Soaring Power Costs May Drive Up Indian Ferro-Silicon Prices and Curtail Production

Ferro-Silicon

Ferro-silicon producers in Meghalaya, India, are facing a challenging period due to rapidly increasing power costs. On 26 October 2024, the Meghalaya State Electricity Regulatory Commission raised the electricity tariff by 1.47 rupees/kWh, bringing the new rate to Rs 6.47/kWh. This tariff hike, which is set to remain in effect until March 2025, is putting immense pressure on the region’s ferro-silicon industry, known for its energy-intensive production processes.

As a result of these rising energy costs, producers in Meghalaya have already reduced their output by 15-20%, and further increases in power tariffs could significantly impact their profit margins. Sources indicate that the combination of higher power costs and strict environmental regulations could lead some producers to cut back further on production or even shut down operations entirely if price adjustments for ferro-silicon do not sufficiently offset the added energy expenses.

Ferro-silicon production requires a large amount of electricity, with approximately 8,500 kWh of power needed for every tonne of ferro-silicon produced. As such, the new tariff will increase the cost of production by more than Rs 12,000 per tonne (approximately $142.71 per tonne), which is significantly higher than the previous year's energy costs. Given the competitive nature of the global ferro-silicon market, this cost increase may lead to higher prices for consumers while squeezing producers’ margins.

Although some producers in Meghalaya restarted their operations in mid-October after a temporary shutdown caused by stricter environmental regulations, the persistent rise in energy costs is threatening to disrupt the recovery. Producers are now at a crossroads—if the November ferro-silicon prices fail to reflect the higher power costs, several facilities may be forced to shut down again, exacerbating supply shortages and potentially driving further price increases.

The Future Outlook for Indian Ferro-Silicon Production

With India being a significant global producer of ferro-silicon, especially in regions like Meghalaya, the outcome of this energy crisis will have wide-reaching implications. If producers continue to struggle with escalating electricity costs, the production slowdown could not only raise domestic prices but also affect export markets. As ferro-silicon is a crucial component used in steelmaking, any supply disruptions in India could put pressure on the global supply chain.

Despite the challenges, the situation presents an opportunity for alternative power solutions, such as renewable energy, to help stabilize production costs. However, without significant intervention or price adjustments, the future of India's ferro-silicon production may be uncertain in the coming months.

EU Unveils Draft Plan to Cut Soaring Energy Costs and Safeguard Industrial Competitiveness

The European Commission

European Commission Pushes for Tax Reforms and Clean Energy to Address Rising Electricity Prices

The European Commission has introduced a draft strategy to combat the EU's growing energy cost burden and avoid de-industrialisation. The plan, released in a draft document, stresses that Europe must narrow its energy price gap with global competitors to retain industrial strength.

Much of the proposal consists of non-binding recommendations, especially on energy taxation. The Commission highlights fossil fuel dependence, high network costs, and heavy taxation as key drivers of price volatility. These factors, officials warn, are making EU industries less competitive on the global stage.

Tax Relief and Market Reforms at the Core of the Strategy

To reduce the electricity cost burden, the EU proposes lowering taxes on power for both energy-intensive industries and households. The plan encourages EU member states to cut electricity taxes to nearly zero. Officials also want to reduce or remove non-energy components from energy bills.

The Commission plans to revive the long-stalled effort to revise the 2003 Energy Taxation Directive, though this would require unanimous agreement across all member states. Additionally, a new Energy Union Task Force will lead efforts to create a fully integrated EU energy market in 2024.

Other key initiatives include an electrification action plan, a digitalisation roadmap, and a heating and cooling strategy. These aim to streamline energy systems, reduce consumption, and accelerate the shift to clean energy.

Flexibility, Renewables, and Future-Proofing the Grid

The draft strategy also promotes consumer empowerment, urging member states to remove barriers to supplier switching, improve energy efficiency, and support renewable energy communities. The Commission will propose measures to decouple retail electricity prices from gas prices, which have remained volatile since 2022.

By 2026, the EU plans to issue guidance on combining Power Purchase Agreements (PPAs) with Contracts for Difference (CfDs). The Commission is also considering new rules for forward markets, hedging instruments, and a possible legally binding tariff methodology for network charges.

In terms of infrastructure, the EU will push for faster permitting of new energy projects and encourage demand response and energy storage to improve system flexibility. Officials estimate that replacing fossil fuels with clean electricity could save 50% on power costs. Electrification and efficiency upgrades would save another 30%, and flexibility improvements could deliver 20% more savings.

As part of long-term planning, the Commission is exploring LNG supply deals and infrastructure investments to stabilize prices and ensure energy security across the bloc.

Alcoa San Ciprián Smelter Restart Targets Full Capacity by Mid-2026

Alcoa

Alcoa San Ciprián smelter restart plans will bring the company’s 228,000 t/yr Spanish aluminium site back to full capacity by mid-2026. The restart marks an important recovery step for European aluminium smelting after the site was closed in 2022 because of high Spanish energy costs.

Alcoa San Ciprián smelter restart progress reached 65pc completion by the end of December 2025. The company reopened the facility last year as part of a wider move to restore previously idle capacity across its global smelting portfolio.

The restart is strategically important because European aluminium smelting remains highly exposed to power costs, policy pressure, and import competition. Bringing San Ciprián back online improves Alcoa’s production base, but it also highlights the continuing challenge of operating energy-intensive aluminium assets in Europe.

Smelter Ramp-Ups Lift Alcoa’s Active Capacity

Alcoa also ramped up production at its previously dormant Alumar smelter in Brazil and Lista smelter in Norway during 2025. These three restarts reduced the company’s idle smelting capacity from 376,000 t/yr to 196,000 t/yr.

The company has a base smelting capacity of 2.6mn t/yr. Its 2026 aluminium production guidance remains unchanged at 2.4mn-2.6mn t, up from 2.3mn t produced in 2025. This indicates that the ramp-ups should support higher output this year.

Alcoa San Ciprián smelter restart also carries broader supply-chain meaning. More operating capacity in Spain could support regional aluminium availability, but sustained competitiveness will depend heavily on power prices and long-term energy arrangements.

Tariffs and Premiums Reshape Aluminium Economics

Alcoa faced significant tariff-related costs in 2025, with aluminium import tariffs adding $571mn over the year. The company said tariff pressure also helped push Midwest aluminium premiums up by 211pc.

Higher Midwest premiums have recently been high enough to fully cover Alcoa’s tariff costs. This shows how trade policy can reshape aluminium market economics by shifting costs through regional premiums and changing the value of domestic or tariff-protected supply.

For aluminium buyers, the implication is clear. Smelter restarts may increase physical supply, but tariffs, premiums, energy costs, and regional policy structures will continue to influence delivered metal costs. Aluminium supply is no longer just a question of tonnage; it is increasingly a question of location, power security, and trade exposure.

The Metalnomist Commentary

Alcoa’s San Ciprián ramp-up shows that aluminium capacity can return when market and policy conditions improve, but energy remains the real competitiveness test. In the US, tariffs are being absorbed through premiums; in Europe, power costs still decide whether smelting capacity can survive.

EU ETS Clean Energy Booster Signals Shift Toward Industrial Energy Relief

EU ETS

EU ETS clean energy booster plans could reshape Europe’s climate finance and industrial competitiveness strategy. The European Commission will propose a €30 billion clean energy investment package financed by 400 million emissions trading system allowances.

The proposal comes as the EU prepares a wider ETS review. Commission President Ursula von der Leyen said the review will set a more realistic path for phasing out allowances and extend free allocations for industry beyond 2035.

The EU ETS clean energy booster reflects a political adjustment in Europe’s decarbonisation model. Brussels still wants emissions reduction, but it is also responding to energy cost pressure on manufacturers, metals producers, chemical companies, and other energy-intensive sectors.

ETS Review Balances Carbon Pricing With Industrial Competitiveness

The ETS has reduced gas consumption and strengthened Europe’s carbon market framework. However, high energy prices, fossil fuel volatility, and the merit order power pricing system have exposed major cost risks for European industry.

The planned review will include short-term measures to update ETS benchmarks for free allocations. It will also strengthen the Market Stability Reserve to reduce carbon price volatility.

Extending free allocations beyond 2035 is significant for heavy industry. Steel, aluminium, cement, chemicals, fertilizers, and refining all face pressure from carbon costs, power prices, and global competition from regions with lower energy and compliance costs.

Clean Energy Funding Targets Power Costs and Supply Security

The EU ETS clean energy booster is designed to accelerate investment in cleaner energy systems while protecting industrial users from excessive cost pressure. Member states can already use state aid to offset energy cost increases, while the Commission is working on national schemes to reduce fuel cost impacts on power generation.

The Commission is also considering lower grid charges for energy-intensive industries and a tax structure that makes electricity more competitive than fossil fuels. These steps matter because electrification only works if industrial power remains affordable and reliable.

The maritime sector will also feature in the ETS review, with Brussels seeking a more level playing field. At the same time, European leaders remain focused on physical energy security, including oil, gas, fertilizers, and maritime transit risks linked to geopolitical instability.

The Metalnomist Commentary

The EU ETS clean energy booster shows that Europe is recalibrating climate policy around industrial survival. Carbon pricing will remain central, but the next phase will depend on whether Brussels can cut emissions without pushing energy-intensive production offshore.

EU Russian Energy Imports Ban Holds Firm Despite New Energy Crisis

EU Russian Energy

EU Russian energy imports will not return under the European Commission’s current policy direction, even as the bloc faces renewed energy pressure from the Middle East conflict. EU energy commissioner Dan Jorgensen said Brussels will continue phasing out Russian gas and still plans to cut Russian oil imports.

EU Russian energy imports have become a strategic red line for Brussels. The Commission argues that returning to Russian supply would recreate the dependency that exposed Europe after Russia’s full-scale invasion of Ukraine in 2022.

EU Russian energy imports are again being debated because higher oil and gas costs are hitting parts of the European economy. However, Brussels is treating the current disruption as a reason to accelerate energy diversification, not reopen Russian supply channels.

The position links energy security directly to industrial resilience. Europe now wants less exposure to both Russian energy and Middle East supply disruption, while shifting more demand toward domestic, renewable and alternative energy systems.

Russian Oil Phase-Out Remains Politically Sensitive

The Commission has not yet presented new legal measures to phase out Russian oil imports. It delayed a proposal originally scheduled for 15 April and has not set a new publication date.

Still, Brussels says a permanent Russian oil ban remains a priority. That matters because Hungary and Slovakia remain the only EU importers of Russian crude, keeping pipeline supply through Druzhba at the centre of political negotiations.

Hungary had opposed blocking Russian oil imports under Viktor Orban. His successor, Peter Magyar, has acknowledged that Hungary cannot end Druzhba imports immediately, but has pledged to eliminate dependence on Russian energy by 2035.

Slovakia has also linked Russian oil flows to its support for further sanctions against Moscow. Bratislava has indicated it could support another sanctions package once Russian oil reaches Slovakia through the Druzhba pipeline.

This shows the difficulty of EU energy policy. The bloc wants a unified strategic position, but member states still have different infrastructure, refinery configurations and supply dependencies.

The Druzhba pipeline therefore remains more than a crude route. It is a political lever in sanctions, energy security and Ukraine-related financing discussions.

Energy Crisis Reinforces Clean Supply Strategy

The current Middle East energy crisis has intensified the EU’s focus on supply security. Jorgensen said the disruption is comparable in seriousness to the 1973 oil crisis and the 2022 Russian energy shock.

The Commission expects LNG prices to take years to stabilise. It also expects oil capacity to need months to normalise after the war ends, showing that energy disruption can outlast military events.

This strengthens the EU case for domestic and clean energy. The Commission wants to reduce import dependence through renewables, electrification, storage, hydrogen and alternative fuels.

For industry, the implication is clear. Europe’s energy security strategy will increasingly affect metals, grids, chemicals, transport fuels and clean technology supply chains.

Lower Russian energy dependence also raises demand for infrastructure. Europe will need more copper, aluminium, electrical steel, transformers, batteries, renewable equipment and grid materials to replace fossil fuel exposure with domestic power systems.

The policy challenge is execution. Europe must cut Russian dependence while managing fuel prices, refinery supply, LNG volatility, industrial competitiveness and political pressure from member states.

The Metalnomist Commentary

Europe’s refusal to return to Russian energy shows that energy security has become an industrial sovereignty issue. The next test is whether the EU can replace fossil dependency with real domestic energy infrastructure fast enough to protect industry from repeated external shocks.

Glencore-Merafe Ferro-Chrome Retrenchments Delayed as Energy Talks Continue

Merafe

Glencore-Merafe ferro-chrome retrenchments were delayed until 9 April as the joint venture continued discussions with Eskom and the South African government over energy pricing. The extension gives South Africa’s ferro-chrome sector another brief window to seek relief from high power costs.

The Glencore-Merafe ferro-chrome retrenchments had already been extended from 31 March before the latest delay. Merafe Resources, the junior partner in the joint venture with Glencore, said the new extension came at Eskom’s request.

The decision highlights the severe pressure on South African ferro-chrome smelters. Low ferro-chrome prices, high electricity costs and competition from lower-cost Chinese producers have made domestic smelting increasingly difficult to sustain.

Energy Costs Continue to Undermine Ferro-Chrome Smelting

South African ferro-chrome producers are struggling because smelting is highly power-intensive. Even after energy regulator Nersa approved a lower Eskom tariff, producers still viewed the relief as insufficient to restore competitiveness.

The tariff reduction was designed to support South Africa’s beneficiation sector, which converts chrome ore into higher-value ferro-chrome. However, the market signal remains weak because selling chrome ore has become more profitable than smelting it domestically.

This is a major industrial policy problem. South Africa holds major chrome resources, but high power costs are pushing the value chain away from local processing and toward raw material exports.

China Competition Deepens Pressure on South African Beneficiation

The Glencore-Merafe ferro-chrome retrenchments reflect a wider structural challenge in the global ferro-chrome market. Chinese producers continue to benefit from lower-cost processing conditions, while South African smelters face expensive electricity and weaker margins.

South African ferro-chrome production dropped sharply in 2025 as low prices and high energy costs forced capacity reductions. Samancor, the country’s other major ferro-chrome producer, has already proceeded with retrenchments despite the lower tariff.

The extended deadline does not remove the underlying risk. Unless energy pricing becomes more competitive, South Africa may continue losing ferro-chrome smelting capacity, weakening domestic beneficiation and reducing industrial value capture from its chrome ore base.

The Metalnomist Commentary

The Glencore-Merafe delay shows that South Africa’s ferro-chrome crisis is now an electricity competitiveness crisis. Without a durable power solution, the country risks exporting more chrome ore while losing the smelting capacity that once anchored its beneficiation strategy.

Energy Fuels Uranium Guidance Could Be Met by Midyear as White Mesa Output Accelerates

Energy Fuels

Energy Fuels uranium guidance could be reached by the end of June as the US producer completes its current ore-processing campaign at the White Mesa Mill in Utah. The company expects uranium oxide production to reach 1.6mn lb by midyear, within its full-year guidance range of 1.5mn-2.5mn lb.

Energy Fuels uranium guidance is significant because White Mesa is currently the only fully licensed and operating conventional uranium mill in the US. That gives the company a strategic position in domestic uranium supply at a time when western governments are trying to rebuild nuclear fuel and critical mineral capacity.

Energy Fuels uranium guidance also reflects stronger mine-to-mill performance from its conventional assets. The company is processing ore from the Pinyon Plain mine in Arizona and the La Sal Complex in Utah, with output expected to average more than 265,000 lb/month of finished uranium during the current campaign.

The company’s shares rose after the operational update, lifting its New York market capitalisation to about $3.6bn. But the stock remains lower year to date, showing that investors still want proof that production strength can translate into durable cash flow and diversified critical materials growth.

White Mesa Mill Strengthens US Uranium Supply Position

White Mesa’s performance is central to Energy Fuels’ role in the US uranium market. The company expects the current processing campaign to finish by the end of June, after which it plans to rebuild ore stockpiles before resuming processing in the fourth quarter.

The timing matters because uranium supply security has become more important for nuclear power, energy security and US strategic fuel planning. Conventional uranium mills are scarce in the US, so steady White Mesa operation gives Energy Fuels a domestic processing advantage that many developers do not have.

Energy Fuels also expects mining performance to improve in the second half of the year. Ore grades and contained uranium are projected to rise, while first-half contained U3O8 production in ore is expected at 750,000-850,000 lb.

The company expects White Mesa ore processing costs of $9-12/lb, near historic lows. Lower processing costs could strengthen margins if uranium prices remain supportive and mine output continues to improve.

This cost performance is especially important because the US uranium sector is still rebuilding after years of underinvestment. Higher grades, reliable ore feed and low processing costs can separate operating producers from companies that only hold development-stage resources.

Energy Fuels said its cost of sales should continue to decline in 2026. If that trend holds, the company could strengthen its position as the leading conventional US uranium producer while maintaining operational flexibility for later processing campaigns.

The midyear guidance achievement would not necessarily mean full-year production stops there. Instead, it would give the company more optionality for the second half, depending on ore availability, mine performance, market conditions and inventory strategy.

Rare Earth Upgrades Add Heavy Rare Earth Growth Path

Energy Fuels is also using White Mesa to build a rare earth separation platform alongside uranium. The mill processes natural monazite sand sourced globally and began commercial separation of rare earth elements two years ago, starting with neodymium-praseodymium.

The company has since added capability for heavy rare earths, including samarium, europium, gadolinium, terbium and dysprosium. These materials are important for permanent magnets, defence systems, electronics, high-performance motors and clean-energy technologies.

Energy Fuels plans to begin further modifications to its existing Phase 1 rare earth circuits in July. The upgrades are designed to allow commercial production of heavy rare earths in addition to existing commercial quantities of NdPr.

This is strategically important because heavy rare earth supply remains highly concentrated. Dysprosium and terbium are especially critical for high-performance magnets used in electric vehicles, wind turbines, robotics and defence applications.

The planned modifications will also add a circuit to process uranium-bearing mixed rare earth carbonates from global mines, including material from ionic adsorption clay sources. Because these mixed rare earth carbonates can feed directly into solvent extraction separation, the new circuit could allow White Mesa to process uranium and separated rare earths simultaneously.

That dual-processing model is important. It could turn White Mesa from a uranium mill with rare earth exposure into a more integrated critical minerals facility. The ability to process multiple feedstocks could improve utilisation, diversify revenue and strengthen domestic supply-chain resilience.

Energy Fuels expects the modifications to become operational in late 2027 to early 2028. The company is also planning a Phase 2 expansion that could raise total rare earth capacity at White Mesa to nearly 6,300 t/yr.

Permitting for both the circuit modifications and Phase 2 expansion is proceeding on schedule, according to the company. If delivered, White Mesa could become one of the most important US platforms linking uranium recovery, monazite processing, NdPr separation and heavy rare earth production.

The broader implication is that Energy Fuels is positioning itself across two strategic supply chains at once. Uranium supports nuclear energy security, while rare earth separation supports magnets, defence, electrification and advanced manufacturing.

The Metalnomist Commentary

Energy Fuels’ update shows why existing processing infrastructure is becoming strategically valuable in the US. White Mesa is not only a uranium asset; it could become a rare domestic bridge between nuclear fuel security and heavy rare earth separation.

Rio Tinto Seeks Support for Australian Aluminium Smelter

Australian Al smelter

Power Costs Challenge Aluminium Operations

Rio Tinto is in talks with both the Australian federal government and the New South Wales (NSW) state government to secure support for its 600,000 t/yr Tomago aluminium smelter. The UK-Australian producer is renegotiating power purchase agreements to reduce costs, as energy expenses continue to rise across the state. Tomago accounts for about 12% of NSW’s total power use and plays a key role in grid stabilisation by adjusting production in line with electricity demand.

Officials confirmed discussions are underway, with NSW premier Chris Minns describing them as commercial negotiations. Industry and innovation minister Tim Ayers added that the government recognises Tomago’s strategic role but did not outline specific intervention measures. Meanwhile, energy minister Penny Sharpe acknowledged that soaring energy costs are straining many of the state’s energy-intensive industries.

Federal Incentives and Industry Outlook

Australia’s federal government has committed A$2bn ($1.3bn) under a low-emission production tax credit scheme, which will take effect in the 2028-29 fiscal year. The initiative aims to sustain aluminium production while encouraging cleaner processes. Rio Tinto has welcomed the scheme, calling it an important step toward maintaining Australia’s competitiveness in global aluminium markets.

Until the scheme is active, however, Rio Tinto must navigate high energy costs that threaten the viability of large-scale smelting operations. The company’s negotiations with power suppliers and government stakeholders will be critical in determining whether the Tomago smelter remains sustainable over the coming years.

The Metalnomist Commentary

Rio Tinto’s situation highlights the vulnerability of aluminium producers to volatile energy markets. While Australia’s tax credit scheme offers long-term relief, the immediate challenge is bridging the gap until 2028. The outcome at Tomago could set a precedent for how governments and power companies support energy-intensive industries under decarbonisation pressures.

Germany Aluminium Industry Decline Deepens as Energy Costs and CBAM Pressure Competitiveness

Germany Aluminium

Germany aluminium industry decline is becoming harder to reverse as production, recycling, and capacity utilization remain well below 2021 levels. Aluminium Deutschland said the sector showed no growth since 2021. Fourth-quarter output stayed only 76-88pc of 2021 levels. As a result, Germany aluminium industry decline now looks more structural than cyclical.

This matters because the sector is losing strength across several product categories at once. Rolled products rose slightly in 2025, but still remained 12pc below 2021 levels. Extruded products fell 1pc last year and stayed 24pc below 2021. Therefore, German aluminium competitiveness is weakening across both primary and semi-finished segments.

The association blames policy and cost pressure for the downturn. High energy prices, weak relief measures, and regulations such as CBAM are central concerns. The wider economy also remains soft. Consequently, Germany aluminium industry decline is being driven by both weak demand and a more difficult operating environment.

German Aluminium Competitiveness Is Under Pressure From Energy and Policy

German aluminium competitiveness is under direct pressure from high power costs and ineffective industrial support. Aluminium Deutschland said current policy frameworks no longer support recovery. It also warned that traditional policy thinking is failing domestic industry. As a result, the sector sees competitiveness risk as a core threat, not a temporary obstacle.

CBAM impact on aluminium is also becoming more controversial inside the industry. The association argues that CBAM may add burdens instead of meaningful protection. That concern is especially serious in a sector already facing cost disadvantages. Therefore, German aluminium competitiveness may weaken further if policy tools fail to deliver real relief.

This issue matters because aluminium is deeply tied to industrial employment and manufacturing resilience. If producers continue losing ground, Germany may become more dependent on imported metal and products. Meanwhile, the country could lose more industrial capacity in areas that support broader supply chains.

Aluminium Recycling in Germany Also Shows Industrial Weakness

Aluminium recycling in Germany is also moving in the wrong direction. German companies produced 2.7mn t of recycled aluminium in 2025. That was down 1pc on the year and 16pc below 2021 levels. As a result, the decline is not limited to primary production or semi-finished products.

Weak downstream demand is a major reason. Automotive, construction, and plant engineering all remained soft. Tight scrap availability and high scrap prices also hurt recycling economics. Therefore, aluminium recycling in Germany now reflects both industrial slowdown and raw material stress.

This matters because recycling should be one of Europe’s stronger advantages in aluminium. When recycling weakens alongside broader production, it signals a much deeper industrial problem. Consequently, Germany aluminium industry decline now extends across the full value chain rather than one isolated segment.

The Metalnomist Commentary

Germany’s aluminium sector is no longer describing a normal downturn. It is describing a competitiveness crisis. If energy costs, policy burdens, and weak demand continue together, Germany risks losing more than output. It risks losing strategic industrial capability.

Nyrstar Australian Smelters Face Uncertain Future Without New Funding

Nyrstar

Nyrstar Australian smelters face an uncertain future as the company reviews possible closures or output curtailments at its Port Pirie lead smelter and Hobart zinc smelter. The review comes after interim government rescue funding expired without a second phase being agreed.

Nyrstar Australian smelters received A$135mn in interim support in August last year. The funding was designed to keep the 160,000 t/yr Port Pirie lead smelter in South Australia and the 280,000 t/yr Hobart zinc smelter in Tasmania operating while longer-term solutions were assessed.

Nyrstar Australian smelters are strategically important because they preserve domestic processing capability for base metals and potential critical minerals. But the facilities remain economically challenged by weak commodity pricing, high energy costs and the need for capital investment.

The company, owned by Trafigura, said it is now exploring all options for the two assets. No final decision has been made on closures or production cuts.

Port Pirie and Hobart Test Australia’s Industrial Policy

The Port Pirie and Hobart smelters sit at the centre of Australia’s debate over whether strategic processing capacity should be preserved through public support. Both assets are partway through two-year feasibility studies to diversify output into critical minerals such as bismuth and tellurium.

This diversification is important because traditional lead and zinc smelting margins have been under pressure. Adding critical minerals could improve the strategic value of the facilities and create new revenue streams.

Port Pirie has already started moving in that direction. The first shipment of antimony from a pilot plant was exported in February under the first-phase funding agreement.

Nyrstar said the Port Pirie pilot plant could produce 2,000 t/yr of antimony by the end of this year. That would be meaningful because antimony is increasingly viewed as a strategic metal for defence, flame retardants, batteries and industrial alloys.

Hobart has already faced production cuts during weaker zinc market conditions. That history shows how exposed the site remains to zinc prices, energy costs and operating margins.

Without a second funding phase, Nyrstar may cut capital expenditure and operating costs as part of the review. That could delay diversification plans and weaken Australia’s ability to preserve downstream metal processing capacity.

Critical Minerals Could Decide Smelter Value

The future of the two smelters may depend on whether they can become more than conventional lead and zinc assets. Processing critical minerals could give them a stronger role in Australia’s industrial strategy.

Australia’s Future Made in Australia policy aims to retain industrial capability and use renewable energy to support low-carbon exports, including metals. Smelters such as Port Pirie and Hobart fit that policy direction if they can become competitive and strategically relevant.

The challenge is cost. Existing smelters need reliable power, capital upgrades and market support to compete against lower-cost global processors.

Recent government support for aluminium and copper processors shows that Canberra is willing to intervene when strategic industrial assets face closure. But each case still needs a credible long-term pathway.

For Nyrstar, that pathway may involve antimony, bismuth, tellurium and other by-product metals. These materials can improve the value of complex smelting operations if they are recovered efficiently and sold into secure supply chains.

For Australia, the decision is broader than one company. Losing smelting capacity would weaken domestic processing depth at a time when governments are trying to reduce dependence on concentrated foreign refining systems.

The Metalnomist Commentary

Nyrstar’s Australian smelter review shows that critical minerals policy must extend beyond mining into processing assets that already exist. The key question is whether Australia can turn legacy smelters into strategic by-product platforms before high energy costs force permanent closures.

Hydro UK Extrusion Closure at Birtley Plant Affects 100 Jobs

Hydro

Hydro UK extrusion closure confirmed as Norwegian aluminum producer Hydro announced the shutdown of its Birtley facility due to challenging market conditions. The Hydro UK extrusion closure will eliminate 12,000 tonnes annual production capacity from two extrusion presses while making 100 employees redundant, as the company consolidates operations at remaining UK facilities in Tibshelf and Cheltenham following extensive employee consultations.

Production Consolidation Strategy Addresses Market Pressures

Hydro UK extrusion operations face restructuring as the company transfers Birtley's customers and production activities to other domestic facilities. The Tibshelf and Cheltenham plants will absorb the redistributed workload, maintaining customer service continuity while optimizing operational efficiency. This consolidation approach demonstrates Hydro's commitment to preserving UK market presence despite facility closures.

Meanwhile, the Birtley closure reflects broader aluminum extrusion industry pressures including elevated energy costs and competitive market dynamics. The facility's 12,000 tonne annual capacity represents a relatively modest scale that may struggle to maintain competitiveness against larger, more efficient operations. Market consolidation trends favor facilities with enhanced economies of scale and operational flexibility.

European Restructuring Extends Beyond UK Operations

However, the Birtley shutdown forms part of broader European restructuring initiatives affecting Hydro's continental operations. The company announced closure of an anodizing facility in Luce, France, alongside 30,000 tonnes of recycling capacity reduction in Puget, France earlier this month. These concurrent shutdowns indicate systematic capacity rationalization across multiple European markets.

Therefore, Hydro's restructuring strategy targets operational optimization while maintaining core market positions in key European regions. The company prioritizes facilities with superior cost structures and strategic market access over smaller, less competitive operations. This approach aligns with industry trends toward consolidation and efficiency improvements amid persistent cost pressures.

Industry Consolidation Reflects Challenging Operating Environment

Furthermore, aluminum extrusion sector consolidation accelerates as producers face sustained pressure from energy costs, raw material pricing, and competitive dynamics. UK manufacturing operations encounter particular challenges from elevated electricity prices and post-Brexit trade complexities. These factors contribute to ongoing industrial capacity rationalization across energy-intensive sectors.

As a result, Hydro's facility consolidation demonstrates how established aluminum producers adapt to challenging market conditions through strategic capacity management. The company's ability to redistribute production while maintaining customer relationships illustrates operational flexibility essential for navigating volatile market environments. Similar consolidation activities may continue across European aluminum processing sectors facing comparable pressures.

The Metalnomist Commentary

Hydro's UK extrusion plant closure exemplifies the ongoing rationalization within Europe's aluminum processing sector, where elevated energy costs and competitive pressures force even established producers to consolidate operations for improved efficiency. The company's ability to redistribute production to remaining facilities while maintaining customer service demonstrates the strategic importance of operational flexibility in managing volatile market conditions that continue to challenge energy-intensive manufacturing across the region.

Chile Lithium BESS Project Launches in Atacama Desert

Atlas Renewable Energy

Atlas Renewable Energy has officially launched the largest Chile lithium BESS project in Latin America. The new Desert BESS facility, located in Chile's Atacama Desert, stores up to 800 MWh of solar energy using 320 lithium-based battery units. It can deliver 200 MW of power, enough to serve 122,000 households year-round.

Powering Buses and Cutting Nighttime Energy Costs

The BESS will operate under a 15-year power deal with Chilean firm Copec Emoac. Copec plans to use the system to power 2,500 electric buses across three states. As a result, each bus can travel up to 69,000 kilometers per year, significantly reducing transportation emissions and energy costs during peak nighttime hours.

Accelerating Chile’s 2030 Energy Storage Goals

The Desert BESS adds over 200 MW to Chile’s grid, pushing national energy storage above 1 GW. Therefore, the country is now on track to exceed its 2030 target of 2 GW of storage capacity by 2026 — four years ahead of schedule. The Chile lithium BESS project showcases how private-sector partnerships can accelerate public energy goals.

The Metalnomist Commentary

The Chile lithium BESS project is a milestone in Latin America's clean energy transition. Its scale, speed, and smart integration with electric mobility offer a roadmap for emerging markets aiming to lead in grid modernization.

Ecuador Increases Power Tariffs for Copper Mines Amid Energy Crisis

Ecuacorriente S.A

In a move to address Ecuador's ongoing energy crisis, the country’s electricity regulatory agency, Arconel, has raised power tariffs for large-scale industries, including the copper mining sector. This change, which took effect on October 30, has significant implications for major mines in the country, notably Mirador, operated by China's Ecsa-Ecuacorriente, and Fruta del Norte, operated by Canadian company Lundin. The revised tariffs will impact electricity consumption during peak hours, further exacerbating the financial pressure on mining operations already grappling with soaring costs.

Key Changes to Power Tariffs

The new electricity tariffs target industries that consume the most power, with particular emphasis on mining operations. The most notable increases are:

• Peak Hours (6-10 pm): Increased from 8.10¢/kWh to 9.86¢/kWh.
• Daytime (8 am-6 pm): Raised from 6.8¢/kWh to 8.5¢/kWh.
• Off-Peak (10 pm-8 am): Increased from 5.4¢/kWh to 7.5¢/kWh.

These price hikes will affect two major mines in Ecuador: the Mirador copper mine, which is one of the country’s largest, and the Fruta del Norte gold mine. The tariff increases are a direct response to the national energy shortage caused by a harsh drought, which has significantly reduced the output from Ecuador’s primary hydroelectric plants.

Impact of Ecuador's Energy Crisis on Mining

Ecuador is currently facing a severe energy crisis, exacerbated by a lack of rainfall, which has hindered the operation of hydroelectric plants. As a result, the country has had to rely heavily on thermoelectric power generation, leading to a 77% increase in thermoelectric fuel consumption in the third quarter of 2024 compared to the same period in 2023, according to Petroecuador, the state-owned oil and energy company.

Despite the increase in energy costs, the Ecuadorian mining chamber, which represents companies like Ecsa-Ecuacorriente and Lundin, has acknowledged that the tariff hike is necessary due to the energy crisis. The increased electricity tariffs are expected to affect the operational costs of these mines, making them less competitive in the global market.

Ecuador's Mining Exports and the Role of Copper

Ecuador's mining sector plays a crucial role in the country’s economy. In the first half of 2024, Ecuador exported $688.8 million in copper concentrate, accounting for 42% of the country's total income from metal exports, which amounted to $1.6 billion. Copper export revenues saw a 12% increase from the previous year, highlighting the growing importance of copper as a key driver of the national economy.

The rise in power tariffs, however, may put the profitability of copper mining operations under strain, particularly for Mirador, one of Ecuador’s largest copper producers. While the mining chamber has voiced support for the tariff increase, it remains to be seen how these changes will affect long-term investment and growth in Ecuador's mining sector.

Elkem Restructuring Targets Cost Control as Silicon Market Weakens

Elkem

Elkem restructuring is becoming a major response to weaker market conditions after the Norwegian metals group completed the sale of its silicones division. The company will now operate through three divisions: Elkem Silicon, Elkem Foundry Alloys, and Elkem Carbon. The move marks a sharper focus on core materials businesses as silicon and ferro-silicon markets remain under pressure.

Elkem restructuring also comes with a significant cost-cutting programme. The company plans to reduce its total workforce by 10% and improve working capital and capital expenditure by Nkr1.3 billion, or about $135 million. Salary and operating cost reductions are expected to generate annual savings of Nkr600 million, while investment will be capped at Nkr1 billion this year.

Elkem restructuring reflects the pressure now facing energy-intensive metals producers in Europe. High inventories, weak demand visibility, and elevated energy costs have already forced the company to temporarily reduce silicon and ferro-silicon production at its Salten and Rana plants in Norway.

Silicon and Ferro-Silicon Markets Pressure Elkem’s Core Operations

Elkem’s latest restructuring follows a sharp earnings decline in its continuing operations. Excluding the divested silicones division, the company recorded fourth-quarter 2025 earnings of Nkr485 million, down by almost 40% from a year earlier. That result shows how quickly weaker demand can affect upstream and intermediate materials businesses.

The company’s silicon and ferro-silicon operations are especially exposed to industrial cycles. These products serve aluminium alloys, foundries, chemicals, steelmaking, and other manufacturing value chains. When customer demand slows or inventories rise, producers face direct pressure on operating rates and margins.

Elkem’s temporary production reductions in Norway underline this challenge. Silicon and ferro-silicon production depends heavily on reliable and competitive power costs. In a weak market, high energy costs can quickly turn capacity utilization into a margin risk rather than a volume advantage.

Cost Cuts Aim to Preserve Competitiveness Until Demand Recovers

Elkem’s cost-cutting programme is designed to preserve financial flexibility until market conditions improve. Chief executive Helge Aasen said the measures should position the company to deliver long-term value for customers, employees, and stakeholders once the market recovers.

However, the outlook remains uncertain. Elkem said the conflict in the Middle East has increased macroeconomic uncertainty and affected value chains for many of its customers. The company now expects the first half of 2026 to be weaker than previously expected, with limited visibility.

The restructuring also signals a broader trend across European metals and materials companies. Producers are narrowing portfolios, reducing fixed costs, and protecting cash as demand from downstream industries becomes harder to forecast. For Elkem, the sale of silicones and the renewed focus on silicon, foundry alloys, and carbon products create a leaner structure, but the company still depends on a recovery in industrial demand.

The Metalnomist Commentary

Elkem’s restructuring shows how energy-intensive metals producers are moving from expansion logic to survival discipline. The key question is whether cost cuts can protect competitiveness long enough for silicon and ferro-silicon demand to recover.

EU Ferro-Alloy Safeguards Face Legal Challenge From Grondmet

Ferro-alloy

EU Ferro-alloy safeguards are facing a legal challenge after German alloy trader Grondmet filed an action for annulment with the EU’s General Court. The case could become an important test of how Europe balances import protection, industrial competitiveness, and raw material access for alloy consumers.

Grondmet is disputing the legal basis for safeguards implemented by the EU on 19 November 2025. The company argues that the measures do not meet the European Commission’s own thresholds because a recent, sudden, sharp, and significant rise in imports cannot be substantiated for ferro-silicon or ferro-manganese.

The challenge matters because ferro-alloys are essential inputs for steelmaking, foundries, stainless steel, and specialty alloy production. If safeguards raise costs or restrict access without clear market justification, downstream manufacturers could face additional pressure at a time when European industry is already struggling with energy costs and regulatory burdens.

Grondmet Questions Import Evidence and Product Grouping

Grondmet’s case focuses on whether the EU properly assessed the ferro-alloy market before applying safeguards. The company says the Commission failed to conduct a product-specific assessment and wrongly treated different grades and qualities as homogeneous product groups.

This point is commercially important. Ferro-silicon, ferro-manganese, and other ferro-alloys are not interchangeable in many industrial applications. Grade, chemistry, impurity limits, origin, and delivery reliability can determine whether a material is suitable for a specific steel or alloy recipe.

Grondmet also argues that out-of-quota price thresholds are disconnected from actual market conditions. The company specifically says the ferro-silicon threshold is misaligned with prevailing prices and lacks clear economic or methodological justification. If accepted by the court, this argument could weaken the basis for applying broad safeguards across differentiated alloy products.

Energy Costs Remain Europe’s Deeper Ferro-Alloy Problem

EU ferro-alloy safeguards also raise a wider competitiveness question. Grondmet argues that the primary structural challenge for European ferro-alloy producers is energy cost, not import pressure. This is a critical distinction because ferro-alloy production is highly power-intensive.

If high electricity prices are the main reason European producers are losing competitiveness, import safeguards may not solve the underlying problem. They may instead shift costs to steelmakers, foundries, traders, and industrial buyers that depend on competitively priced alloying materials.

The legal process could also attract wider industry participation. An action for annulment allows third parties to intervene either in support of or against the challenge. Grondmet has invited European traders, producers, and consumers to join the case, suggesting that the dispute may become a broader debate over EU industrial policy and market access.

The Metalnomist Commentary

The Grondmet case highlights a growing tension in European metals policy. Protection tools may support producers in the short term, but they can weaken downstream competitiveness if they do not address the real cost problem: energy.

Global Energy Investment to Reach $3.3 Trillion in 2025, Led by Clean Energy

IEA(International_Energy_Agency)

Clean Energy Spending Doubles Fossil Fuel Investment

Global energy investment is forecast to hit a record $3.3 trillion in 2025, with two-thirds allocated to clean energy technologies, according to the International Energy Agency (IEA). This marks a 2% real-term increase from 2024, despite ongoing geopolitical tensions and economic uncertainty.

The IEA expects $2.2 trillion to be invested in renewables, nuclear power, grids, storage, low-emissions fuels, energy efficiency, and electrification. In comparison, fossil fuel investment is projected at $1.1 trillion. The agency attributes the surge in clean energy spending to emission reduction goals, industrial policy incentives, energy security concerns, and the competitiveness of electricity-based solutions.

Energy security remains a primary driver of investment growth. While some investors are cautious about new project approvals, the IEA notes minimal disruption to existing developments.

Electricity Sector Investment Surges While Fossil Fuels Decline

The “age of electricity” is shaping global capital flows, with the power sector expected to attract $1.5 trillion in 2025. Solar power will lead the charge, drawing $450 billion alone. However, grid investment, while reaching a record $400 billion, is struggling to keep pace with soaring power demand.

Conversely, fossil fuel supply investment is expected to fall 2% — the first drop since 2020. Upstream oil spending will decline 6% to about $420 billion, while gas investment will also retreat amid price drops, higher operating costs, tariffs, and oversupply concerns. Coal investment will continue to grow, though at a slower 4% annual rate, driven largely by China and India.

Regional Shifts and Policy Impacts

China remains the largest global energy investor, with its share of clean energy investment rising from 25% a decade ago to nearly one-third today. In the US, investment in renewables and low-emission fuels is set to plateau as supportive policies wane. Meanwhile, oil and gas spending is increasingly concentrated in resource-rich Middle Eastern nations.

Spending on low-emissions fuels is projected to hit a record in 2025 but will stay below $30 billion, with projects vulnerable to policy uncertainty. The IEA warns that regional disparities in policy and market dynamics could influence the pace of the clean energy transition.

The Metalnomist Commentary

The IEA’s projection underscores the accelerating momentum of the clean energy transition, even amid economic headwinds. While record spending on renewables and electricity infrastructure marks progress, bottlenecks in grid expansion and regional policy uncertainties could challenge the pace of change. Investors and policymakers will need to address these gaps to secure long-term energy security and decarbonization goals.

Glencore-Merafe Lion Smelter Restart Highlights South Africa’s Ferro-Chrome Power Challenge

Glencore-Merafe

Glencore-Merafe Lion Smelter restart has brought some relief to South Africa’s ferro-chrome sector. The joint venture restarted production at Lion Smelter in Limpopo on 16 February. It has currently brought back 50pc of the smelter’s operating capacity. As a result, Glencore-Merafe Lion Smelter restart marks an important operational recovery.

This restart matters because Lion is now the venture’s only active smelter. Boshoek and Wonderkop have remained offline since last year’s suspensions. That leaves Lion carrying the near-term production burden. Therefore, Glencore-Merafe Lion Smelter restart is strategically important for the venture’s output profile.

The company expects Lion to reach full operating capacity by 31 March 2026. That target gives the market a clearer recovery timeline. However, the restart does not solve the venture’s deeper structural problem. South Africa ferro-chrome power costs still remain too high for long-term competitiveness.

South Africa Ferro-Chrome Power Costs Still Threaten Sustainability

South Africa ferro-chrome power costs made this restart possible, but only on a temporary basis. The National Energy Regulator approved a 12-month interim tariff of 87.74¢/kwh. That gave Glencore-Merafe enough short-term relief to restart Lion. Consequently, the company could bring some capacity back online.

However, Merafe made its position clear. The venture says it needs a tariff of 62¢/kwh to operate sustainably. That means the current relief does not provide a durable economic solution. Therefore, South Africa ferro-chrome power costs remain the main constraint on the business.

This issue also affects the two idle smelters. Boshoek and Wonderkop both need the same lower tariff to restart. Without that pricing relief, the venture cannot justify bringing them back. Meanwhile, the company faces a deadline to begin consultation on possible retrenchments.

Ferro-Chrome Competitiveness Remains Under Heavy Pressure

Ferro-chrome competitiveness is now the bigger issue behind this restart. Glencore-Merafe’s ferro-chrome production fell 63pc in 2025. High energy costs and weak market conditions drove that decline. As a result, the venture has lost ground in a very competitive global market.

Inner Mongolia producers remain a major challenge. They benefit from lower production costs and stronger power economics. South African smelters cannot compete effectively under the current cost structure. Therefore, Glencore-Merafe Lion Smelter restart is positive, but still fragile.

The company now wants a long-term tariff solution by 28 February. That deadline matters because employment, capacity planning, and future production all depend on it. Without structural energy reform, South Africa’s ferro-chrome sector may keep losing share. Consequently, ferro-chrome competitiveness now depends as much on power policy as on metal markets.

The Metalnomist Commentary

Lion’s restart is encouraging, but it does not change the core reality. South Africa’s ferro-chrome industry still faces a power cost problem that temporary relief cannot fix. If no long-term tariff solution emerges soon, this restart may look more like a pause in the downturn than the start of a real recovery.

US Solar Duties Target Asian Cell Imports as Washington Defends Domestic Manufacturing

US solar

US solar duties on cells and modules from India, Indonesia and Laos will raise the cost of imported photovoltaic products after the Commerce Department issued preliminary antidumping findings. The decision allows customs authorities to begin collecting cash deposits from importers.

US solar duties are part of a broader trade case brought by domestic manufacturers that accuse foreign producers of selling solar products at unfairly low prices. The case covers crystalline silicon photovoltaic cells and modules imported into the US market.

US solar duties now combine antidumping margins with earlier countervailing duties. General preliminary duty rates stand at roughly 234% for India, 140% for Indonesia and 103% for Laos.

The decision comes at a critical point for the US solar supply chain. Washington is trying to expand domestic clean energy manufacturing while reducing dependence on lower-cost Asian imports.

Duties Raise Costs for India, Indonesia and Laos Solar Supply

The preliminary antidumping margins differ by country and company. Indian producers face the steepest margin, at about 123%.

Companies in Indonesia face a lower dumping margin of about 35%, while firms in Laos face around 22%. These rates come on top of countervailing duties announced earlier this year.

The combined duty levels could significantly affect solar module sourcing decisions. Importers may need to reassess contracts, landed costs and supply availability if final rates remain high.

The investigation was triggered by a petition from the Alliance for American Solar Manufacturing and Trade. The group includes US manufacturers such as First Solar and Mission Solar Energy, along with Qcells, a subsidiary of South Korea’s Hanwha.

The coalition argued that companies in the three countries benefited from subsidies and sold solar products into the US at unfairly low prices. It also alleged that Chinese-linked manufacturers operating in Southeast Asia were undercutting American-made products.
The decision strengthens the trade protection around US solar manufacturing. But it may also raise near-term procurement costs for developers that depend on imported cells and modules.

Domestic Manufacturing Push Collides With Deployment Costs

The case highlights the tension inside US clean energy policy. The government wants more domestic solar manufacturing, but the solar deployment market still relies heavily on imported equipment.

Antidumping tariffs are intended to counter imports sold below normal value. Countervailing duties target products that benefit from government subsidies.
Together, these duties can protect domestic producers from price competition that regulators view as unfair. They can also reshape trade flows by pushing buyers toward alternative origins or US-made products.

For manufacturers, the ruling supports investment in domestic capacity. Higher duties can improve the competitiveness of US-made solar products and encourage new factory spending.

For project developers, the impact is more complicated. Higher module costs can pressure project economics, especially where power purchase agreements, tax credits and construction budgets were based on cheaper imported supply.

Commerce is expected to issue final antidumping determinations in early September. Until then, the market will face uncertainty around final rates, supplier exposure and contract pricing.

The broader industrial message is clear. Solar policy is no longer only about renewable energy deployment. It is also about manufacturing location, trade enforcement and supply-chain control.

The Metalnomist Commentary

The new US solar duties show that clean energy deployment and industrial protection are increasingly inseparable. The key question is whether Washington can build domestic solar capacity fast enough to offset higher import costs without slowing project growth.

Largo and Stryten Launch Storion Energy to Boost U.S. Vanadium Redox Flow Battery Market

Largo

Largo and Stryten Energy have officially formed Storion Energy, a joint venture designed to produce vanadium electrolyte for vanadium redox flow batteries (VRFBs). The collaboration aims to strengthen the U.S. long-duration energy storage (LDES) sector by reducing reliance on imported vanadium-based energy solutions.

Storion will combine Stryten’s proprietary VRFB technology with vanadium pentoxide (V₂O₅) from Largo’s Maracás Menchen Mine in Brazil, providing a reliable domestic supply of vanadium electrolyte for U.S. battery manufacturers. The venture seeks to expand VRFB adoption as an alternative to lithium-ion batteries, particularly in applications requiring extended-duration energy storage.

Reducing Costs to Compete with Lithium-Ion Batteries

One of the major challenges for VRFB deployment in Western markets is the high cost of vanadium electrolyte, which accounts for 40-50% of a VRFB system’s total cost, depending on market vanadium prices.

Storion plans to supply vanadium electrolyte at just $0.02/kWh, well below the U.S. Department of Energy’s (DOE) target of $0.05/kWh for flow batteries that provide at least 10 hours of energy storage. This cost reduction is made possible by:

• Stryten’s advanced technology for efficient electrolyte production.

• Largo’s vanadium leasing model through Largo Physical Vanadium, which helps mitigate upfront material costs.

Strategic U.S. Manufacturing Presence

Storion Energy will operate out of Alpharetta, Georgia—where Stryten’s headquarters is located—and Wilmington, Massachusetts, home to Largo Clean Energy. This dual-location setup will enable efficient production and distribution of vanadium electrolytes, enhancing domestic energy security and accelerating VRFB commercialization.

China Tariff Relief Bypasses US Energy Trade

US energy trade, China

China tariff relief bypasses US energy trade in the latest preliminary deal. The headline reduction excludes crude and LNG. Therefore, China tariff relief bypasses US energy trade and preserves steep energy tariffs. As a result, China tariff relief bypasses US energy trade while easing pressure on farm goods.

Energy tariffs stay despite broader deal signals

The agreement suspends many retaliatory tariffs announced since March. However, it does not touch China’s February energy duties. The cumulative tariff on US LNG remains about 50pc. Meanwhile, the effective rate on US crude stays near 22.5pc. Therefore, US oil and gas flows to China remain uneconomic. The US will cut its broad headline tariff by 10 points. Even so, energy-specific duties still block trade recovery. Beijing has not confirmed exact terms in its statements. Market participants should assume energy tariffs persist for now.

Shipping fees ease, but fuel flows remain constrained

The US will suspend new port fees on Chinese vessels. In response, China will suspend its countermeasures on US vessels. Consequently, logistics friction should decline for many cargos. Yet energy economics depend on tariff arithmetic, not fees. LNG offtake needs long-term price certainty and access. Crude flows need competitive landed costs into China. Until energy tariffs fall, trade lanes will stay muted. Therefore, suppliers must pivot toward alternate Asian buyers. US producers may target Korea, Japan, and Southeast Asia.

The Metalnomist Commentary

The deal separates agriculture from hydrocarbons, preserving leverage over energy. Watch for a second-stage negotiation that explicitly addresses crude and LNG. If Beijing maintains February duties, Atlantic LNG spreads and US crude differentials will keep steering barrels elsewhere.