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Coronavirus to complicate Australian shipping

  • Spanish Market: Coal, Coking coal, Metals, Natural gas
  • 04/02/20

The Australian government's decision to impose a 14-day quarantine on vessels that leave mainland China after 1 February bound for Australian ports will cause scheduling issues for Australian energy and mineral shipments.

Pilots, who are used to guide bulk carriers, LNG carriers and other vessels into most Australian ports, and other Australia-based workers will not board vessels that left mainland China after 1 February until they have passed a 14-day quarantine period. This could cause delays for vessels arriving from China to Australian iron ore, LNG, bauxite and other mineral loading terminals in Western Australian (WA), the Northern Territory and far north Queensland, which are usually less than a 14-day journey from key Chinese ports. It may also cause delays for vessels that need Australian reef pilots to navigate the Great Barrier Reef on their approach to coal and LNG terminals in Queensland, as these personnel often join vessels some distance from the port.

Vessels must declare if any of the crew has symptoms, such as a fever, breathlessness or flu-like symptoms. If there is any sickness on vessels from mainland China within the quarantine period, then the quarantine will be restarted for a further 14 days.

The uncertainty created by the possible extension of quarantines is likely to cause particular problems for multi-user ports, like the WA iron ore and lithium concentrate export port of Port Hedland, as well as the coal and LNG port of Gladstone in Queensland. These ports operate complex schedules designed to maximise access to congested channels for multiple users.

Shipping queues are already longer than normal on the east coast of Australia because of increased activity and some difficult weather conditions over the past two weeks. The most northerly Queensland coal port of Abbot Point had 13 vessels queuing today, up from an average of around four, while Gladstone had 27 that is around double its average. The queue outside the adjacent coal ports of Hay Point and Dalrymple Bay Coal Terminal is at 26, which is only marginally above average, while the queue at Newcastle is at an 18-month high of 20 vessels.

By Jo Clarke


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12/05/25

Russia urges decision on Bolivia Li deal

Russia urges decision on Bolivia Li deal

Sao Paulo, 12 May (Argus) — The Russian ambassador to Bolivia today criticized what he described as Bolivian government stalling of a $970mn lithium concession deal with Russian-backed Uranium One Group. Dmitry Verchenko, in an interview with Bolivian state outlet Agencia Boliviana de Información, said the Bolivian congress is taking an "excessive" amount of time to reach a decision on the $970mn lithium concession deal signed in September 2024. The concession deal included the production of 14,000 metric tonnes (t)/yr of lithium carbonate equivalent (LCE) from the Uyuni salt flat — the largest lithium reserve in the world at 23mn t. Verchenko said that Uranium One, a subsidiary of state-owned atomic energy agency Rosatom, will build a pilot plant capable of producing 1,000t/yr LCE as soon as possible and follow up with gradual expansions. The project — which is still unnamed — will be the country's first direct lithium extraction (DLE) plant, a brine processing method that reduces LCE production time and water usage. Bolivian energy minister Alejandro Gallardo last month urged congress to approve both Russia's and China's CBC concession deals , but still no progress has been made. Congress in February said that it would only discuss the two deals after a nationwide round of public consultations that remains unscheduled. Political uncertainty delays Bolivia's Li hopes There is no forecast of when or if the concessions may be approved because Bolivia's congress is deeply divided between allies and political opponents of Luis Arce, the current president. Neither faction has the required majority for the bills to pass. The country will hold a presidential election in August and market participants expect a congressional vote on the matter may be pushed to next year because of uncertainty in the current polling ahead of the election. Russia looks further afield Verchenko added that Russian and Uranium One are waiting on the approval of the concession deal despite neighboring Argentina and Chile rapidly developing their lithium markets. Given the delay, Russia is already looking for alternative lithium solutions in Latin America with Brazil emerging as a potential partner . Following an in-person meeting with Russian president Vladimir Putin on 10 May, Brazilian president Luiz Inácio Lula da Silva confirmed that Brazil is actively seeking to collaborate with Russia to extract spodumene from the country's so-called Lithium Valley, a lithium-rich region located in the state of Minas Gerais. Bolivia's 2024 lithium carbonate output stood at 1,832t . By Pedro Consoli Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Ukrainian gas imports double in May


12/05/25
12/05/25

Ukrainian gas imports double in May

London, 12 May (Argus) — Ukraine's gas imports have nearly doubled in the first 10 days of May from April, although still only the Polish and Hungarian routes are being used. Ukraine's net imports — after netting off inflows and outflows to and from Moldova — averaged 140 GWh/d on 1-10 May, nearly double the 73 GWh/d average in April, the latest available data from transmission system operators show. The increase has been driven by flows from Hungary at VIP Bereg rising to near full capacity of 103 GWh/d from 60 GWh/d, and a smaller 12 GWh/d increase from Poland ( see flows graph ). Net flows to Moldova also fell to 13 GWh/d from 23 GWh/d, leaving more gas in Ukraine. But imports would need to ramp up significantly to match the 4.6bn m³ that state-owned incumbent Naftogaz estimated would be needed over the entire summer. If Ukrainian net imports remain at 140 GWh/d until 15 October, around the typical start of the heating season, then cumulative net imports would reach around 22TWh, or around 2.1bn m³ using Ukraine's standard 10.5 kWh/m³ conversion rate. VIP Bereg is already flowing at near maximum capacity, as is the interconnection point with Poland, meaning that any additional flows will need to arrive from Slovakia at Budince or from Romania at Isaccea, both particularly expensive transit routes. Demand for third-quarter capacity along the Bereg route continues to outstrip available capacity, with the auction now in its sixth day and still not concluded. So far, Naftogaz has announced few public supply deals, although it has contracted 300mn m³ of LNG from Poland's Orlen , with some market participants saying Orlen would supply as much as 1bn m³. The firm has €410mn in funds from the European Bank for Reconstruction and Development , which it hopes will finance the purchase of around 1bn m³. But it is unclear where funding for additional purchases will come from, and the government does not intend to increase household or business tariffs to cover Naftogaz's higher costs. Even if Ukraine imports as much as Naftogaz said it will need, the country could still face shortages in the winter . Ukraine started the injection season in mid-April at the lowest stock level in at least a decade , and while Naftogaz managed to restore more than half of the output it lost in February following attacks on its production infrastructure, Ukrainian production still remains well below pre-2022 levels. Hungary maintains pivotal hub role Hungary has become an increasingly important transit hub over the past year, and Ukraine's import needs have increased its prominence further. With VIP Bereg at a 99pc utilisation rate this month and continued exports northward to Slovakia, Hungary has been pulling in more gas from other sources to maintain these flows. Inflows from Serbia at Horgos, where Russian gas arrives into Hungary through Turkish Stream, rose to 244 GWh/d on 1-10 May from 223 GWh/d in April, just below the point's technical capacity of 246 GWh/d. And inflows from Austria have also increased considerably, rising to 139 GWh/d from 92 GWh/d, while receipts from Romania more than doubled to 40 GWh/d from 19 GWh/d ( see Hungarian flows graph ). Hungarian prompt prices have risen to a premium over Austria and Romania in order to attract more gas ( see prices graph ). Slovakia remains at a premium to Hungary, though, driven by the need to incentivise flows from Hungary now that Russian transit through Ukraine has ceased. Hungarian transmission tariffs remain significantly cheaper than in Slovakia or Romania, so demand for Hungarian capacity at quarterly auctions last week held strong . The bookings suggest that the recent flow configuration is set to continue in the second half of summer, with all import capacity from Serbia booked and most available capacity from Austria. The export route from Romania to Ukraine remains unpopular, not just because of the high transmission tariffs paid in Romania and Moldova, but also because of the conditional nature of the flows. An equal amount of gas must be brought into Romania at Negru Voda 1 as is exported at Isaccea 1, as they are part of the same Trans-Balkan Pipeline string. Additionally, anyone hoping to bring gas from Greece or Bulgaria up to Ukraine must secure capacity in as many as 10 or more auctions, which take place simultaneously given that the transit route crosses in and out of Moldova several times. Even one failed auction could make exports along this route impossible. By Brendan A'Hearn Hungarian DA vs nearby markets €/MWh Ukrainian net flows by point GWh Hungarian net flows by point GWh Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

US shale M&A faces headwinds on oil price rout


12/05/25
12/05/25

US shale M&A faces headwinds on oil price rout

New York, 12 May (Argus) — Dealmaking in the US shale patch, which had been on a roller-coaster ride in the past few years, is at risk of grinding to a halt as a result of an oil price slump. Just as a growing number of producers are unveiling plans to cut spending and slow activity as crude prices teeter around levels needed to profitably drill wells, prospects for mergers and acquisitions (M&A) in the shale patch are also souring. That marks a departure from the start of 2025 , when dealmakers were expecting a bumper year with recent acquirers looking to offload non-core assets and private equity gearing up to make a return after raising new funds. April brought five deals with a combined value of $2.3bn, bringing the year-to-date total for M&A activity in the US upstream space to $19.2bn, consultancy Enverus says. That was down by 60pc from a year earlier, when the latest round of consolidation was in full sway. "We're just hearing over and over again, across the board, that companies are overwhelmingly sitting on their hands," law firm Sidley partner Stephen Boone says. Recent deals include natural gas giant EQT buying the upstream and midstream assets of privately held Olympus Energy for $1.8bn . Gas is increasingly likely to dominate dealmaking going forward, as not only has the commodity fared better than oil on a relative basis, but investors are likely to be drawn by the US LNG boom and rapid growth of gas-fired power generation demand to meet the energy needs of data centres required for artificial intelligence . "The trouble is, there aren't enough potential gas deals to make up for a drop in oil asset activity, which we do anticipate is going to fall off a cliff," Enverus principal analyst Andrew Dittmar says. Aside from the trade tariff-induced market volatility that has sent crude prices tumbling to four-year lows, a lack of high-quality targets on the oil side also suggests deals will be few and far between this year. Most publicly-held operators will be focused on protecting their bottom line as they remain focused on shareholder returns rather than growth, and might well be reluctant to take on debt to fund deals. And private equity may prefer to bide its time. "That group is likely looking for some sign of a bottom on crude before jumping in, rather than trying to catch a falling knife of asset values," Dittmar says. That is not to say that deals have completely dried up, with Permian Resources agreeing this week to snap up assets in the New Mexico part of the top US shale play from APA for $608mn. But Diamondback Energy, a top Permian producer which has played an active role in the most recent round of M&A, might sum up the view of many with its plan to remain on the sidelines for the time being. Too much noise "We're in the period right now where there's so much noise and volatility that not a lot gets done," Diamondback's president, Kaes Van't Hof, says. "Anything that we would look at would have to be extremely cheap, and I just don't think we're there yet today." Even if some relief comes on the tariff front and the economy avoids a recession, it will take time for deals to pick up again, and that could push a resurgence in dealmaking well into 2026. The fact that public operators have spent the years since the pandemic on repairing balance sheets and focusing on investor payouts might also count against any uptick in transactions anytime soon. "That's actually going to keep M&A down, because now that we see the downturn, we have significantly less distressed companies out there that will be forced to sell, and we have more and more companies that think they are better situated to just ride it out," Sidley's Boone says. By Stephen Cunningham Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Tata UK lambasts importers' TRA submissions


12/05/25
12/05/25

Tata UK lambasts importers' TRA submissions

London, 12 May (Argus) — Claims by the International Steel Trade Association and importers in the Trade Remedies Authority's (TRA) safeguard review are "factually incorrect", Tata Steel UK has said Importers have stated — accurately — that Tata does not produce 2m-wide hot-rolled coil, or material with a tensile strength of over 500 megapascal, so these products should not be under the scope of the safeguard. In a rebuttal submission released by the TRA today, Tata said such specifications "constitute a small proportion of the overall market", and that current quotas are more than sufficient to provide import choice. Should these grades be excluded from the safeguard, Tata — which is effectively a re-roller until its electric arc furnace becomes operational — said importers could circumvent the safeguard, importing higher grades "at much lower prices" to compete with material produced and sold by Tata. Tata said wider coil is "often imported only to be slit into narrower cuts", meaning it is not fundamentally different from material it sells domestically. Some applications do require decoiled 2m-wide material, but Tata suggests this is a small proportion of the overall market. No end-users have raised concerns regarding supply of such material, Tata said, adding that sufficient tonnes could be imported from the EU or Turkey, origins with quotas that are "consistently underutilised quarter after quarter". Buyers just want such products to be excluded so they can "access significantly lower-priced imports", it said. Tata has requested quotas be amended in line with the demand reduction seen in recent years, and that caps are implemented on other countries' quota for hot-dip galvanised. Should a cap of 25pc be imposed, which is what the market anticipates, some traders said material currently on route to the UK could still be clearing in January 2026. The TRA is expected to release its initial findings this week. By Colin Richardson Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

Saudi Aramco cuts dividend after fall in 1Q profit


12/05/25
12/05/25

Saudi Aramco cuts dividend after fall in 1Q profit

Dubai, 12 May (Argus) — State-controlled Saudi Aramco has announced a sharp cut to its quarterly dividend after reporting a 5pc year-on-year decline in profit for the first three months of 2025. The company's profit fell to $26.01bn in January-March from $27.3bn in the same period last year after lower oil prices squeezed revenues. Aramco said its bottom line was also hit by higher operating costs. The company said it sold its crude for an average $76.30/bl in January-March, down from $83/bl the first quarter of 2024. "Global trade dynamics affected energy markets in the first quarter of 2025, with economic uncertainty impacting oil prices," Aramco's chief executive Amin Nasser said. The company said its overall dividend for the quarter will be $20.61bn, down from $31bn in the corresponding period in 2024. The steep drop is due to the performance-linked element of the dividend being slashed to just $219mn for the quarter, from $10.7bn a year earlier. Aramco already announced in March that it expected its dividends for the full year to fall to $85.4bn from $124.3bn in 2024. Despite the current economic uncertainty, Aramco's capital expenditure (capex) rose to $12.5bn for January-March from $10.83bn in the same period last year, although this puts investment broadly in line with the lower end of the full-year 2025 capex guidance of $52bn-58bn that the company announced in March. The aggressive capex programme will help drive growth plans for the downstream and new energies sides of Aramco's business, as well as fund the firm's strategy to maintain its maximum sustainable crude capacity at 12mn b/d and expand its gas output by 60pc by 2030 compared with 2021 levels. By Nader Itayim Send comments and request more information at feedback@argusmedia.com Copyright © 2025. Argus Media group . All rights reserved.

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