2 MRs to rise on EU policy

London, 27 December (Argus) — Rates for specialised Medium Range (MR) tankers in southeast Asia will be driven up in 2025 by changes in EU policy on deforestation, higher biofuels blending mandates, and new mandates in the aviation sector, all of which will support exports of biodiesels, feedstocks and palm oil. Demand for specialised MRs in southeast Asia is ruled by exports of palm oil to Europe and the US Gulf coast. Palm oil does not usually need to travel on IMO2 ships and can be moved on IMO3 vessels. But it is often moved as a part-cargo of between 5,000-15,000t so is often picked up by IMO2 or IMO2/3 vessels, which are more suitable as they have a higher number of segregated tanks. Kpler data show around 6.3mn t of palm oil was exported from Indonesia and Malaysia to the US Gulf and Europe in the January-November 2024 period. Palm oil deliveries from southeast Asia have been trending lower since 2020 with the product becoming less popular in Europe because of deforestation issues. On 4 December, an agreement was reached between the European Council and the European Parliament to delay the application of the EU Deforestation Regulation (EUDR) by one year. This means larger companies will not be required to prove that their products, such as palm oil, did not contribute to deforestation until 30 December 2025. This has averted a potential rapid loss in palm oil exports to Europe in 2025 but there will probably be a substantial decline in exports later in the year as businesses prepare for the EUDR. In the short term, the decision to postpone the EUDR will probably boost cargo numbers heading to Europe as traders had been holding off for clear regulatory guidance. This will support freight rates for IMO2 MRs in the new year by pulling more IMO2/3s and IMO3s away from the market and by increasing the number of part cargoes available for IMO2s. Feedstock exports ramp up Indonesia and Malaysia also export many specialised products that require IMO2s, such as waste based feedstocks palm oil mill effluent (POME), palm fatty acid distillate (PFAD) and used cooking oil (UCO), as well as finished biodiesels like Ucome. Kpler puts exports of these products to Europe at around 2.8mn t in the first 11 months of 2024, with POME cargoes making up 42pc of all shipments or around 1.2mn t. POME was included in Annex IX Part A of the EU's renewable energy directive (RED), meaning member states can count it twice towards their renewable energy goals. Exports of feedstocks and biodiesels to Europe will probably rise in 2025 as blending mandates rise and because of a reduction in the carryover of emissions tickets in Germany and the Netherlands. Argus estimates European demand for biodiesel Pomeme to rise by around 36pc on the quarter in first three months of 2025 to around 3.5mn litres. Higher requirements for biofuels and feedstocks in Europe should push up demand for products like POME, PFAD, and UCO from Malaysia and Indonesia and support higher IMO2 demand in southeast Asia. But this could be tempered by an Indonesian ruling to include an export permit for POME and PFAD that requires participants to fulfil their cooking oil domestic market obligation. SAF mandates begin in Europe Exports of HVO and SAF from Singapore to Europe also make up part-cargo demand for IMO2 MRs. Argus forecasts European HVO demand will rise by 85pc on the quarter to 2,582mn l in the first three months of 2025. New 2pc SAF mandates in the EU and UK in 2025 will provide a sizable rise in SAF demand. This should spur a jump in cargoes loading from Singapore — driving up demand for part-cargo space on IMO2 MRs. By Leonard Fisher-Matthews Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Generic Hero Banner

Business intelligence reports

Get concise, trustworthy and unbiased analysis of the latest trends and developments in oil and energy markets. These reports are specially created for decision makers who don’t have time to track markets day-by-day, minute-by-minute.

Learn more