Alaska LNG Gains Momentum Through Two-Phase Development

Alaska LNG

Glenfarne’s Phased Approach Reduces Risks for Alaska LNG

Alaska LNG’s two-phase financing strategy is designed to reduce investment risks and improve project viability. Glenfarne Energy Transition, the lead developer with a 75% stake, plans to separate the $44bn project into two independent stages. The first stage includes a North Slope gas treatment plant and a 765-mile pipeline delivering gas to Anchorage, where shortages are expected by 2027.

By structuring the project with separate final investment decisions (FIDs), Glenfarne avoids the pitfalls of the 2016 attempt by ExxonMobil, BP, and ConocoPhillips, which collapsed due to high upfront risks. Glenfarne’s phased approach ensures that each stage is financially viable and attractive to both creditors and offtakers.

Domestic Supply Security and LNG Export Potential

The initial phase secures gas supply for Alaska’s largest population center while laying the foundation for LNG exports. The 3.5bn ft³/d pipeline would transport sufficient gas to meet domestic needs and supply the future liquefaction facility in Nikiski.

If developed, the second phase would add compression capacity, a 42-mile connector pipeline, and a 20mn t/yr LNG terminal. Glenfarne has already received regulatory approval from the US Federal Energy Regulatory Commission and export authorizations from the Department of Energy, positioning the project for international market entry.

Strong International Interest in Alaska LNG Volumes

Asian buyers are showing strong demand for Alaska LNG, signaling export market viability. In June, Glenfarne announced receiving more than $115bn worth of bids from over 50 companies. Taiwan’s CPC signed a preliminary deal in March, while the Philippines and Thailand have expressed interest in future volumes.

Geopolitical dynamics also play a role, as former US President Donald Trump has urged Asian allies to invest in Alaska LNG in exchange for trade concessions. These developments highlight the project’s potential to strengthen US energy ties in the Asia-Pacific region.

The Metalnomist Commentary

Alaska LNG’s revival through Glenfarne’s phased financing marks a strategic shift in US LNG project development. By ensuring domestic gas security while targeting Asian demand, the project balances local needs with global energy ambitions. However, execution risks remain high, especially in financing and geopolitical stability, which will determine whether Alaska LNG becomes a cornerstone of US energy exports.

Canada fast-tracks LNG and mining projects to reshape its resource strategy

Canada fast-tracks

Canada fast-tracks LNG and mining projects as Ottawa launches a new tier of “National Interest Projects.” The first list includes LNG, nuclear, mining and port infrastructure that will receive accelerated permitting and financing support. As a result, Canada fast-tracks LNG and mining projects to revive growth, enhance energy security and pivot trade away from US dependence.

Canada fast-tracks LNG and mining projects with LNG Canada Phase 2 at the centre of the plan. The proposed second phase in British Columbia would double existing 14mn t/yr capacity if sanctioned. Therefore, Phase 2 would create one of the world’s largest LNG export facilities and strengthen Canada’s Pacific energy footprint. Prime minister Mark Carney frames these assets as “nation building” projects that can transform Canada into an energy superpower.

LNG, nuclear and port projects gain streamlined federal backing

The fast-track list extends beyond gas export capacity into nuclear and logistics infrastructure. The Darlington New Nuclear Project in Ontario, centred on small modular reactors, aims to provide firm low carbon power. Meanwhile, an expansion of the Port of Montreal container terminal will support higher trade volumes with “reliable” partners beyond the US. These projects anchor a broader strategy that links energy, trade and industrial policy.

Canada will use a new Major Projects Office to shepherd these investments through remaining approvals. The office will coordinate regulatory and permitting processes and help secure necessary financing. Therefore, projects on the “National Interest Projects” list can bypass some red tape that previously discouraged investors. Streamlined reviews must conclude within two years, a major change in a country known for slow project timelines.

Canada fast-tracks LNG and mining projects to support critical minerals and oil sands

Canada fast-tracks LNG and mining projects partly to strengthen critical minerals supply. Two western mining projects made the first list: an expansion at the Red Chris copper gold mine in British Columbia and the McIlvenna Bay Foran Copper Mine in Saskatchewan. These assets support copper demand from electrification, grids and data centres, while reinforcing Canada’s role in allied critical mineral supply chains.

Carbon capture plans also feature prominently in the next wave of projects. Carney highlighted the Pathways Alliance 22mn t/yr carbon capture and storage project for referral to the Major Projects Office. Pathways could link to a new pipeline serving multiple markets and underpin “enormous” emissions reductions. However, it would also facilitate new oil sands growth, tying climate strategy directly to hydrocarbon expansion.

Political dynamics around these decisions remain complex yet pragmatic. Alberta premier Danielle Smith described her recent meeting with Carney as “exceptionally productive” and urged Albertans to be patient. She claims “Albertans are finally being heard,” signalling provincial support if projects deliver tangible economic benefits. Meanwhile, Carney plans a second tranche of major projects by mid November, which could include additional energy and infrastructure schemes.

The Metalnomist Commentary

Canada’s move to fast-track LNG and mining projects shows how permitting reform, not only subsidies, now drives resource strategy. If the Major Projects Office delivers credible two year timelines, global capital may revisit Canadian LNG, nuclear and mining assets. Market participants should watch which projects enter the second tranche, since that list will reveal how aggressively Ottawa intends to balance hydrocarbons, critical minerals and climate goals.

Q-Flex LNG Loading Outside Qatar Signals LNG Fleet Disruption After Hormuz Shock

Q-Flex LNG

Q-Flex LNG loading outside Qatar could mark a major shift in LNG shipping patterns after the US-Iran war stranded supply from Ras Laffan and disrupted normal QatarEnergy fleet operations. The 216,200m³ Mesaimeer is scheduled to load at Oman’s Qalhat export terminal, potentially making it the first Q-class vessel to load outside Qatar since the conflict began.

The move matters because Q-Flex LNG loading has been almost entirely tied to QatarEnergy’s Ras Laffan terminal since 2008. These vessels were designed around Qatar’s large-scale LNG export model, with cargo sizes, port access and operating economics suited to dedicated long-haul flows.

Q-Flex LNG loading at Qalhat would show how the LNG market is adapting to a severe regional disruption. The effective closure of the Strait of Hormuz has left Qatar’s LNG supply constrained and much of its specialised carrier fleet underutilised.

The cargo details remain uncertain. Mesaimeer could load a typical cargo of around 72,000t, or a much larger parcel closer to the vessel’s historical maximum.

QatarEnergy Fleet Faces Limited Alternative Deployment

Q-Flex and Q-Max vessels are the largest LNG carriers in the market. Their size gives QatarEnergy efficiency on established routes, but it also limits flexibility during a regional shipping crisis.

Many ports cannot handle Q-Flex or Q-Max dimensions. These vessels also carry larger cargoes than many buyers or terminals can easily absorb, making them less attractive in the open spot market.

QatarEnergy has offered some vessels into the spot relet market and through bilateral channels. But traders showed limited interest because of high boil-off, bunker consumption, port restrictions and large cargo sizes.

Mesaimeer’s planned Qalhat loading is therefore significant. The vessel has only loaded at Ras Laffan since entering service in 2009, so a non-Qatari loading would represent a rare operational shift.

Oman’s 11.4mn t/yr Qalhat terminal offers one possible route to keep QatarEnergy-controlled tonnage active while Ras Laffan flows remain disrupted. It is still unclear whether QatarEnergy sublet the vessel or purchased a free-on-board cargo from Qalhat.

The development highlights a key LNG market lesson. Large-scale export systems can be highly efficient in normal conditions, but specialised shipping assets become harder to redeploy when chokepoints close.

Golden Pass Could Offer Another Outlet for Q-Flex Vessels

QatarEnergy may also use Q-Flex vessels at the Golden Pass LNG terminal in the US, where it owns a 70% equity stake. ExxonMobil holds the remaining interest in the 18.1mn t/yr project.

Golden Pass is located at Sabine Pass, where typical Q-Flex vessel dimensions can transit. That makes the terminal a logical option if QatarEnergy needs alternative loading points for its large carrier fleet.

The Q-Flex vessel Al Nuaman is already holding offshore Golden Pass with an AIS declaration for Sabine Offshore Anchorage. This suggests QatarEnergy is evaluating practical deployment options outside the Gulf.

If Q-Flex vessels begin loading regularly outside Qatar, it could reshape short-term LNG logistics. It would also create new operational patterns for large LNG carriers that have historically served a highly concentrated Qatari export system.

The broader market issue is supply-chain resilience. The Strait of Hormuz disruption has exposed how LNG trade depends not only on production capacity, but also on shipping access, fleet compatibility and terminal flexibility.

For LNG buyers, the main concern is cargo availability. For shipowners and traders, the problem is whether large specialised vessels can be economically redeployed during a regional crisis.

The Metalnomist Commentary

The Mesaimeer’s possible Qalhat loading shows that LNG logistics are being forced into emergency adaptation. The larger lesson is clear: energy security now depends on flexible shipping, diversified terminals and vessels that can operate beyond their original trade lanes.

Trump's Abrupt Tariff Decision: Pausing Global Levies While Increasing China's Tariffs

China Tariff

In a surprising shift, President Donald Trump announced that he would pause the punitive tariffs on key US trading partners, which were set to begin today. However, he simultaneously raised tariffs on Chinese imports to an extraordinary 125%. This move marks a significant reversal from earlier statements, as Trump justified the pause with the recent volatility in financial markets, particularly in the stock and bond markets.

Pausing Global Tariffs but Targeting China

Trump’s decision, announced via social media, paused reciprocal tariffs on nearly every country except China. These tariffs, which had ranged from 17% on countries like the Philippines and Israel to 49% on Cambodia, were set to begin today. The pause will last for 90 days, offering a temporary respite to US trading partners.

However, the increased tariffs on Chinese imports stand in stark contrast. According to Treasury Secretary Scott Bessent, the tariff rate on China will rise to an unprecedented 125%. This escalation follows ongoing trade tensions between the US and China, with China repeatedly increasing its trade actions against the US.

The EU, which would have faced a 20% tariff starting today, has already prepared retaliatory measures. The European Union has also proposed countermeasures for the 25% tariff on steel and aluminum imports imposed earlier by the US.

Flexibility in Tariff Policy and Trade Negotiations

In a shift from earlier policy, President Trump indicated a willingness to consider exemptions for certain US importers who may be disproportionately affected by the tariffs. This move contrasts with previous statements where the administration had insisted on a blanket approach. Energy commodities and critical minerals were exempt from both the baseline 10% tariff and the higher reciprocal tariffs.

Furthermore, Bessent suggested that trade discussions may also involve non-trade issues, with the US considering a major LNG project in Alaska that could attract interest from South Korea, Japan, and Taiwan. These potential deals could factor into negotiations aimed at reducing the US trade deficit with these countries.

China’s Response and Global Impact

China, predictably, responded to the new tariffs with its own retaliatory measures. As of April 10, China will increase import tariffs on US goods by 50 percentage points, reaching a total of 84%. This escalation underscores the growing trade conflict between the two largest economies in the world.

The UK and Canada have also indicated potential countermeasures. The UK, which remains subject to a 10% tariff, has included refined oil products from the US in a list of goods that could be targeted. Mexico and Canada, however, were excluded from the latest round of tariffs, further highlighting the complex nature of US trade policies.

Uncertainty Surrounds Tariff Strategy

The sudden reversal in tariff policy caught many in the administration by surprise. US Trade Representative Jamieson Greer, who had been testifying before the House Ways and Means Committee, was blindsided by the announcement. This left many questioning the coherence and strategy behind Trump’s tariff decisions.

Representative Steven Horsford of Nevada remarked that there appeared to be no clear strategy, as evidenced by Greer’s reaction. This further compounded the sense of unpredictability surrounding US trade policy.

Conclusion: A Shifting Trade Landscape

President Trump's abrupt changes to tariff policies, particularly the increase in tariffs on China, signal that the US is deepening its trade conflict with the country. While the temporary pause on global tariffs provides some relief to US allies, the continued escalation with China may have long-lasting effects on global trade dynamics. As negotiations unfold, businesses worldwide will be watching closely to understand the full impact of these decisions.

Argentina copper mine investment accelerates under Rigi incentive framework

Argentina copper mine

Argentina copper mine investment is entering a new phase under the Rigi incentive framework. The approval of McEwen Copper’s $2.7bn Los Azules project signals that Argentina copper mine investment is now central to the Milei government’s economic strategy. As a result, Argentina copper mine investment is being positioned as a key pillar for both fiscal reform and long-term export growth.

Rigi turns Los Azules into a flagship Argentina copper mine investment

The Los Azules project is the first copper mine approved under Argentina’s large-scale investment regime, Rigi. The scheme offers a 25pc tax rate instead of 35pc, 30 years of legal stability and exemption from import duties on capital goods. These incentives are designed to de-risk Argentina copper mine investment amid currency volatility and political uncertainty. Construction at Los Azules could begin as early as 2026, subject to permitting approvals. The mine is expected to produce about 175,000 t/yr of copper, placing it among the country’s most significant future producers. This scale matters for Argentina’s balance of payments, because copper exports can provide stable hard-currency revenues.

Copper anchors Argentina’s wider energy and mining investment push

The Los Azules approval is part of a broader Rigi pipeline that already totals $15.7bn in committed projects. The portfolio spans two solar plants, two lithium mines, an oil pipeline, an LNG facility and a steel mill. Together, these projects illustrate how copper, lithium and energy infrastructure are being bundled into a single strategic investment narrative. The government is targeting at least $50bn in energy investment and another $50bn in mining by 2027. That timeline aligns with president Javier Milei’s current term and his wider macroeconomic adjustment agenda. At the same time, Argentina is courting external financial support, including a potential $20bn currency swap backed by the US government. Stable capital inflows are critical to sustain Rigi and reassure foreign mining investors.

The Metalnomist Commentary

Los Azules shows how targeted tax stability and customs relief can unlock large-scale copper capex even in a risky macro environment. The challenge will be execution: permitting, infrastructure delivery and social licence will determine whether this project hits its 2026–27 window. For the global copper market, Argentina’s success or delay at Los Azules will shape future supply expectations in the second half of the decade.

India Renewable Curtailment Exposes Grid Bottleneck Behind Clean Power Growth

Ember

India renewable curtailment reached around 300GWh in January-March because of transmission constraints, showing that the country’s clean power buildout is now running ahead of grid readiness. The lost generation accounted for nearly two-thirds of India’s total renewable curtailment in the first quarter.

India renewable curtailment was concentrated in renewable-heavy northern and western grid pooling stations, especially Rajasthan and Gujarat. These regions have added large solar and wind capacity, but transmission expansion has not kept pace.

India renewable curtailment is strategically important because wasted clean power weakens project economics, increases peak power costs and delays the energy transition. It also highlights rising demand for grid materials, including copper, aluminium conductors, transformers, electrical steel and battery storage systems.

The curtailed volume represented around 1.5-2% of total renewable generation from interstate transmission system-connected plants in northern and western India. On 30 March alone, India lost 34GWh of renewable output because of insufficient transmission margins.

Transmission Delays Threaten Renewable Project Economics

India has achieved only around 80% of its annual transmission buildout targets over the past five years. That gap is now becoming visible in curtailment, grid connection delays and weaker returns for renewable developers.

One in four interstate transmission schemes scheduled for the 2026-27 fiscal year faces delays of at least one year. Around 20GW of renewable capacity is expected to face grid connectivity delays exceeding four months.

These delays carry direct financial consequences. A six to twelve-month delay in solar projects can reduce internal rates of return by 100-200 basis points because of lost early cash flows and higher financing costs.

The problem also affects India’s fuel import exposure. Curtailed renewable generation could have displaced costly gas-fired power during peak demand periods, reducing reliance on expensive LNG at a time when spot gas prices were elevated by the US-Iran war.

For metals markets, the message is clear. India’s renewable buildout now needs faster transmission investment, which means more demand for aluminium conductor, copper cable, transformers, substations, steel structures and grid equipment.

BESS Deployment Offers Near-Term Relief

Battery energy storage systems could provide a near-term solution at renewable pooling stations. Ember estimates that around 3-4GW of two-hour storage could absorb most curtailed renewable generation.

The economics are becoming more attractive. Stored solar power delivered at 7-8 rupees/kWh would remain below the Rs9-10/kWh many Indian states pay for peak-demand electricity.

This makes BESS deployment more than a technical fix. It is a cost-control tool, a grid-stability tool and a way to protect renewable project returns.

Battery storage demand also has materials implications. BESS deployment supports demand for lithium, phosphate, graphite, copper, aluminium, power electronics and thermal management systems, with lithium iron phosphate likely to remain important for stationary storage.

India’s southern region recorded no transmission-related renewable losses because renewable additions and transmission readiness were better aligned. That contrast shows that curtailment is not inevitable; it is a planning and execution problem.

India’s clean power transition will therefore depend on synchronising generation, transmission and storage investment. Solar and wind additions alone will not deliver energy security if power cannot move from renewable zones to demand centres.

The Metalnomist Commentary

India’s renewable curtailment shows that the energy transition is becoming a grid materials story. The next bottleneck is not only solar panels or wind turbines, but transmission capacity, storage deployment and the metals needed to move clean electricity.

Australia–Japan critical minerals partnership targets secure supply chains

Critical Minerals

Australia–Japan critical minerals partnership moves to the forefront of bilateral ties. Australia–Japan critical minerals partnership builds on decades of energy cooperation. Australia–Japan critical minerals partnership seeks resilient, non-China supply for strategic industries.

From energy security to economic security

Australia and Japan will deepen cooperation on critical minerals. The focus shifts from LNG and coal to strategic metals. Penny Wong flagged economic security as the next stage of ties. Japan depends on stable inputs for EVs, magnets, and semiconductors. Australia offers scale, rule-of-law, and proximity to Asian markets.

Deals signal scope across rare earths and nickel

Existing projects anchor momentum for the Australia–Japan critical minerals partnership. Sojitz and Jogmec signed an A$200mn Lynas offtake in 2023. They agreed to buy 65% of Lynas’ heavy rare earth output. Sumitomo Metal Mining and Mitsubishi joined Ardea’s Kalgoorlie nickel project. The study outlines potential to reach 4mn t/yr of nickel. These deals pair Japanese capital with Australian resources and processing.

Strategic rationale and next steps

The partnership seeks resilient, transparent supply chains. It aligns with allied de-risking and industry policy goals. Therefore, both sides will likely back midstream processing in Australia. Meanwhile, long-term offtakes can underwrite project finance. Standardization and ESG traceability will strengthen market access. Early wins could include magnet-grade REO and battery-grade nickel.

The Metalnomist Commentary

Tokyo and Canberra are upgrading a proven model: Japanese investment plus Australian ore becomes strategic metals. The hinge now is midstream capacity and bankable offtakes; refining in Australia will test costs but de-risk geopolitics.

BP appoints Meg O’Neill as next CEO in April

Meg O’Neill

BP appoints Meg O’Neill as next CEO starting April. BP appoints Meg O’Neill as next CEO after Murray Auchincloss steps down on 18 December. Therefore, the leadership change signals continued focus on disciplined capital allocation.

Auchincloss leaves after more than three decades at BP. BP will name Carol Howle interim chief until O’Neill arrives. Meanwhile, Auchincloss will advise through December 2026 to support the handover.

Leadership transition highlights Woodside track record

O’Neill grew Woodside into Australia’s largest listed energy company, BP said. She also led Woodside’s acquisition of BHP Petroleum International. Earlier, she spent more than two decades at ExxonMobil.

BP appoints Meg O’Neill as next CEO as investors demand steadier execution and returns. Chairman Albert Manifold highlighted transformation, growth, and disciplined capital allocation. As a result, BP will likely emphasize cash flow, dividends, and project discipline.

Strategy reset keeps hydrocarbons central as spending tightens

BP reset its energy transition strategy earlier this year. Auchincloss said BP expected a faster transition, but the outlook changed. Therefore, BP raised its 2030 oil and gas output target and cut renewables spending.

O’Neill will inherit a portfolio that balances hydrocarbons with selective low-carbon bets. Meanwhile, BP must manage trading and shipping under higher geopolitical risk. Therefore, markets will watch capital discipline, project delivery, and cost control first.

The Metalnomist Commentary

This appointment fits BP’s pivot toward returns and operational reliability. However, O’Neill must defend the strategy amid volatile oil and LNG cycles. If she executes, BP could regain valuation support.

Butting Alabama stainless pipe plant to anchor US expansion

Butting

The Butting Alabama stainless pipe plant will house the company’s US headquarters and first factory. The Butting Alabama stainless pipe plant represents a $61mn investment in Baldwin County. The Butting Alabama stainless pipe plant strengthens domestic stainless supply near Mobile.

Phase one: headquarters and cryogenic fabrication

Butting will build its US headquarters with engineering and fabrication functions. The first phase includes stainless spools, components, and cryogenic pipe systems. Construction is expected to begin in the fall. This phase establishes talent, tooling, and customer qualification pathways.

Phase two: welded pipe mills and capacity growth

The second phase adds two stainless welded pipe mills. It also expands cryogenic production and broader fabrication capabilities. As a result, US buyers gain localized lead times and lower logistics risk. The phased plan targets energy, LNG, chemicals, and industrial projects across the Gulf Coast.

The investment supports reshoring across stainless and specialty piping. Meanwhile, regional suppliers can align material grades and specs faster. Therefore, project developers can reduce schedule slippage and inventory costs.

The Metalnomist Commentary

Butting’s two-step build creates early customer access, then mill-scale depth. Execution will hinge on workforce, power, and niche alloy sourcing. Watch order backlogs and Gulf Coast project awards through phase two.

Energy Security Investment Rises as IEA Sees $3.4 Trillion Global Spend

IEA

Energy security investment is accelerating as the war in the Middle East and the de facto closure of the Strait of Hormuz push governments and companies to diversify supply. The IEA expects global energy investment to reach $3.4 trillion in 2026.

Energy security investment is now shifting strongly toward electricity, grids, storage, renewables, nuclear, low-emissions fuels and efficiency. The IEA expects around $2.2 trillion to flow into these areas, compared with about $1.2 trillion for fossil fuels.

Energy security investment also carries direct metals implications. More spending on grids, storage, solar, wind, nuclear and electrification will support demand for copper, aluminium, electrical steel, lithium, nickel, rare earths and other critical materials.

The IEA described the current crisis as the largest energy security crisis the world has faced. It expects decision-makers to prioritise resilience, diversification and trusted energy partners.

Electricity Spending Becomes the Core Security Response

Electricity-related investment is becoming the dominant theme in global energy spending. The IEA expects investment in electricity supply and infrastructure to reach nearly $1.6 trillion in 2026.

That figure rises to about $2 trillion when end-use electrification is included. This shows that energy security is no longer only about oil and gas supply. It is increasingly about reliable power systems.

Power grids will be central to this shift. Grid expansion, storage deployment and electrification require large volumes of copper, aluminium and electrical equipment.

Renewables will also remain a major investment channel. The IEA expects renewables spending to reach around $665bn in 2026, including $365bn for solar, $200bn for wind and $75bn for hydropower.

Annual renewables spending growth has moderated because of lower technology costs and policy changes in China and the US. However, low-emissions sources still account for more than 70% of global power investment.

The metals signal is clear. Energy security policy is reinforcing the same material demand base already supported by decarbonisation. Grid metals, battery materials and renewable energy inputs remain structurally important.

Fuel Supply Shock Keeps Fossil Investment Alive

Fossil fuel investment is also rising in selected areas. Total fossil fuel supply investment is expected to exceed $1 trillion in 2026, returning to 2024 levels.

Oil investment is expected to fall for a third consecutive year to below $500bn. Long project lead times, supply-chain limits, offshore rig tightness and uncertainty over the duration of the price spike are limiting near-term spending outside the Middle East.

Natural gas investment is moving in the opposite direction. The IEA expects gas investment to reach $330bn, the highest level in a decade, supported by LNG export projects and demand from data centres.

Coal investment is also expected to rise to $180bn, the highest level since 2012. Around 70% of that spending is expected in China, while some Asian countries may keep existing coal-fired power plants running longer to protect energy security.

The IEA said past investments in renewables, nuclear, efficiency and electrification have already improved energy security in major fuel-importing regions. It estimated that China, the EU, Japan, South Korea, southeast Asia and India avoided around $260bn in fossil fuel imports in 2025.

The conflict is also forcing a search for new energy export routes to reduce reliance on the Strait of Hormuz. Repair costs for damaged energy infrastructure are expected to reach tens of billions of dollars.

For industrial markets, the result is a more complex energy outlook. Electricity investment is rising fast, but gas and coal remain part of short-term security planning. That mix will shape metals demand, energy costs and industrial competitiveness.

The Metalnomist Commentary

The IEA’s outlook shows that energy security and electrification are now the same investment story. The winners will be supply chains that can deliver grids, storage, renewables and critical minerals at scale while reducing exposure to fragile fuel routes.

Glencore Argentina Copper Projects under Rigi Signal $13.5bn Shift

Glencore

Glencore Argentina copper projects under Rigi advance with a $13.5bn plan. The firm seeks Rigi incentives for two mines. The Rigi framework offers 30 years of legal stability. Therefore, Glencore Argentina copper projects under Rigi gain tax and customs relief. The bid is the largest package submitted to date. As a result, Glencore Argentina copper projects under Rigi could reset national copper ambitions.

Rigi Catalysts and Project Scale

Rigi reduces taxes and duties for large investments. It also anchors predictable rules for three decades. Glencore proposes $9.5bn for El Pachón in San Juan. Agua Rica adds $4bn in Catamarca province. Both deposits include copper with gold, molybdenum, and silver. Management praised President Milei’s policy shift. The incentive program launched in 2024 and is expanding.

Argentina’s Copper Reset and Lithium Context

Argentina ended copper production in 2018. However, the country still holds sizable copper reserves. New projects could restore refined output over time. Meanwhile, Argentina is rising in global lithium. Production reached 18,000t in 2025, per USGS data. Approved Rigi projects span lithium, solar, LNG, oil, and steel. Therefore, midstream and mining investments are converging.

The Metalnomist Commentary

Rigi de-risks capex and timelines, which attracts major balance sheets. Yet execution still depends on permits, power, water, and offtakes. Watch EPC awards and community agreements to gauge bankability.

Rio Tinto's $2.5 Billion Investment Boosts Argentina's Lithium Production Capabilities

Rio Tinto Argentina's Lithium

International mining giant Rio Tinto has announced a substantial $2.5 billion investment in the expansion of its Rincon lithium operation in Argentina, aiming to increase the country's lithium production six-fold over the next decade. This move marks a significant step in Argentina's ambition to become a leading global energy supplier.

Strategic Expansion and Technological Advancements

The Rincon project, located in Salta province, commenced with a 3,000 metric tons per year starter plant in November and is Rio Tinto's inaugural commercial lithium operation. The new investment will enhance annual production to 60,000 metric tons of battery-grade lithium carbonate. Utilizing advanced direct lithium extraction (DLE) technology, the expansion is set to begin construction in mid-2025, with ramped-up production expected to start in 2028 and reach full capacity early in the next decade.

This strategic enhancement not only elevates Rio Tinto's position in the lithium market but also contributes significantly to Argentina's growing status in the global energy sector, alongside its LNG and oil exports.

Argentina's Lithium Market and Economic Reforms

Argentina currently ranks as the fourth-largest lithium producer globally, boasting substantial reserves and resources. The nation is a crucial part of the "lithium triangle," which includes neighboring Bolivia and Chile and holds about 60% of the world's lithium resources.

In support of such large-scale investments, Argentina has implemented economic reforms including the Regimen de Incentivo Grande Inversiones (RIGI), which offers tax and customs benefits, and legal stability for investments exceeding $200 million. Rio Tinto is among the companies poised to benefit from RIGI, reflecting a favorable investment environment under President Javier Milei's administration, which has also introduced sweeping tax reforms aimed at boosting economic stability and growth.