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China travel curbs threaten lunar new year fuel demand

  • Spanish Market: Oil products
  • 14/01/21

Chinese authorities are issuing increasingly strict warnings against travel during next month's lunar new year period on rising concerns about new Covid-19 outbreaks, threatening to curb transport fuel use during the high-demand period.

China has been hit by its worst coronavirus outbreak since last summer, with 138 new cases recorded yesterday. Most of the cases were reported in Hebei province, just north of Beijing, prompting the government to impose transportation curbs that have disrupted road fuel deliveries within Hebei and to other provinces including Shanxi, Beijing and Shaanxi, have disrupted road fuel deliveries.

Diesel consumption has been hit by the transportation and logistics restrictions, while gasoline demand has fallen because of a drop in car use in locked-down cities such as Shijiazhuang, Xingtai and Langfang. As many as 22mn people are now subject to lockdowns, although the limited geographic spread of the outbreaks has minimised the impact on prices and demand in China as a whole.

But the potential for lunar new year travel to seed the coronavirus across the country — and concerns the Hebei outbreak could spread to nearby Beijing — have alarmed the government, even as case numbers pale in comparison to those in Europe and the US. Top economic planning body the NDRC and the national health commission have called for people to avoid travel, while the transport ministry said it will suspend public transportation to and from medium and high-risk areas. The government is even paying some migrant workers to cancel trips home during the holiday, which officially starts on 12 February.

The curbs are likely to weigh on transportation fuel demand during Chunyun — the near-40 day period before and after the lunar new year, when domestic travel typically peaks as people return to their hometowns.

Road passenger volumes — an indicator of demand for road fuels, especially gasoline — usually rise by over 20pc month on month in the period, national bureau of statistics data indicate. Gasoline demand hit 3.11mn b/d in January-February 2019, 8pc higher than in the following two months, while diesel demand was 16pc higher at 3.1mn b/d in the same comparison. The lunar new year holiday falls on different dates each year, complicating comparisons.

Road passenger volumes slumped by more than 80pc in last year's Chunyun period compared to a month earlier as China imposed the world's first nationwide Covid-19 lockdown.

Wholesalers and retailers typically build large fuel stocks ahead of the lunar new year. But refiners have cut their expectations for this year's pre-holiday sales because of the impact of the Covid-19 restrictions on travel, as well as colder-than-usual winter weather. Many regions of China have been hit by snowfalls, even in areas where temperatures rarely dip below zero, while Beijing last week recorded its coldest morning since 1966. Refiners have now started curtailing run rates, slowing demand for imported crude.


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19/12/24

Viewpoint: Politics, economy key to bitumen recovery

Viewpoint: Politics, economy key to bitumen recovery

London, 19 December (Argus) — Political change and uncertainty will come to dominate the European bitumen market more than usual in 2025, while demand could decline further than it did in 2024. Market participants are trying to pin down the bottom of the market for bitumen demand, after falling for several years in most of Europe. And support for demand seems far from certain in 2025 given spiralling public debt, political uncertainty and a lack of funding for road maintenance and projects in most European countries. But there could be some positive economic news as interest rates start to fall and inflation returns to more normal levels, while the outlook for oil prices in 2025 is less bullish than previously with plentiful supply forecast. Increased supply and lower crude prices would tend to pressure lower bitumen prices, which could support consumption, given road budgets can be stretched further. Politics seems more unpredictable than ever, with various elections and other changes expected in 2025, often shifting to the right or populist wing in Europe. The necessity of road maintenance and project work to support economies is plain to see for governments, but there is uncertainty on the priority they will be given by some new political forces emerging. Bitumen production is still going to be plentiful in the new year, despite some refinery closures and problems in the past year and more. Issues at both Greek and Turkish refineries, which are powerhouses for Mediterranean bitumen exports, will not have a major impact given the weaker demand in much of north Africa and the lack of available arbitrage routes. Outlets to the US and east of Suez are closed at present and show little sign of re-emerging strongly in the period ahead. Spring maintenance, particularly a February to May shutdown at Algerian Sonatrach's 198,000 b/d Augusta refinery in Sicily, will also limit supply just when demand starts to seasonally rise. In the last viewpoint Argus expected a weaker year for 2024 demand, while also looking at pricing and how differentials to high-sulphur fuel oil (HSFO) could go negative. As winter approaches at the end of 2024 this has happened in the north of Europe and fob cargo discounts have been seen in the eastern Mediterranean all year. Bitumen market fundamentals have drifted further away from those of crude and HSFO in the last year, although a relationship still exists with HSFO maintaining a persistent standing as a price marker for inland bitumen markets for weekly or monthly calculations and for export waterborne prices as the basis with a differential. But Argus expected that traders would seek more arbitrage movements from the European Mediterranean, and this did not come to fruition in 2024, with little seen moving to the US and even less to the Asia-Pacific region. There is not much indication this will change in 2025 with lower prices and plentiful supply in Asia and US supply points. Poorer refining margins may have an impact in 2025 after the strength post-Covid, which will put more renewed pressure on older and simpler refiners to close. These facilities are more likely to produce bitumen. Instead traders will rely on large new ships to feed supply and move bitumen longer distances, a trend already well underway with a number of new ships entering service. Freight costs should stay at elevated levels given the ETS scheme comes into fuller effect in 2025 after first being implemented in 2024. The inclusion of shipping in this EU scheme will oblige shipowners and charterers of vessels from 5,000 gross tonnes to purchase carbon allowances, rising from 40pc of carbon emissions in 2024, to 70pc in 2025, before 100pc in 2026. From uncertainty can come opportunity and with the worst of the economic outlook now behind us then perhaps 2025 can be the beginning of the end in the downtrend for bitumen demand and we start to see vital road maintenance work and infrastructure projects get the funding they need. By Jonathan Weston Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Reliability drives New Zealand power mix: Minister


19/12/24
19/12/24

Reliability drives New Zealand power mix: Minister

Sydney, 19 December (Argus) — New Zealand's conservative coalition government wants to ensure reliable generation, whether that is from coal, oil, gas, or geothermal resources, the country's resources minister Shane Jones told Argus this week. Jones was also clear about the need to draw a distinction between "the expectations on [a] small, open trading nation like [New Zealand] not to use coal and the major hope[s] and needs of the average New Zealander for affordable power, reliable power." "If [reliable power] comes from coal, that's the mix and the menu for the future," he added. Jones argued that existing renewable power sources cannot exclusively provide for New Zealand's energy needs. He instead suggested that his government is interested in promoting alternative power sources such as oil, gas and geothermal, through investments and policy changes. New Zealand's coal-fired power generation surged between July-September, according to the New Zealand's Ministry of Business Innovation and Employment (MBIE). Coal rose to 8pc of total generation from 3pc a year earlier, following a drop in hydroelectric power production. The country burned 363,513t of coal over those months, more than tripling its use for power generation purposes compared to the same period last year. Oil, gas Jones has taken steps to boost the country's oil sector since taking office in late 2023, following the coalition's victory over the centre-left Labour party. The minister introduced the Crown Minerals Amendment Bill in June, a piece of legislation that he described as being "aimed at increasing investor confidence in petroleum exploration and development." Jones told Argus that under the previous government, "people who may have been willing to [make] investment[s] and bring patient capital concluded that New Zealand was no longer available as a destination for oil and gas and this has resulted in a diminution in [oil] investment." The Crown Minerals Amendment Bill will overturn a 2018 ban on offshore oil exploration, which was introduced while Jones was serving in the previous Labour-led coalition government. New Zealand's oil sector increased its annual well spending from NZ$110mn ($63.2mn) in 2018 to NZ$403mn, in the years following the ban in 2018. The total number of active oil permits in the country has plunged from 56 to 37 over the same period, MBIE data show. New Zealand likely houses at least 223.5bn m³ of undiscovered, offshore gas reserves; 249mn bl of undiscovered, offshore oil reserves; and 177mn bl of undiscovered, offshore NGL reserves, mostly scattered around the North Island, according to US Geological Survey (USGS) estimates in 2022. The country's discovered, recoverable reserves are at between 38.3mn-52.7mn bl of oil; 29.4bn-39.8bn m³ of gas; and between 1.2mn–1.4mn t of LPG as of 1 January 2024, according to the MBIE. Besides restarting oil exploration, the Crown Minerals Amendment Bill also seeks to change permitting processes to drive capital into the sector. Permits are currently allocated through a competitive tender process, Jones told Argus this week. The government wants "the flexibility to use alternative processes to match investor interest in the most efficient and effective way by allowing the option of using non-tender methods." MBIE has indicated that the government may start using ‘priority in time' tenders, which allocates permits to the first eligible projects that apply for them, once the bill passes. But the Crown Minerals Amendment Bill does not specify how the government will manage non-competitive tenders. The government is also not using the Crown Minerals Amendment Bill to "specifically intervene in coal mining operations" in New Zealand, Jones said. But coal demand will fall "in the event that [the government is] able to expand the supply of indigenous gas," he noted. Geothermal The government's energy strategy also appears to involve doubling down on domestic geothermal generation, which is New Zealand's second most common source of power. Geothermal generators produced 2,363GWh of power between July-September, accounting for 20.5pc of total generation, in line with historical averages, according to MBIE data. New Zealand's government seems to be trying to push that share up. The government in early December decided to allocate up to NZ$60mn of public infrastructure funding to research for deep, geothermal energy production. The work will focus on drilling geothermal wells up to 6km deep, nearly twice the depth of standard wells. Jones told Argus that New Zealand officials are currently in Japan, discussing supercritical geothermal generation opportunities with engineers and scientists. By Avinash Govind Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

US Army Corps proposes new Illinois River lock


18/12/24
18/12/24

US Army Corps proposes new Illinois River lock

Houston, 18 December (Argus) — The US Army Corps of Engineers (Corps) has proposed a new lock to replace the LaGrange Lock and Dam (L&D) near Beardstown, Illinois, as part of the Navigation and Ecosystem Sustainability Program (NESP). The project would be the first new lock for NESP, a program that invests in infrastructure along the Mississippi and Illinois rivers. The new 1,200ft proposed LaGrange Lock would allow for passage of more barges in a single lockage, instead of having to split the tow in two with the current 600ft LaGrange Lock. At the moment, most tows trying to pass through the LaGrange lock experience multiple hour delays. The new LaGrange lock would have an estimated cost of $20mn, with a construction timeline of five years. The project area would be located on the west bank of the Illinois River near the 85-year old LaGrange L&D, encompassing 425 acres. Real estate acquisition, design plans and contractors are already in place, said the Corps. The current LaGrange lock would remain in operation and become an auxiliary chamber. The Corps opened the upcoming project to public comments on 11 December and will close on 3 January. NESP has four other projects along the Mississippi River. Another full lock construction project is anticipated for Lock and Dam 25. By Meghan Yoyotte Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Alabama lock expected to reopen late April


18/12/24
18/12/24

Alabama lock expected to reopen late April

Houston, 18 December (Argus) — The main chamber of the Wilson Lock in Alabama along the Tennessee River is tentatively scheduled to reopen in four months, according to the US Army Corps of Engineers (Corps). The Corps expects to finish phase two of dewatering repairs on the lock on 20 April, after which navigation can resume through the main chamber of the lock. The timeline for reopening may shift depending on final assessments, the Corps said. Delays at the lock average around 12 days through the auxiliary chamber, according to the Lock Status Report by the Corps. Delays at the lock should wane during year-end holidays but pick up as spring approaches, barge carriers said. The main chamber of the Wilson Lock will have been closed for nearly seven months by the April reopening after closing on 25 September . By Meghan Yoyotte Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Viewpoint: Ample supply to weigh on base oils market


18/12/24
18/12/24

Viewpoint: Ample supply to weigh on base oils market

London, 18 December (Argus) — European base oil prices are likely to fall further in 2025 on a persistent global supply overhang of Group III material and weaker demand for Group I spot supplies. European Group III spot prices with varying approvals face downwards pressure as overseas producers target European buyers supported by attractive margins and ample spot supplies. Stricter emission standards and engine oil specifications have supported a switch towards more premium base oils such as Group II and III away from Group I production, which is in long-term decline. Prices for fca northwest Europe (NWE) Group III 4cst and 6cst supplies with partial or no approvals fell by 16pc and 13pc to €1,125/t and €1,185/t, respectively on the week ending 13 December 2024, the lowest levels since April 2021. Rising Chinese domestic Group III production capacity has slashed the country's requirements for supplies from South Korea and the Mideast Gulf, incentivising suppliers to look towards the European market. Buying appetite for tenders out of Bahrain has also increased and spot supplies have arrived at more competitive levels. This has spurred other suppliers to lower offers further as they look to remain competitive and claim market share before the conclusion of upcoming Group III refinery expansions in 2025. The Mideast Gulf has an estimated Group III production capacity of 2mn t/yr. This is set to increase with state-controlled Saudi Aramco's base oil subsidiary Luberef focusing on expansion projects at its Yanbu facility . This will increase nameplate capacity by 76.2pc, to approximately 1.3mn t/yr of base oils by 2025. Europe remains the most attractive export outlet owing to smaller Group III production capacity in comparison to other regions. Europe has an estimated nameplate base oil capacity of 7mn t/yr, of which 13pc is Group III. A shift away from Group III imports in the US has further supported Mideast and South Korean suppliers to redirect supplies from this region and towards Europe. An announcement by Shell to convert its hydrocracker at its 147,000 b/d Wesseling refinery in west Germany into a Group III base oil production unit looks to increase domestic output by 300,000t/yr. But production is only anticipated to begin in 2026-2028, leaving European buyers mostly dependent on imports in 2025. European demand has plummeted thanks to amply supply levels — leading to a continuous wait-and-see approach from traders as they anticipate prices to fall further. Participants have reported term contracts finalised at price levels well below year ago levels and anticipate spot prices in 2025 to drop as a result. European Group I nameplate capacity has fallen by 55pc over the last decade to around 4mn t/yr owing to refinery closures, according to Argus calculations. In 2024, Eni's Group I 600,000 t/yr Livorno unit shut, and there were several refinery fires and outages elsewhere in Europe. But despite tighter spot supplies, prices fell because of weaker demand. Demand is anticipated to fall further in 2025 as producers prioritise output of more premium base oil. This includes Polish firm Orlen's Gdansk refinery expansion , adding a group II base oil unit with an estimated capacity of 400,000t/yr of Group II. Exxonmobil also announced that it will produce a high-viscosity Group II alternative to the Group I bright stock grade by 2025 out of its Jurong refinery in Singapore. Bright stock currently has no alternative, which supports its production. But Exxon's announcement is likely to weigh on refinery output and shrink the Group I market further. By Christian Hotten Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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