Japan’s NYK receives fifth LNG-powered car carrier

Spanish Market: Natural gas, Oil products
25/07/23

Japanese shipowner Nippon Yusen Kaisha has launched its fifth LNG-powered car carrier, which will mainly be used to transport vehicles manufactured by domestic car producer Toyota Motor.

The 71,846 gross-ton Freesia Leader was built by Chinese state-owned shipbuilder China Merchants Jinling Shipyard (Nanjing), and will be able to carry up to 7,000 passenger cars in each shipment. LNG bunker barge Kaguya supplied Freesia Leader with marine fuel-use LNG at the port of Nagoya in central Japan on 24 July.

Japanese firms are expanding LNG bunkering points in the country, as domestic shipowners are accelerating their LNG-powered vessel deployments as well as their alternative marine fuels strategies to cut CO2 and greenhouse gas emissions.

The country has already launched two LNG bunkering ships — Kaguya in the Ise and Mikawa bays, and Ecobunker Tokyo Bay in Tokyo. The Kaguya has been supplying LNG to ocean-going LNG-fuelled vessels since October 2020, while it is unconfirmed if Ecobunker Tokyo Bay has started operations yet.

More LNG bunker barges will be added to the fleet in the coming years. Keys Azalea will begin its LNG deliveries in the Kyushu and Setouchi areas in 2024, while another ship is to be launched in the Osaka and Setouchi areas in April 2026-March 2027.

The four LNG bunker barges will cover the country's main bunkering areas of Tokyo, Nagoya, Osaka, Setouchi and Kyushu.

Around a third of Japan's total conventional bonded marine fuel sales are currently delivered in the Tokyo bay area, which includes Tokyo, Yokohama and Chiba, according to bunker traders.

By Maiko Nakashima

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.

19/12/25

Mexico central bank cuts target rate to 7pc

Mexico City, 19 December (Argus) — Mexico's central bank cut its benchmark interest rate by 25 basis points to 7pc, its lowest level since June 2022, maintaining a slower pace in the easing cycle on inflation concerns. The decision marked the eighth rate cut this year and the fourth quarter-point reduction following four consecutive half-point cuts. This year's cuts follow five quarter-point cuts in 2024 from a cyclical peak of 11.25pc in March. The board approved the cut in a 4-1 vote, with deputy governor Jonathan Heath dissenting in favor of holding the rate at 7.25pc. Heath has been the lone dissenter in the past five decisions, consistently urging greater caution. The central bank said the decision reflected "the behavior of the exchange rate, the weakness of economic activity and the possible impact of changes in global trade policies," repeating language used in its last four statements. Gabriela Siller, chief economist at Banco Base, pointed to a "significant change" in the bank's forward guidance, noting a shift toward a less dovish tone. The board said it "will consider when to make further adjustments" to the policy rate, replacing the "will consider cutting" language used in November. Mexican bank Banorte also said the central bank struck a less dovish tone, pointing to a change in its forward guidance. Annual inflation rose to 3.8pc in November from 3.57pc in October, according to statistics agency Inegi. Core inflation, which excludes volatile food and energy prices, accelerated to 4.43pc from 4.28pc. The central bank now sees headline inflation ending 2025 at 3.7pc, up from 3.5pc in its November forecast, while core inflation is projected at 4.3pc, revised from 4.1pc. It also raised its headline and core forecasts for the first two quarters of 2026, while maintaining that both will converge to its 3pc target by the third quarter. The bank said the revisions mainly reflect a "more gradual-than-expected" easing in services inflation, along with a smaller contribution from accelerating consumer goods prices. The board also addressed recent tax reforms, which it expects will have a temporary and not necessarily proportional impact on prices, adding it will update its forecasts as it conducts a comprehensive assessment of the revised tax code's effects. By James Young Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Viewpoint: Bitumen markets eye pockets of demand

19/12/25

Viewpoint: Bitumen markets eye pockets of demand

London, 19 December (Argus) — Paving activity may strengthen in some European and north African markets in 2026, but several others are expected to see continued declines in bitumen demand. Germany could lead any recovery, market participants said, as a new government plans to expand and maintain the road network. The country — once Europe's bitumen powerhouse — had a weak 2025, but paving work is expected to lift consumption from mid-2026. German bitumen demand has fallen by more than 20pc since 2021, while France and the UK are down by over 25pc in the same period. Budget constraints and high inflation drove these declines. Sweden, Norway and Denmark — already demand drivers in 2025 — could strengthen further in 2026. Road budgets are set to rise as governments prioritise infrastructure and the value of well-maintained highways, possibly linked to higher defence spending as Nato strengthens in Europe. North Africa has also drawn European Mediterranean surplus cargoes , and market participants expect demand from the region to increase next year, led by Algeria, Morocco and some Libyan consumption. Elsewhere, there is little cause for optimism. In France, most participants expect 2026 demand to be weaker than in 2025. With the government beset by regular upheaval and parlous public finances, road spending seems an unlikely priority. Several other northwest and central European countries will also see steady to lower bitumen consumption in 2026. Meanwhile, prospects for a peace deal between Ukraine and Russia remain slim, so a large upswing in Ukrainian import demand looks unlikely next year. Export opportunities outside Europe also appear limited, as Asia-Pacific and the Middle East remain well supplied and demand there stays slow. South Africa, now reliant on imports, is more likely to source from the Mideast Gulf or Pakistan than from the Mediterranean. The prospects of shipping product to the US could improve in the coming months, with Mediterranean bitumen values currently firm relative to crude and fuel oil. But large volumes seem unlikely. Some Mediterranean cargoes moved to the US last year, but the trend was short-lived. In the bitumen freight market, several new larger tankers will enter service in 2026, increasing vessel availability in what will still be a weak market. This could weigh on freight rates but help offset higher costs from the EU ETS scheme, which comes fully into effect in 2026 after its 2024 implementation. Bitumen prices fell in 2025 and are expected to stay under pressure through winter, before seasonal gains from March 2026. Markets should see greater strength relative to fuel oil in summer as bitumen demand typically rebounds then. Demand for bitumen was generally weaker across most European countries in 2025 than in 2024, weighing on prices. Budgets came under pressure and political challenges contributed to a lack of focus on infrastructure and road maintenance spending. Bitumen prices hit historic lows in 2025, partly offsetting inflation-driven increases in building, equipment and material costs. By Jonathan Weston Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

W Australia's gas surplus outlook strengthens: Aemo

19/12/25

W Australia's gas surplus outlook strengthens: Aemo

Sydney, 19 December (Argus) — The Australian Energy Market Operator (Aemo) is forecasting a bigger gas supply surplus in Western Australia (WA) for most of 2026-30, according to its 2025 WA Gas Statement of Opportunities (GSOO) report released today. Aemo now projects that both gas supply and demand will be lower than previously expected in the period, because of cutbacks at major industrial users and downward revisions to its production forecasts. But its demand revisions were larger than its supply revisions, increasing its projected surplus. The state's gas supply will exceed demand over most of that period, except in 2028 and 2030 (see table) . It has increased its projections for the size of the surplus compared with those in its 2024 WA GSOO report. Supply side Aemo cut its WA gas supply forecast because of delays, gas reserve depletions, and decreased expected production at the Gorgon, Scarborough, and Pluto projects, it said. The market operator previously expected Australia producer Strike Energy to open its 87 TJ/d (2.3mn m³/d) West Erregulla project in 2026. But Strike only aims to make a final investment decision on the project in July-December 2026 , later than originally anticipated . Strike's West Erregulla delay lowered WA's expected gas production by 52 TJ/d in 2027 and 63 TJ/d in 2028, Aemo said. Aemo has also cut its production expectations for the Scarborough and Pluto gas fields by up to 24 TJ/d in 2030, it said. Australian developer Woodside Energy aims to process 7mn t/yr of Scarborough gas and 3mn t/yr of Pluto gas from early 2027, it said in November. Workers building a 5mn t/yr LNG train at the Pluto LNG terminal plan to launch a strike on 6 January. Their current enterprise bargaining agreement with Australian engineering firm Bechtel will expire on 19 December, Argus understands. Planned maintenance and lower utilisation at the Gorgon project contributed to a 16 TJ/d cut to Aemo's forecasts, it said. The project's owners — which include Chevron, ExxonMobil, Shell, Osaka Gas, Tokyo Gas and Jera — will modify its three-train Gordon LNG terminal as part of a A$3bn ($1.98bn) project, it said in December. Reserve downgrades and depletions at the Walyering, Beharra Springs, Macedon, and Varanus Island fields mostly account for the rest of the supply revisions, Aemo said. The Walyering and Beharra Springs field reserve downgrades cut Aemo's WA supply forecast by 5 TJ/d in 2026 and 23 TJ/d in 2029, it added. Demand side The closure of nickel mining and alumina refining operations cut Aemo's 2026-30 demand forecast, the operator said. But demand will still rise over that period, from 1,085 TJ/d in 2026 to 1,295 TJ/d, because of new mining and processing activity, it said. US producer Alcoa opted to permanently close its 2.2mn t/yr Kwinana alumina refinery on 30 September , after it paused the site in July 2024. It has not announced a full closure timeline yet, Alcoa Australia president Elsabe Muller told Argus at the time. Australian miner IGO has also paused its Forrestania and Cosmos nickel projects over recent years. Multiple developers including Australian producers Iluka Resources , Cobalt Blue , and RZ Resources will develop critical mineral mining or processing projects in WA over the coming years. By Avinash Govind WA projected gas surplus TJ/d Year Surplus (2024 WA GSOO) Surplus (2025 WA GSOO) 2026 4 54 2027 5 20 2028 -12 -89 2029 5 132 2030 -2 -11 *GSOO refers to Gas Statement of Opportunities Source: Australian Energy Market Operator Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Energy Transfer halts plans for Lake Charles LNG

18/12/25

Energy Transfer halts plans for Lake Charles LNG

Houston, 18 December (Argus) — US midstream firm Energy Transfer is suspending development of its planned 16.5mn t/yr (2.2 Bcf/d) Lake Charles LNG export terminal in Louisiana to focus on natural gas pipeline expansions, the company said today. The pivot allows the company to reallocate capital to gas pipeline projects that provide "superior risk/return profiles", Energy Transfer said. The company separately said it will increase the capacity of its planned Desert Southwest expansion of the Transwestern pipeline, allowing it to move more gas from west Texas' Permian basin to the southwestern US. The decision to scrap Lake Charles LNG follows a month of dissonance from company executives about moving forward with the facility. Energy Transfer co-chief executive Mackie McCrea told investors in early November that the company would not be able to reach a final investment decision (FID) until it sold off 80pc of equity shares in the project. But Amy Chen Davis, vice president of Lake Charles LNG, told an industry event on 10 December that the company was in talks with potential partners and would reach a final decision in early 2026. The company said earlier this year it planned an FID by the end of 2025. The midstream firm has sought for years to convert the existing Lake Charles import facility into an export terminal. Shell signed on with a 50pc stake in 2019 but pulled out the following year as part of cost-cutting measures during the Covid-19 pandemic. McCrea had signaled to investors that the company was being cautious with entering the LNG export industry. "When you're chasing billions of dollars in projects, several of which we've already announced, we've got to be careful stepping out on something like this," McCrea said on 5 November. "We're not an LNG company like we compete with. We're a pipeline company that has a regas facility converting part of it to LNG." Investor MidOcean Energy had signed a preliminary agreement to fund 30pc of Lake Charles LNG's construction costs in exchange for 30pc of offtake, but the firms never finalized the deal. Suspension of the project also may set back the efforts of Saudi Aramco, which holds a 49pc stake in MidOcean, to develop an LNG portfolio. MidOcean has a share in Peru's 4.45mn t/yr Pampa Melchorita LNG export plant and the Shell-led 14mn t/yr LNG Canada export terminal in British Columbia. Pipeline project in focus Meanwhile, Energy Transfer said it will upsize capacity on the Desert Southwest expansion. The company said it will increase the expansion's capacity by 800mn cf/d to 2.3 Bcf/d to satisfy additional demand in the southwestern US. Energy Transfer reached an FID on Desert Southwest in August. The expansion is one of several projects working to increase gas transportation capacity out of the Permian, where a steady increase in crude-driven activity — and commensurate rise in associated gas output — has outpaced the increase in gas takeaway capacity. This has created a local gas supply glut and some of the lowest gas prices in the US. By Tray Swanson Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

US House passes bill to expedite permitting

18/12/25

US House passes bill to expedite permitting

Washington, 18 December (Argus) — The US House of Representatives on Thursday approved a bill designed to fast-track permitting for energy projects and reduce related litigation risks. But a last-minute change Republicans made to exclude some offshore wind and solar projects led some Democrats and a major clean energy group to withdraw support, complicating the bill's chances of passage in the Senate. The Republican-controlled House voted 221-196 to pass the SPEED Act, with 11 Democrats crossing the aisle to vote for what would be the most significant changes to federal permitting in years. The bill will now advance to the US Senate, where proponents will likely need to agree to make significant changes if they hope to pick up the votes of at least seven Democrats to avoid a filibuster. The bill "finally brings common sense by cutting red tape that dramatically increases the cost and, in some cases, just makes it economically unfeasible to do projects", House Republican majority leader Steve Scalise (R-Louisiana) said. The SPEED Act focuses on revising project reviews under the National Environmental Policy Act (NEPA), which is a source of delay and litigation risk for pipelines and renewable projects alike. The bill would require federal agencies to narrow those reviews and uphold those decisions even if federal courts find them to be inadequate. The bill would also provide permit "certainty" by limiting the government's ability to rescind prior approvals, averting a repeat of events like the cancellation of the Keystone XL pipeline. "We applaud the House for advancing the SPEED Act, a bipartisan, commonsense step toward fixing a federal permitting system that's long been broken," oil industry group the American Petroleum Institute said. Republican leaders were hoping 30-40 Democrats would join them to support the SPEED Act. The bill had broad bipartisan support when it was drafted because of provisions meant to prevent permitting delays that have plagued both oil and gas pipelines and renewable energy development. But Republican leaders, to satisfy far-right conservatives, made a change to the bill earlier this week that would prevent its expedited permitting procedures from benefiting any project that Trump's administration has blocked or revisited since 20 January. The Trump administration has targeted multiple offshore wind and solar projects this year and has ordered the developer of the nearly complete 704MW Revolution Wind project off the coast of Rhode Island to stop construction. That change fractured a bipartisan coalition that had spent months working on technology-neutral permitting language. The American Clean Power Association, the largest industry group for US renewable energy, on Wednesday withdrew its support of the bill , arguing the "poison pill amendment" that Republicans made eviscerated bipartisan language that gave expedited permitting treatment for all types of energy resources. A number of House Democrats who had backed the bill also withdrew their support. American Clean Power plans to work with both parties in the Senate to make changes. "This is not the final draft," representative Scott Peters (D-California) said during floor debate Thursday, vowing to work with his colleagues in the Senate to address House Democrats' concerns. By Chris Knight and Haik Gugarats Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Argus Specialised Freight

Datos, perspectivas y herramientas únicas para ayudar a gestionar los riesgos de flete en los mercados de biocombustibles, materias primas renovables y productos químicos

Argus Carbon

Benchmarks de precios del carbono, noticias sobre políticas y proyectos, y análisis exhaustivos, a diario.

Informe Argus Low Carbon Hydrogen Strategy

Tercera parte: América del Norte Un análisis en profundidad de los sectores, países y políticas claves que permiten el crecimiento del hidrógeno.

Argus Hydrogen and Future Fuels

El punto de vista global sobre el hidrógeno y los mercados de productos derivados.

Argus LNG Daily

Acceda a las últimas evaluaciones del precio al contado de GNL, noticias del mercado y análisis independientes.

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