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Polish coal supply tightens as imports fall

  • : Coal
  • 21/01/26

Weak Polish thermal coal imports early in 2021 could tighten availability of fine grades, which until recently were oversupplied in the country.

Quicker gains in Asia-Pacific coal prices compared with the Atlantic have weighed on Russian exports to Poland in recent weeks. Argus assessed NAR 6,000 kcal/kg Australian coal at a $21.10/t premium to Europe on 22 January, which was up from $11/t in December and represented an 18-month high.

Extremely cold weather in Siberia has also hit rail loadings for Europe and curbed supply to Poland, importers said. A rail terminal operator in Braniewo on the Russia-Poland border told Argus that winter imports had been unusually low, but that it was too soon to say if the trend was temporary or will continue.

Lower imports, combined with a recovery in industrial and power-sector demand and a cold snap in early January, has already pressured traders' fine coal stocks. Importers sought to minimise imports of coal fines throughout 2020 as weak prices made sized grades more profitable for stock and sale.

Braniewo coal fines stocks — unmoved for most of 2020 — have visibly shrunk in recent weeks, a source told Argus, while another importer said they now had no fines in stock.

Some importers have still suspended imports of coal fines as they wait to see how sustainable the latest price rally is, since competition among suppliers of coal fines in Poland is fierce. One importer said they were "lucky" to buy 5,500 kcal/kg 0-50mm Russian coal for February-delivery for $63.50 DAP border price, when offers ranged at $68-75/t.

On 26 January, an importer offered 6,000 kcal/kg coal at Gdansk for $77.50/t on the Argus Open Markets platform. A Russian supplier also offered 5,500 kcal/kg coal in Braneiwo at $80/t, but neither offer resulted in a deal.

Any shift from oversupply to shortage is still expected to be gradual, as thermal coal demand is in structural decline in Poland, with consumption falling by around 10 pc/yr, traders said. There is an estimated 20mn t of thermal coal in stock across the country, but around 17mn t of this is at coal mines, power plants and CHPs. Stocks at coal mines are also believed to be mainly lower grades, for which demand is weaker.

The shortage of more desirable coal grades is evident in the minimal exports from the country last year. Polish exporter Weglokoks' international sales fell by 58pc on the year to 260,000t in 2020, shipped almost exclusively by rail.

In January-November 2020 Poland imported just over 10mn t of thermal coal, a 16pc decline on the year according to figures from the country's ARP, which collects import data for the government.

This was the second annual decline from the record 16mn t imported in 2018. Russia remained by far the largest source of Polish imports, with nearly 8.5mn t received in January-November, down by 15pc on the year. Colombia and Kazakhstan followed, with nearly 900,000t and more than 800,000t respectively, ARP said.

Poland's seaborne imports fell by about 20pc on the year to a little more than 4mn t in 2020, according to estimates and data compiled by Argus from ports. Inland rail imports of Russian coal were 6.6 mn t, according to Russian rail data. Braniewo handled around 2.9mn t in 2020, which was stable on the year, according to terminal operators. The Brest-Malasheviche border crossing with Belarus was the second-biggest entry point for Russian coal to Poland.

Seaborne imports by port mn t

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24/09/25

Vietnam’s Vinacomin to boost coal imports

Vietnam’s Vinacomin to boost coal imports

Singapore, 25 September (Argus) — Vietnamese coal producer Vietnam National Coal and Mineral Industries (Vinacomin) plans to more than double its thermal coal imports over the next six years to meet an anticipated growth in demand. The state-owned company, which meets most of Vietnam's coal requirements, aims to lift imports to 12.6mn t this year and to 14.5mn t in 2025, and increase its receipts of seaborne thermal coal to 22mn t in 2030, a senior official from the firm told Argus on 25 September. It imported 9.2mn t of coal in 2023. The move to raise imports comes as Vinacomin wants to raise its blended coal supplies to utilities, because it is the key supplier to local coal-fired power plants. Vinacomin typically blends its domestic coal with imported thermal coal to meet utility requirements as anthracite accounts for most of the locally produced coal, and is not preferred by plants for direct use given its low volatile matter content. Vinacomin is also a key supplier of coal to industries such as steel and cement. The coal import plans support Vietnam's overall coal import outlook at a time when the country's seaborne coal receipts are set to reach an all-time high in 2024. Vietnam has imported 45.86mn t of all types of coal in the first eight months of the year, up by about 33pc from a year earlier, according to its customs data . The country could end up importing close to 69mn t of coal this year at the current average rate of 5.73mn t/month, according to Argus calculations, marking Vietnam's highest annual imports since the 55mn t of coal it received in 2020. The imports could reach about 73mn t by 2030 and rise further to peak at around 85mn t in 2035 , according to the government's latest national energy master plan released last year. Vinacomin's strategy to grow imports also comes as Vietnam's domestic coal output has remained rangebound and sluggish. Vinacomin has set a target to produce 37.4mn t this year, up from 36.8mn t it produced last year. Domestic coal output growth faces challenges as there is no near-term plan to explore the Red River delta, which accounts for nearly 86pc of Vietnam's total coal reserves of 48.9bn t. Coal mining in the belt could be ecologically sensitive as the bulk of the land is used for agriculture, while coal projects in the region could also be economically unviable. Vinacomin in 2024 is seeking imported coal with calorific value of NAR 4,800-5800 kcal/kg coal of low and mid-volatile matter coal, with typical sulphur content of 0.6pc to aid its blending efforts, the official said. Vinacomin buys the bulk of the coal via tenders and it refers to international coal indices including Argus' ICI index for Indonesian coal as well as the API index for non-Indonesian coal. By Saurabh Chaturvedi Vinacomin's thermal coal import plan (mn t) Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Draught limits tighten on lower Mississippi River


24/09/23
24/09/23

Draught limits tighten on lower Mississippi River

Houston, 23 September (Argus) — The US Coast Guard (USGC) placed further restrictions on traffic on the lower Mississippi River as water levels continue to deteriorate. The USCG on 22 September announced that all northbound traffic cannot have draught deeper than 9.5ft from Tunica, Louisiana, to Greenville, Mississippi. For Greenville to Tiptonville, Mississippi, barges must remain above a 9ft draught, the shallowest draught channel allowed for the lower Mississippi River by the US Army Corps of Engineers. All northbound transit also cannot load more than four barges wide or configure more than five barges wide. Southbound traffic from Tiptonville to Greenville cannot be more than six barges wide or deeper than 9.5ft. Greenville to Tunica southbound barges can load as deep as 10ft but cannot be more than seven barges wide. All locations between Cairo, Illinois, and Greenville fell back to their low water threshold over the weekend as rainfall from Hurricane Francine flowed down the river. More grain has moved downriver this year compared with last year as the US Department of Agriculture (USDA) expects higher US grain exports in the 2024-25 marketing year. Around 367,000 short tons of grain moved for the week ended 14 September, which is about double the same period a year earlier, the USDA said. Both south and northbound movement is expected to see a heavier pace in October. By Meghan Yoyotte Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Japan pushes abatement approach to energy transition


24/09/23
24/09/23

Japan pushes abatement approach to energy transition

Tokyo, 23 September (Argus) — Japan is keen to promote its energy transition approach, focused on carbon abatement technologies, to the wider coal-reliant Asia-Pacific region. The country has accelerated development of carbon abatement technologies to keep fossil fuels in its energy mix and boost energy security and economic growth. Japan, with its G7 counterparts, pledged to phase out "unabated" coal-fired plants by 2035, or "in a timeline consistent with keeping a limit of a 1.5°C temperature rise within reach, in line with countries' net zero pathways". This is a major step for Japan, a resource-poor country. But legislative progress aimed at developing value chains for carbon capture and storage (CCS) and cleaner fuels, such as hydrogen and ammonia, might have encouraged Tokyo to commit, especially since the G7 text allows for some wiggle room. To ensure continued use of its abated thermal power plants, trade and industry ministry has requested ¥11.2bn ($79mn) to support CCS projects, including exploration of CO2 storage sites, for 2025-26, up sharply from the ¥1.2bn budgeted for 2024-25. Japan has yet to set a date to achieve the phase-out target. But it had already promised not to build new unabated coal-fired plants at last year's UN Cop 28 climate talks, while pledging to phase out "inefficient" coal-fired plants by 2030. Less than 5pc of Japan's operational coal fleet has a planned retirement year, according to analysis by Global Energy Monitor, and these might comprise the oldest and least efficient plants. Coal capacity built in the last decade, following the Fukushima-Daiichi nuclear disaster, is unlikely to receive a retirement date without a countrywide policy that calls for a coal exit. Japan's coal demand could decline, to some extent, under global divestment pressure. But the fuel remains key, as the government sees renewables and nuclear as insufficient to meet rising power demand driven by the growth of data centres needed to enable artificial intelligence. Continental divide The country is keen to extend its vision for "various" and "practical" pathways, including abatement technologies, to coal-reliant southeast Asia. This stems from Tokyo's sceptical view about promoting a more European approach to the energy transition — driven by wind and solar power — to Asian countries. Japan stresses the importance of more diversified pathways, including thermal power with abatement. The country aims to spur decarbonisation in Asia-Pacific through a platform called the Asia Zero Emission Community (Azec) initiated in 2022. Asia-Pacific accounts for more than half of global greenhouse gas (GHG) emissions, at 17.178bn t of CO2 equivalent, according to the IEA. In Jakarta last month, 11 Azec countries emphasised the need to co-operate "to decarbonise coal power generation". The platform sets out options such as biogas, hydrogen and ammonia, and retrofitting with CCS and carbon capture, utilisation and storage. Japan's industries have already committed to carbon abatement at coal-fired plants in Asia, leveraging their technological know-how. Tokyo has pledged to provide about $70bn to support decarbonisation globally. This funding is part of wider financial assistance to help mobilise the estimated $28 trillion that Asia requires. To secure the funding, Japan has already issued part of a $139bn climate transition bond and aims to strengthen the financial support through the Asia Zero Emission Centre, the latest Azec initiative, under which transitional finance will be studied further, a trade and industry ministry official told Argus . Japan is on track to reduce its GHG emissions by 46pc by the April 2030-March 2031 fiscal year from its 2013-14 level, and hit its net zero emissions goal by 2050. By Motoko Hasegawa and Yusuke Maekawa Japan CO2 emissions by sector Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

ADB grants Indonesia $500mn energy transition loan


24/09/23
24/09/23

ADB grants Indonesia $500mn energy transition loan

Singapore, 23 September (Argus) — The Asian Development Bank (ADB) has approved a $500mn loan to support Indonesia's energy transition through the Affordable and Sustainable Energy Transition programme. The programme aims to establish a policy and regulatory framework for a clean energy transition, strengthen sector governance and financial sustainability, and ensure a just transition towards net zero. Indonesia has set a target to reach net zero by 2060, but is heavily reliant on fossil fuels, which accounted for 80GW, or 86pc of total power generation capacity in 2023, according to a report by energy think-tank Ember. The country's renewable growth capacity has also been slow, with only 3.3GW of renewables added over 2018-23, bringing the total share of renewables to 13GW as of 2023. On the contrary, the country added 26GW of fossil fuel capacity over the same period, according to Ember. "This policy-based loan programme supports Indonesia's foundational and co-operative policy development to identify and address the sector's complex challenges to accelerate its shift towards sustainable energy," the ADB's country director for Indonesia, Jiro Tominaga, said. One of the main measures of the programme is to develop a Comprehensive Investment and Policy Plan (CIPP). A draft CIPP was published in November last year and it serves as a framework for the Just Energy Transition Partnership (JETP). Indonesia in 2022 entered the JETP, a financing mechanism through which it is supposed to receive $20bn from international partners like the US, EU, Japan and Canada to phase out coal and increase the share of renewables in its energy mix. But the JETPs have been long on promise and short on implementation, and need to be scaled up to be effective, according to a research report . Indonesia could need up to $12 trillion until 2050 to finance its energy transition away from coal , and the lack of additional financing could slow down the uptake of cleaner energy. Other measures under the programme include regulatory improvements to scale up renewable energy capacity and initiatives to strengthen the capacity and governance of state-owned energy firms. The ADB is working with French public financial institution Agence Francaise de Development and the German Development Co-operation through German bank kfW as co-financing partners "to support the government's leadership in energy transition," the ADB said. More details on how the funds will be used were not disclosed. The Asia-Pacific region holds significant investment opportunities in the energy transition. It needs at least $1.1 trillion/yr in climate financing, but actual investment falls short by at least $815bn/yr . The ADB estimated its investments in the region to have amounted to $10.7bn in 2023. By Prethika Nair Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Indonesian Sumsel 1 coal-fired unit eyes December start


24/09/18
24/09/18

Indonesian Sumsel 1 coal-fired unit eyes December start

Manila, 18 September (Argus) — The first 300MW unit of the 600MW Sumsel 1 mine-mouth coal-fired power plant in Indonesia's south Sumatra province is scheduled to begin commercial operations in December following several years of delays. The plant, which is located in Muara Enim regency, is being developed by China Shenhua Energy and Lion Power Energy, which have 75pc and 25pc respective stakes in the project. Once fully operational it is expected to consume around 2-3mn t/yr of coal. Lion will be responsible for sourcing the coal. The $750mn plant is part of Indonesia's 35GW power generation roadmap developed by the Indonesian government in 2015. The project was contracted to China Shenhua Energy in 2016. The first unit at the plant was originally scheduled for completion by 2020. But land acquisition delays and the Covid-19 pandemic and resulting restrictions on the movement of people and travel bans delayed construction, Lion said. Construction work on the plant structure is now in the final stages and operational testing is expected to begin soon. But hitting the operational target date also depends on the completion of a 275kV high-voltage line that will connect the plant to the grid, state-owned utility PLN said. The 80km transmission line will pass through four districts in south Sumatra. The local government is pushing for the acceleration of the voltage line construction and has instructed the sub-district head and local government offices to provide support for the power line construction, PLN said. Sumsel 1, once fully operational, will operate on a build-own-operate basis with a 25-year power supply contract with PLN, the utility said. By Antonio delos Reyes Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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