概要
欧州では、制裁措置により石炭の輸入先がロシアから他の供給国にシフトしています。電力ミックスにおける石炭の役割はピーク負荷用へとさらにシフトしており、今後のプランニングはより困難になっています。
アジア太平洋地域では、一般炭が電力・産業部門の柱であり続けています。世界の石炭貿易のフローと価格スプレッドは変化しており、主要供給国であるロシア、インドネシア、オーストラリア、南アフリカ、コロンビア、米国からのフローは、価格ダイナミクスと貿易障壁に対応して新しい市場に浸透しつつあります。
価格と市場動向を常に注視し、石炭市場が他のエネルギーやコモディティのベンチマークとどのように交差しているかを把握することが、今後数年間はより一層重要になってきます。
Latest coal news
Browse the latest market moving news on the global coal industry.
Freight issues disrupt Indonesian coal market
Freight issues disrupt Indonesian coal market
Singapore, 11 March (Argus) — Coal traders in the Indonesian thermal coal market have been facing issues fixing vessels this week due to a surge in bunker prices on the back of the US-Iran war, according to market sources. Some vessel operators defaulted on charter parties and claimed that ships could not bunker in time or proceed to scheduled loading ports, said a Singapore-based trader. A Chinese trading firm had difficulty getting any vessel fixtures this week and said that one vessel operator declined to quote because of a surge in bunker prices. Several shipowners have stopped offering vessels in the market, other market participants also said. A few shipping firms that are offering vessels in the spot market are asking for premiums which forced buyers to hold back, said an Indonesian coal producer. Some of the producer's customers have also requested delaying loading dates by a few days. "There is a complete risk-off behaviour happening now. Bunker is too volatile," said a market source at a major dry bulk shipping firm. The market needs to stabilise before people are willing to commit, he added. Vessel fixing has been quieter, and there has been a downtrend in available Panamax vessels on ballast to Indonesia to load coal, he said. Rising freight rates have largely deterred coal market participants from trading activity this week. Argus assessed Panamax freight rates to transport coal from Indonesia to south China reached $11.90/t on 10 March, up from $8.65/t on 27 February before the onset of the US-Iran war. By Nadhir Mokhtar Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Oil industry seeks EU methane regulation pause
Oil industry seeks EU methane regulation pause
Brussels, 10 March (Argus) — EU refiners and fossil fuel importers called for the application of the bloc's methane emissions regulation to be paused pending amendments. With no changes, the EU risks a self-inflicted supply shock equivalent to 2022 disruptions, with up to 43pc, or 114bn m³, of the bloc's 2024 gas imports and 87pc of its crude oil imports, or some 9.8mn b/d based on 2024 volumes, at risk of being non-compliant in 2027–2029, oil and gas producer body IOGP said. The EU cannot afford a regulatory supply shock in the current geopolitical context, said refiners body FuelsEurope and IOGP. The EU methane regulation entered into force in 2024 but has requirements for importers of crude oil, natural gas and coal on reporting methane emissions from 2027, for contracts concluded or renewed after 4 August 2024. Presenting a study commissioned from Wood Mackenzie, FuelsEurope and IOGP warned that no exporting country has been recognised as equivalent with EU monitoring, reporting and verification (MRV) standards, required from January 2027. Only some 7pc of global oil and gas production meets the reporting standards required by the methane regulation. Additionally, the study points to the lack of a recognized third-party verification protocol and accredited verifiers. Wood Mackenzie finds that EU refinery throughput could fall by some 50pc, or 4.6mn b/d in 2027–2030 as a result of insufficient compliant crude, equivalent to closing 40 EU refineries. Impacts would be less severe under an adaptive scenario, with greater flexibility in granting country-level MRV equivalence, according to Wood Mackenzie. But 20pc, 53bn m³, of natural gas imports and 38pc, 4.3mn b/d, of crude oil imports into the EU, in 2024 volumes, could still be excluded. EU energy ministers discussed their implementation concerns in December last year. The European Commission then noted that the methane regulation requires member states not to "endanger" security of supply when applying penalties. The commission said the methane regulation is open to different compliance solutions. Importers can show compliance through contractual evidence as well as methane MRV information, the commission told energy ministers. The study indicated that Europe's fuel import bill could rise by more than $17bn annually under the regulation. But it noted that while gas prices risk being over twice as high, they still fall "well short" of average prices in 2022 at the start of the Russia-Ukraine war. "We're not asking for five or ten years," said IOGP Europe managing director Francois-Regis Mouton. The industry wants time for discussion and for the EU to vote an amended regulation that can be implemented. "We don't need tens of changes in the regulation," added Mouton. By Dafydd ab Iago Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
LNG disruptions drive enquiries for Australian coal
LNG disruptions drive enquiries for Australian coal
Singapore, 10 March (Argus) — Australian coal producers and sellers are receiving increased enquiries for coal supplies, driven by LNG supply disruptions resulting from the US-Iran war. But actual physical buying has been cautious so far. Asian LNG inventories are so far ample, with South Korea likely holding sufficient LNG inventories to last more than a week . This is despite some regional importers having had their LNG vessels held up by the blockade of the strait of Hormuz, traders said. Despite this, elevated spot LNG prices continue to deter importers from seeking replacements for cargoes impacted by the blockade or from state-owned QatarEnergy's (QE) force majeure declaration . Taiwan has been actively procuring thermal coal supplies, with state-owned utility Taipower seeking 400,000t to be delivered in June-August through a tender closing on 17 March . The country is seeking to build thermal coal inventories to prepare for any potential shortfall in LNG supplies. Taiwan relies heavily on LNG for power generation, with LNG accounting for about 38.8pc of the fuel mix, while coal contributes roughly 20pc, according to Taipower data. The country's peak operating reserve (POR) stood at 17.85pc on 9 March, Taipower data show. The POR is a metric used to measure the daily "power supply reliability" to maintain operations. The current POR is considered to be of "adequate supply" exceeding 10pc, while POR within 6-10pc indicates "tight supply" and anything lower represents an emergency fuel situation. South Korean buyers have been approaching Australian coal producers for prompt supplies, but have been cautious in making purchases if prices do not match their expectations. South Korean state-owned utility Korea South-East Power (Koen) awarded a Panamax cargo of Australian NAR 5,000 kcal/kg coal for April-loading at $80/t fob Queensland through a tender that closed on 6 March, according to market sources. But Koen did not award any offers for its higher-calorific value (CV) coal tender. The generator likely received an offer for South African NAR 5,800 kcal/kg coal at $103/t fob Richards Bay, but it was not awarded, market participants said. Countries like South Korea have been more exposed to LNG prices as the fuel accounts for 29pc of its power generation mix while coal accounts for 26pc, according to Korea Power Exchange (KPX) data. Utilities in South Korea typically keep coal-fired generation flat for several months with slight periodic adjustments. There has been no adjustment to coal-fired generation in March so far, remaining capped at around 40.7GWh/month in 2026, down from around 40.8GWh/month throughout 2025, KPX data showed. Adequate Australian coal supply Australian producers can fulfil higher demand for thermal coal. Domestic production will outpace exports by 31mn t in the July 2025-June 2026 financial year and by 36mn t in 2026-27, Australian government forecaster the Office of the Chief Economist (OCE) said in December. Australian producers exported 128mn t of high-CV thermal coal in 2025, up by 28pc from the previous year but down from 192mn t in 2021, data from marine tracker Kpler show. Sustained coal-to-gas switching could lead producers to wash more medium CV coal into high CV coal. Chinese-Australian producer Yancoal increased its high CV share of production from 4pc in January-March 2022 to 33pc in April-June 2022 driven by switching after Russia-Ukraine conflict escalated in February 2022. But the gap between high CV and medium CV coal may not be high enough to warrant substantial switching yet. High CV coal traded at a $271/t premium over medium CV coal in 2022, justifying additional washing costs . In contrast, Argus ' Australian NAR 6,000 kcal/kg fob Newcastle price was last assessed at $129.95/t on 9 March, just $42.25/t above its Australian NAR 5,500 kcal/kg fob Newcastle price of $87.76/t. Producers could blend some lower-grade coking coal with thermal coal without facing additional costs. But it is too early for them to consider adjusting production schedules, a miner told Argus on 4 March. By Avinash Govind, Nadhir Mokhtar and Rou Urn Lee Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
PJM coal-fired power resumes gains in February
PJM coal-fired power resumes gains in February
Houston, 9 March (Argus) — Coal-fired power in the PJM Interconnection resumed year-on-year gains in February primarily because of lingering colder-than-normal weather in the first week of the month. Generators dispatched 483,253 MW/d of coal generation into PJM last month, up from 454,748 MW/d in February 2025, the grid operator's daily generation data showed. Last month's year-on-year rise in coal power picks up a trend that prevailed in most of 2025. Coal power had fallen from year-earlier levels in January 2026 for the first time since August 2025. Coal's share of PJM's fuel mix increased to 18.4pc last month from 17.9pc a year earlier, at least partly because the prolonged period of freezing weather starting in late-January extended into the first week of February. From 1-7 February, coal power in PJM averaged 636,316 MW/d, jumping from 371,341 MW/d a year earlier. But excluding the first week of the month, weather in the PJM region was mostly mild, and average coal power trailed the same period of 2025 by over 10pc. PJM had nearly the same amount of coal generating capacity available last month than it had in February 2025, during which time NRG retired its Indian River power plant in Delaware. No other coal plants within PJM's service territory were deactivated over the past year. Overall electric generation dispatched into PJM all of last month totaled 2.63mn MW/d, up by 3.3pc from February last year. Natural gas-fired power — PJM's dominant fuel source — also rose by 3.3pc from the previous year to 1.07mn MW/d in February, keeping gas' portion of the grid's overall generation unchanged at 42pc. Profit margins continued to favor coal power over gas in PJM West during the first few days of February when power prices and natural gas prices were elevated in response to the extreme winter weather. During the first week of February, the peak day-ahead spark spread for 10,000 Btu/kWh coal units in the hub averaged $109.53/MWh, while the spread for 8,000 Btu/kWh natural gas units averaged $43.78/MWh. But by the second week of February, natural gas had regained its competitive advantage in the hub and remained the more economic fuel source for the remainder of the month. Coal prices in the eastern US were higher last month than they had been in the same period last year. Prices for prompt quarter deliveries of Central Appalachian CSX rail-originated coal with 12,500 Btu/lb delivered to southwest Ohio averaged $4.24/mmBtu in February, up from $3.99/mmBtu a year earlier. And the monthly average for the price of Illinois basin coal with 11,500 Btu/lb 5lb SO2/mmBtu delivered to the same destination rose to $2.96/mmBtu from $2.48/mmBtu in February 2025. Eastern US spot gas prices moved in mixed directions. The day-ahead Columbia Gas index averaged $3.037/mmBtu in February, down from $4.004/mmBtu a year earlier, while the monthly average for the day-ahead Texas Eastern Transmission zone M-3 climbed to $5.882/mmBtu from $5.111/mmBtu in February 2025. Total renewable generation in PJM averaged 213,602 MW/d last month, slipping from 214,575 MW/d a year earlier, primarily weighed down by a 13pc drop in hydropower during the 12-month period. Wind and solar power still edged up in February by 4.3pc and 1.8pc, respectively, from the same month last year. Generation from PJM's renewable sources combined made up 8.1pc of the grid's fuel mix last month, down from 8.4pc a year earlier. Nuclear power in the grid also declined from the previous year in February, falling by 4.7pc to 768,104 MW/d, reducing nuclear's market share to 29pc from 31pc. By Anna Harmon Send comments and request more information at feedback@argusmedia.com Copyright © 2026. Argus Media group . All rights reserved.
Spotlight content
Browse the latest thought leadership produced by our global team of experts.
Spotlight content
Browse the latest thought leadership produced by our global team of experts.
Explore our coal products
Real time access to trusted price assessments, indexes, global market intelligence, analytics and outlooks for European, Asia-Pacific, Americas and African coal markets.
主な価格査定
アーガスの価格は、実際の市場価値を知る、信頼できる指標として市場で認められています。最も広く利用され、関連性の高い価格査定の一部をご覧ください。





