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Australian resource investment rises in 2021

  • : Coal, Coking coal, Hydrogen, Metals, Natural gas
  • 21/12/19

Investment in committed resource and energy projects in Australia rose in the 12 months to the end of October from a year earlier, led by increased investment in iron ore and upstream oil and gas that reflect a catch-up on projects deferred from 2020 because of the impact of the initial spread of the Covid-19 pandemic.

The value of committed projects rose to A$54bn ($38.7bn) for the period from [A$39bn] (https://direct.argusmedia.com/newsandanalysis/article/2162301) a year earlier, according to Australia's Office of the Chief Economist (OCE).

The outlook for resources and energy investment suggests that 2021 represented significant growth in the resources investment cycle. The rise in resource investment was driven by iron ore, upstream and battery metals projects.

More than A$11bn had been committed to oil and gas/LNG projects in the 12 months to 31 October. Most of this is attributed to two projects that reached a final investment decision in 2021, the Barossa backfill gas project and the Jansz-lo compression project for the 15.6mn t/yr Gorgon LNG offshore Western Australia (WA).

The report does not include the largest upstream venture to be sanctioned in Australia in around a decade, the $12bn Scarborough gas project, as it was given the go-ahead after the OCE report was concluded.

The value of projects completed in the 12 months to 31 October rose to A$10.1bn from A$2.3bn a year earlier. A total of 15 resource and energy major projects were completed in the period with completed iron ore projects dominating. This was because of the completion of the A$4.6bn South Flank iron ore mine, the Eliwana iron ore mine and the commissioning of the

West Angelas Deposits C & D expansion project.

The investment report now includes hydrogen, ammonia and carbon capture and storage projects, which account for A$185bn worth of investment, which are largely at the publicly announced phase of the investment cycle and not in the feasibility or committed stage. The inclusion of hydrogen has pushed the total value of potential resource and energy projects to more than A$536bn at the end of October from A$372bn 12 months earlier.

Developments in battery technology and expectations of growing electric vehicle manufacturing, continue to spur investment in Australia's nickel, cobalt, rare earths and lithium resources with 60 possible projects with a combined value of around A$29bn,. A number of development projects are investing in processing facilities to produce battery cathode precursors in the form of lithium hydroxide.

Around 20pc of projects at the feasible stage are driven by demand for commodities used in rechargeable batteries, the OCE said. The largest proportion of projects at the feasibility stage are in WA, including a number of prospective nickel-cobalt projects.

Australia resource/energy investment plans at 31 October 2021(A$bn)
No. of projectsValue A$bnProjects in feasibilityValue A$bnCommitted projectsValue A$bnCompleted projectsValue A$bnTotal projectsValue A$bn
Coal2321-25+3745-51+83.712.06972-82+
Hydrogen11127-133+66-52+10.521135-185+
Iron ore128-10+1216-22+611.046.43441-50+
LNG, gas, petroleum1426-29+1565-71+1323.030.745115-123+
Critical minerals102.6-5.3+196-10+94.420.34013-20+
Total113203-229+160163-243+7954.01510.1367434-536+
Investment plans at 31 October 2020
Coal2117-204557-6563.410.97277-89
iron ore1514-181219-2547.510.13241-51
LNG, gas, petroleum1433-481977-831020.010.844130-152
Total10688-119168175-2115439.082.2335300-372

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24/11/22

Japan’s Taketoyo to resume biomass co-firing in 2027

Japan’s Taketoyo to resume biomass co-firing in 2027

Tokyo, 22 November (Argus) — Japan's largest electricity producer Jera aims to resume coal and biomass co-firing at the 1.1GW Taketoyo plant in 2027's first quarter, after a fire halted plant operations in January. Jera announced on 22 November that the thermal power plant in central Japan's Aichi prefecture would resume co-firing wood pellets with coal at a rate of 8pc, around the end of the 2026-27 fiscal year ending in March. This will come after its safety measures are completed. The plant's co-firing rate was 17pc before the serious fire, which was caused by an explosion of dust from wood pellets. The company will consider increasing the co-firing rate again in the future, provided safety can be ensured. But the plant will restart coal-only combustion in early January 2025, operating mainly during the summer and winter seasons, when electricity demand is high. Jera will keep operation rates low at Taketoyo and other coal-fired plants when electricity demand is low and rely more on gas-fired generation, to achieve its initial plan to cut CO2 emissions through co-firing at Taketoyo. Taketoyo started co-firing operations in August 2022 and burned around 500,000 t/yr of wood pellets imported from the US and Vietnam. It will burn 200,000 t/yr after it resumes co-firing at 8pc. The plant will slow down the speed of wood pellet conveyors to reduce friction as a part of safety measures, which means it must also reduce its coal and biomass co-firing rate. It is also currently working on other safety measures, such as installing air pressure conveying facilities dedicated to wood pellets and explosion suppressor systems to inject fire extinguishing agents. The outage at Taketoyo has encouraged Jera to boost replacement gas-fired generation, with the extra gas-fired costs accounting for most of the estimated cost resulting from the shutdown, which could be tens of billion yen in the 2024-25 fiscal year ending in March. By Takeshi Maeda Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

US alleges Nippon dumped HRC at higher rates


24/11/21
24/11/21

US alleges Nippon dumped HRC at higher rates

Houston, 21 November (Argus) — The US government alleged that Japanese steelmaker Nippon Steel dumped hot-rolled (HR) flat steel products at higher rates than previously determined. The US Department of Commerce's International Trade Administration (ITA) determined that during the period from October 2022 through September 2023, Nippon sold HR steel flat products with a weighted-average dumping margin of 29.03pc, up from the 1.39pc dumping margin the ITA determined for the prior period of October 2021 through September 2022. Tokyo Steel Manufacturing, which was also investigated, was determined to have not sold HR flat steel below market value, unchanged from a prior review. US imports during the period from October 2022 through September 2023 of the investigated items from Japan were 202,000 metric tonnes (t), down from the 293,600t imported in the same period the prior year, according to customs data. The original investigation into imports of Japanese flat-steel products was concluded in 2016. The ITA is now reviewing the time period of October 2023 through September 2024 and expects to issue the final results of these reviews no later than 31 October 2025. The US imported 235,700t of the investigated products from Japan during that time, customs data showed. By Rye Druzchetta Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Cost of government support for fossil fuels still high


24/11/21
24/11/21

Cost of government support for fossil fuels still high

London, 21 November (Argus) — The cost of government measures to support the consumption and production of fossil fuels dropped by almost third last year as energy prices declined from record highs in 2022, according to a new report published today by the OECD. But the level of fiscal support remained higher than the historical average despite government pledges to reduce carbon emissions. In an analysis of 82 economies, data from the OECD and the IEA found that government support for fossil fuels fell to an estimated $1.1 trillion in 2023 from $1.6 trillion a year earlier. Although energy prices were lower last year than in 2022, countries maintained various fiscal measures to both stimulate fossil fuel production and reduce the burden of high energy costs for consumers, the OECD said. The measures are in the form of direct payments by governments to individual recipients, tax concessions and price support. The latter includes "direct price regulation, pricing formulas, border controls or taxes, and domestic purchase or supply mandates", the OECD said. These government interventions come at a large financial cost and increase carbon emissions, undermining the net-zero transition, the report said. Of the estimated $1.1 trillion of support, direct transfers and tax concessions accounted for $514.1bn, up from $503.7bn in 2022. Transfers amounted to $269.8bn, making them more costly than tax concessions of $244.3bn. Some 90pc of the transfers were to support consumption by households and companies, the rest was to support producers. The residential sector benefited from a 22pc increase from a year earlier, and support to manufacturers and industry increased by 14pc. But the majority of fuel consumption measures are untargeted, and support largely does not land where it is needed, the OECD said. The "under-pricing" of fossil fuels amounted to $616.4bn last year, around half of the 2022 level, the report said. "Benchmark prices (based on energy supply costs) eased, particularly for natural gas, thereby decreasing the difference between the subsidised end-user prices and the benchmark prices," it said. In terms of individual fossil fuels, the fiscal cost of support for coal fell the most, to $27.7bn in 2023 from $43.5bn a year earlier. The cost of support for natural gas has grown steadily in recent years, amounting to $343bn last year compared with $144bn in 2018. The upward trend is explained by its characterisation as a transition fuel and the disruption of Russian pipeline supplies to Europe, the report said. By Alejandro Moreano and Tim van Gardingen Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Investment funds’ net long on Ice TTF reaches new high


24/11/21
24/11/21

Investment funds’ net long on Ice TTF reaches new high

London, 21 November (Argus) — Investment funds' net long TTF position on the Intercontinental Exchange (Ice) jumped to a new all-time high earlier this month, outstripping the previous record in late August. The latest weekly data from Ice show investment funds' net long TTF position shot up to a new record at just under 273TWh by 15 November, topping the previous all-time high of roughly 268TWh in the week ending 30 August , revised data show. After peaking in August, the position dropped to 192TWh on 20 September, and held broadly stable before jumping 33.6TWh in the week ending 25 October . TTF prices rose in the following two weeks, but funds trimmed their net long position to around 226TWh on 8 November ( see graph ). But in the most recent week of data from Ice, investment funds' net long position shot up to just under 273TWh by 15 November, a new record high. Over the same period of 8-15 November, The Argus TTF front-month contract rose by more than 9pc, and there were similarly large moves for the first-quarter 2025 and summer 2025 contracts. The calendar 2025 price was also up by 8pc ( see table ). Significant price volatility in recent trading sessions has also prompted Ice to increase margin rates by around 20pc on all contracts out to September 2025 , with smaller increases further down the curve. Austrian incumbent OMV announced this week Russia's Gazprom would halt its contractual supply from 16 November , prompting sizeable day-on-day price moves across Europe and possibly encouraging investment funds to go longer and capitalise on the volatility. But central European flows have changed only slightly since then, with roughly the same amount of Russian gas entering the region. Higher TTF prices have also caused LNG diversions from Asia to Europe in recent days, which reached double digits on 19 November . Such a large net long position suggests investment funds may still expect a tight European gas balance this winter. Record-low freight rates have brought the cost of shipping US LNG to Asia closer to the cost of the shorter US-Europe route, meaning European prices have to rise sufficiently high enough to offset this and close the inter-basin arbitrage again in order to attract uncommitted cargoes. Cold weather has also prompted EU firms to draw down storage stocks heavily so far this month . Aggregate EU withdrawals averaged just under 3 TWh/d on 1-15 November, four times the 756 GWh/d average for that period in 2018-22 and sharply contrasting the 965 GWh/d of net injections across the bloc on 1-15 November 2023. Unlike investment funds, the two other major categories of Ice market participant — commercial undertakings and investment/credit firms — boosted their net short positions by a combined 53TWh, leaving the latter with nearly 200TWh in net shorts, the highest since mid-September. Despite significant storage withdrawals, commercial undertakings ‘risk reduct' contracts — generally used for hedging — in the week to 15 November jumped by just under 30TWh to nearly 211TWh, the highest since 24 December 2021. Some of that increase may have been driven by a need to hedge the LNG cargoes diverted to Europe in recent weeks as European hub prices rose. A 9TWh increase in the net long position of commercial undertakings' other contracts slightly moderated the overall net short increase. The gross short and long positions of commercial undertakings totalled 1.95PWh, nearly twice as large as the investments funds' 646TWh and investment/credit firms' 421TWh combined. By Brendan A'Hearn Argus TTF prices 8-15 Nov €/MWh Dec-24 1Q25 Sum 25 Win 25 Cal 25 8-Nov 42.08 42.31 40.81 38.41 40.65 15-Nov 46.02 46.12 44.12 41.00 43.98 % change 9.4 9.0 8.1 6.7 8.2 Argus Net positions on ICE TTF TWh Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

Cop: Talks in Baku torn between mitigation and finance


24/11/21
24/11/21

Cop: Talks in Baku torn between mitigation and finance

Edinburgh, 21 November (Argus) — Developing and developed nations remain at loggerheads on what progress on climate finance and mitigation — actions to cut greenhouse gas emissions — should look like at the UN Cop 29 climate summit. But Cop 30 host Brazil has reminded parties that they need to stick to the brief, which is finance for developing countries. Concluding a plenary where parties, developed and developing, listed grievances, environment minister Marina Silva recognised "the excellent progress achieved" on mitigation at Cop 28. She listed paragraphs of the Cop 28 deal, including the energy package and its historic call to transition away from fossil fuels in energy systems. "We are on the right track," she said, talking about mitigation, but "our greatest obligation at this moment is to make progress with regard to financing". "This is the core of financing that will pave our collective path in ambition and implementation at Cop 30," Silva said, adding that $1.3 trillion for developing countries should be "the guiding star of this Cop". Parties are negotiating a new collective quantified goal (NCQG) — a new climate finance target — building on the $100bn/yr that developed countries agreed to deliver to developing countries over 2020-25. But developed countries insist that a precise number for a goal can only be produced if there is progress on mitigation and financing structure for the NCQG. "Otherwise you have a shopping basket but you don't know what's in there," EU energy commissioner Wopke Hoekstra said. Some developing nations said they need the "headline number first". Some developing countries, including Latin American and African nations as well as island states, have also complained about the lack of mitigation ambition. Cop is facing one of the "weakest mitigation texts we have ever seen," Panama said. But they also indicated that financial support was missing to implement action. Developed countries at Cop 29 seek the implementation of the energy pledges made last year. "What we had on our agenda was not just to restate the [Cop 28] consensus but actually to enhance and to operationalise that," but the text goes in the opposite direction, Hoekstra said, talking about the latest draft on finance. Whether hints that Brazil has mitigation in focus for next year's summit will be enough to assuage concerns from developed countries at Cop 29 on fossil fuel ambitions remains to be seen. The communique of the G20, which the country hosted, does not explicitly mention the goal to transition away from fossil fuels either. The developed countries' mitigation stance grew firmer after talks on a work programme dedicated to mitigation, the obvious channel for fossil fuel language, was rescued from the brink of collapse last week. Discussions have stalled, but another text — the UAE dialogue which is meant to track progress on the outcomes of Cop 28 — still has options referring to fossil fuels. But in these negotiations too, divisions remain. "The UAE dialogue contains some positive optional language on deep, rapid and sustained emissions reductions and the [Cop 28] energy package, climate think-tank E3G said. But Saudi Arabia has made clear that this was unacceptable, while India, which worked to water down a coal deal at Cop 26, is pushing back on the 1.5°C temperature limit of the Paris Agreement. Negotiators are starting to run out of time. Draft after draft, the divide fails to be breached with no agreement on an amount for the finance deal. "We cannot talk about a lower or higher number because there is no number," noted Colombia's environment minister Susana Muhamad. The next iteration should have numbers based on the Cop 29 presidency's "view of possible landing zones". The fact that the draft text on finance has no bridging proposal is a concern, non-profit WRI director of international climate action David Waskow said. Finance was always meant to be the centrepiece of Cop 29. Parties have not formally discussed the goal in 15 years, and have been trying to prepare for a new deal through technical meetings for the past two years. But the discussion needs to end in Baku. By Caroline Varin Send comments and request more information at feedback@argusmedia.com Copyright © 2024. Argus Media group . All rights reserved.

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