IQE GaSb and GaN strategy pivots business toward AI and power markets amid sale options

IQE

IQE’s GaSb and GaN strategy is reshaping the UK compound semiconductor maker as it explores a potential sale of the company. The IQE GaSb and GaN strategy shifts focus toward high-value sensing, photonics and power electronics while legacy wireless markets remain under pressure. As a result, the IQE GaSb and GaN strategy now sits at the core of IQE’s turnaround and M&A narrative.

IQE has continued to rationalise its footprint while redirecting capital to growth nodes. The firm suspended manufacturing at its Silicon site in south Wales and plans to exit fully by the fourth quarter, with a new operator taking over the facility. This follows the sale of its decommissioned Bethlehem, Pennsylvania site in late 2023, with skills, IP and customers transferred to Greensboro, North Carolina. That larger US site now anchors IQE’s presence in advanced sensing, optical communications, aerospace, defence and wireless markets.

However, the restructuring runs in parallel with a strategic review that has widened from a Taiwan business sale to a possible sale of the entire company. IQE has been approached by at least one potential buyer and has received further early expressions of interest. Any acquirer would gain exposure across all four III-V platforms — GaAs, InP, GaN and GaSb — with particular upside in infrared sensing, AI data communications and GaN power electronics.

GaSb sensor momentum underpins IQE GaSb and GaN strategy

GaSb is emerging as a central pillar of the IQE GaSb and GaN strategy, especially in infrared and space imaging. IQE holds GaSb substrate manufacturing capacity in Spokane, Washington, and in Milton Keynes in the UK, creating a transatlantic supply base. The company has shipped its first commercial 6-inch GaSb epiwafers for large-area sensor products used in advanced space and satellite imaging.

These technology milestones are now backed by tangible orders. IQE secured a first-year $1.7mn purchase order for GaSb epitaxial wafers under a three-year agreement with a long-standing infrared sensing customer. It also landed a $4.1mn purchase order for antimonide substrates, with deliveries running into 2026. These sensors target industrial, aerospace and security applications, where long qualification cycles favour stable, specialist suppliers.

Meanwhile, photonics revenue remained broadly flat at £26.6mn in the first half, compared with £26.8mn a year earlier. Strong InP demand for AI-driven data communications offset delays in US military and defence infrared programmes. IQE also launched a 6-inch foundry platform for silicon photonics, positioning GaSb and InP technologies inside emerging AI and hyperscale data centre architectures.

GaN power growth, AI demand and risks to IQE GaSb and GaN strategy

On the GaN side, IQE is expanding reactor capacity for 8-inch GaN-on-silicon targeted at gesture recognition in AR and VR displays. At the same time, it is developing high-voltage (>1,000V) GaN technologies, including vertical GaN and GaN-on-sapphire, to serve automotive power electronics and radar markets. These developments reinforce how GaN power is becoming a key enabler for AI-era data centre power needs and high-efficiency conversion.

Management sees this GaN power pivot as crucial to long-term growth. Chief executive Jutta Meier highlighted the diversification into GaN power and connectivity as the right strategy, citing surging AI-related infrastructure and communications demand. IQE expects to benefit from the exit of a key GaN foundry player, which could free market share for its expanded platform. Multiple Tier 1 design wins in laser and detector products for AI and hyperscale data centres signal that the IQE GaSb and GaN strategy is already landing important customers.

Yet the investment case also carries risks. First-half group revenue fell to £45.3mn from £66mn, driven by a 52pc collapse in wireless revenue to £18.6mn. Overhang from 2024 inventory builds, tariff uncertainty and weak smartphone demand continue to weigh on handset-linked GaAs volumes. IQE expects wireless inventories to normalise only from 2026 and now guides 2025 revenue at £90-100mn, down from £118mn in 2024. The success of the IQE GaSb and GaN strategy must therefore offset a structurally weaker wireless segment and fund ongoing capacity shifts.

The Metalnomist Commentary

IQE is moving from a broad, handset-heavy portfolio toward a more focused, higher-margin mix centred on GaSb sensing, GaN power and AI photonics. That repositioning strengthens its appeal as a strategic target for buyers seeking exposure to AI infrastructure and defence-linked semiconductors. The key question is whether GaSb and GaN growth can ramp fast enough to stabilise revenues before wireless markets recover.

Adani Nuclear Power Capacity Plan Targets 10GW by 2035

Adani

Adani nuclear power capacity could reach 10GW by 2035 as the Indian conglomerate expands into atomic energy alongside thermal, renewable, hydroelectric and gas-based generation. The plan would make Adani one of the most ambitious private entrants into India’s nuclear power sector.

Adani nuclear power capacity development comes as India seeks to widen private participation in nuclear generation. The country needs significantly more reliable baseload power to support industrialisation, electrification and rising digital infrastructure demand.

Adani nuclear power capacity will be developed through Adani Atomic Energy, a wholly owned subsidiary incorporated by Adani Power in February. The business is authorised to generate, transmit and distribute electricity from nuclear and atomic energy.

The group has not disclosed potential sites, reactor configurations or grid integration plans. However, the 10GW target would represent around one-tenth of India’s planned 100GW nuclear fleet by 2047.

Nuclear Adds Baseload Power to Adani’s Integrated Energy Strategy

Adani plans to invest more than Rs2 trillion over the next five years to expand its overall power generation portfolio to 45GW. The programme covers thermal power, renewables, hydroelectricity, pumped storage and supporting transmission infrastructure.

Nuclear adds a different capability to that portfolio. It can provide large-scale, low-carbon baseload electricity while renewable generation expands.

India currently has around 8.8GW of installed nuclear capacity, with nuclear supplying about 3% of national electricity generation in the 2024-25 financial year. Reaching 100GW by 2047 would therefore require a major acceleration in construction.

Private-sector participation could help provide capital, engineering capacity and project execution. However, nuclear projects require long development periods, strict regulation, specialised supply chains and large upfront investment.

For Adani, nuclear could complement its existing thermal and renewable assets. A diversified generation mix gives the group more flexibility as India’s power demand rises.

The company also remains heavily invested in coal generation. Adani Power operates 18.33GW and has 23.72GW of locked-in capacity, giving it a target of 42.05GW by the 2031-32 financial year.

Data Centres and Grid Growth Strengthen Power Demand Outlook

Adani’s nuclear target also fits rising electricity demand from digital infrastructure. The group’s data centre business aims to reach 3GW of capacity by 2030, supported by growth in artificial intelligence and cloud computing.

Data centres require continuous, high-quality power. This increases the value of generation sources that can provide round-the-clock electricity alongside renewable power and storage.

Adani is also expanding hydroelectric and pumped-storage capacity. Through its partnership with Bhutan’s Druk Green Power, the group plans to jointly develop up to 5GW of hydropower and pumped storage.

The portfolio increasingly resembles a full energy system rather than a collection of individual generation assets. Thermal power provides dispatchability, renewables lower emissions, storage balances variability and nuclear could add low-carbon baseload.

This strategy also carries metals implications. Nuclear, grids, data centres and transmission infrastructure require large volumes of copper, aluminium, specialty steels, zirconium alloys and other engineered materials.

If Adani executes even part of the 10GW nuclear target, India’s nuclear supply chain will need more qualified equipment, materials, engineering and fuel-cycle capacity.

The Metalnomist Commentary

Adani’s nuclear plan shows that India’s power strategy is moving toward a broader mix rather than a renewables-only model. The industrial opportunity will extend beyond generation into grids, specialty metals, nuclear-grade materials and long-term power infrastructure.

Germany Data Centre Capacity Strategy Targets Major AI and Grid Expansion by 2030

Data Center

Germany data centre capacity is set for a major expansion after the cabinet adopted a national strategy targeting at least a two-fold increase by 2030. The plan also aims to quadruple Germany’s AI and high-performance computing capacity over the same period.

The strategy reflects Germany’s push to strengthen digital sovereignty while competing for AI infrastructure investment. It also places data centres directly inside the country’s energy, grid, and industrial planning agenda.

Germany data centre capacity stood at 2.98GW in 2025, more than double the level recorded in 2010. AI and high-performance computing capacity totalled 500MW, while total data centre power consumption reached 21TWh.

Grid Connections Become the Main Bottleneck for AI Infrastructure

Germany’s data centre strategy identifies grid access as one of the biggest constraints on future growth. The country has strong supply security and a renewables-rich power mix, but long connection queues and limited grid capacity could slow new projects.

The strategy calls for data centre demand to be included earlier in grid infrastructure planning. It also supports more flexible connection rules, allowing transmission system operators to reserve capacity for data centres where competition for grid access is intense.

This matters for metals and electrical infrastructure suppliers. Faster data centre growth will increase demand for transformers, switchgear, copper and aluminium conductors, power cables, busbars, cooling systems, and grid reinforcement materials. The Frankfurt metropolitan area, already Germany’s largest data centre cluster, will remain a focal point for these constraints.

Energy Planning and Renewables Must Keep Pace With Digital Demand

Germany data centre capacity growth will only remain sustainable if renewable energy and grid infrastructure expand at the same pace. The strategy highlights the need to use existing infrastructure more efficiently while improving digitalisation at the distribution system operator level.

The new maturity-level procedure for large consumer grid applications is designed to create a clearer queue for major power users. Industry groups also support faster approval processes, early identification of priority areas, and better planning around water requirements.

For industrial supply chains, the message is clear. AI infrastructure is becoming a power-intensive manufacturing and materials story, not only a digital services story. As Germany scales AI and HPC capacity, the country will need more electrical metals, power equipment, cooling infrastructure, and grid-ready industrial zones.

The Metalnomist Commentary

Germany’s data centre strategy shows how AI growth is turning grid capacity into an industrial competitiveness issue. The winners will not only be cloud operators, but also suppliers of power equipment, conductors, transformers, and low-carbon electricity infrastructure.

Wanji Aluminium Smelter Starts Construction in Xinjiang With Green Power Focus

Wanji Aluminium

Wanji aluminium smelter construction has started in China’s Xinjiang region, marking another step in the country’s shift toward larger, more energy-efficient primary aluminium capacity. The 580,000 t/yr project will require total investment of 4.6bn yuan, or about $667 million.

The Wanji aluminium smelter will use Xinjiang’s clean energy resources, including integrated wind and solar power. This gives the project a lower-carbon positioning at a time when electricity source, power cost, and emissions intensity are becoming central to aluminium competitiveness.

Wanji aluminium smelter development also follows China’s capacity replacement policy. The company currently operates a 580,000 t/yr smelter in Luoyang, Henan province, which is scheduled to be demolished by December 2027 after the Xinjiang capacity is completed.

Xinjiang Project Targets High-Efficiency Aluminium Production

The Xinjiang smelter will use 600kA large-scale electrolytic cells, which Wanji described as the world’s most efficient technology. The project will also adopt advanced process systems to reduce energy use and improve operating performance.

Power consumption is expected to be as low as 12,430 kWh/t of aluminium. That level would place the facility among the world’s most energy-efficient aluminium smelting operations.

This matters because aluminium smelting is one of the most electricity-intensive industrial processes. Producers with access to low-cost renewable power and efficient electrolytic cells can gain a structural advantage over older smelters exposed to coal power, higher tariffs, or carbon costs.

Capacity Replacement Supports China’s Aluminium Upgrade Strategy

The project is moving forward in line with Wanji’s capacity replacement plan released in August 2025. China has encouraged aluminium producers to upgrade electrolytic baths and shift more production toward greener energy sources.

The replacement of Wanji’s Luoyang smelter with the Xinjiang facility shows how China is reshaping its aluminium industry. The strategy is not only about adding volume, but replacing older capacity with larger, cleaner, and more power-efficient assets.

Wanji also plans to build the Xinjiang site into a fuller industrial chain, covering alumina through processed aluminium products. This could strengthen value integration and support downstream aluminium fabrication in the region.

The Metalnomist Commentary

Wanji’s Xinjiang project shows how China is combining capacity replacement, renewable power, and high-efficiency smelting technology to strengthen aluminium competitiveness. The key global implication is clear: low-carbon aluminium will increasingly depend on power strategy as much as smelter scale.

BHP renewable power for copper projects accelerates South Australia’s low-carbon shift

BHP

BHP renewable power for copper projects is moving from strategy to execution in South Australia. The new deals with Neoen link Olympic Dam, Carrapateena and Prominent Hill to dedicated wind and battery assets, reshaping their long-term emissions profile. As a result, BHP renewable power for copper projects is becoming central to the group’s decarbonisation roadmap and its compliance with Australia’s safeguard mechanism.

Wind, storage and safeguard compliance for Olympic Dam

BHP will source 100MW of renewable electricity from Neoen’s 300MW Goyder North wind farm and 200MW Goyder battery. This follows an earlier contract for 70MW from Goyder South, which has supplied Olympic Dam since July. Together, these agreements should cover about 70pc of BHP’s copper-related electricity demand in South Australia by 2030.

Olympic Dam falls under Australia’s safeguard mechanism, where on-site generation counts towards covered scope 1 emissions. In 2023-24, Olympic Dam produced 244,321t of CO₂e, staying just below its 246,875t baseline. Therefore, BHP renewable power for copper projects is not just an ESG narrative but a direct tool for avoiding the surrender of additional ACCUs or safeguard credits.

Meanwhile, BHP still surrendered 47,000 ACCUs across 16 other facilities, including iron ore, coal and nickel operations. This highlights how decarbonisation progress remains uneven across the portfolio. However, the South Australian power strategy shows how dedicated renewable contracts can reduce both compliance risk and long-term power-price exposure.

Copper decarbonisation, diesel displacement and long-term risk

BHP is targeting a 30pc cut in operational greenhouse gas emissions by 2029-30 versus 2019-20 levels. The group has already reduced operational emissions to 8.7mn t CO₂e, a 36pc decline from that baseline. In this context, BHP renewable power for copper projects provides a tangible bridge between climate commitments and actual asset-level performance.

The company ultimately aims for net-zero operational emissions by 2050, mainly by displacing diesel in its mining fleets. Progress here has lagged because of technical delays in low-emission vehicle deployment. However, locking in large-scale renewable power for copper operations buys valuable time while mobile-equipment solutions mature.

For customers and policymakers, BHP renewable power for copper projects offers a clearer line of sight to lower-carbon copper supply. This matters as OEMs, grid operators and EV supply chains increasingly differentiate between standard and low-emission copper units. It also strengthens South Australia’s positioning as a hub for renewable-powered mining and processing.

The Metalnomist Commentary

BHP’s structured shift into contracted wind and storage underscores how decarbonisation is becoming a core competitiveness issue for copper miners. For metals buyers, the next phase will involve translating these renewable power deals into quantifiable, auditable carbon advantages at the cathode, rod and cable level.

Hillside Aluminium Smelter Future Hinges on South32 Eskom Power Deal

Hillside Aluminium

Hillside aluminium smelter operations beyond 2031 will depend on a new long-term power agreement between South32 and South African utility Eskom. The companies are negotiating a replacement contract for the KwaZulu-Natal smelter before its current discounted electricity supply arrangement expires.

The Hillside aluminium smelter is one of South Africa’s most important energy-intensive industrial assets. Securing competitively priced power is essential because aluminium smelting depends on stable, large-scale and affordable electricity.

South32 and Eskom have created a working group to explore ways to bring competitively priced renewable energy into South Africa’s national grid. The goal is to support Hillside’s future power needs while also benefiting Eskom’s wider customer base.

The talks come shortly after South32 moved its Mozal aluminium smelter in Mozambique into care and maintenance after failing to secure a new electricity supply agreement. That decision highlights the strategic risk facing smelters when power contracts expire without a commercially viable replacement.

Power Security Becomes the Main Aluminium Constraint

Electricity is the defining cost factor for primary aluminium. Smelters need continuous power, and even modest changes in tariffs can determine whether production remains competitive.

The Hillside aluminium smelter currently benefits from a discounted power contract that runs until 2031. A new agreement would secure the plant’s operating future beyond that date and reduce uncertainty for workers, suppliers and downstream customers.

South32’s experience at Mozal shows what is at stake. The Mozambican smelter was moved into care and maintenance after its electricity contract expired at the end of March and no new agreement was reached.

That outcome gives urgency to the Hillside negotiations. Without a competitive long-term power solution, South32 could face difficult decisions about one of its key southern African aluminium assets.

For Eskom, the talks also carry wider industrial policy significance. South Africa needs to preserve energy-intensive manufacturing while managing grid constraints, decarbonisation pressure and the transition toward cleaner power.

Renewable Power Could Support Low-Carbon Aluminium

The working group’s focus on renewable energy shows how aluminium supply is becoming tied to decarbonisation. Buyers increasingly want lower-carbon aluminium, especially in automotive, packaging, construction and industrial applications.

A renewable-linked power solution could improve Hillside’s long-term competitiveness. It would help South32 reduce emissions exposure while keeping the smelter connected to South Africa’s industrial base.

However, the challenge is execution. Renewable power must be competitively priced, reliable and integrated into the national grid in a way that supports continuous smelter operations.

The agreement could also set a precedent for other energy-intensive industries in South Africa. If Eskom and South32 can structure a viable low-carbon power model, it may help attract or retain industrial investment in metals, chemicals and manufacturing.

For the aluminium market, the message is clear. Future smelting capacity will depend less on ore or alumina access alone and more on long-term power security, grid reliability and carbon intensity.

The Metalnomist Commentary

The Hillside power talks show that aluminium competitiveness is now an energy strategy question. South32 and Eskom must prove that South Africa can keep heavy industry alive while moving toward lower-carbon electricity.

Morocco coal power phase-out hinges on global finance

Morocco coal power

Morocco coal power phase-out plans now sit at the center of the country’s new 2035 climate strategy. The Morocco coal power phase-out commitment targets an exit from coal by 2040, but only if international partners provide large-scale financial and technical support. Without that backing, the Morocco coal power phase-out will slip into the 2040s, despite Rabat’s pledge to halt new coal plant plans.

Coal-heavy power system faces a managed transition

Morocco coal power phase-out ambitions collide with a power mix still dominated by imported coal. Coal supplied 29.2pc of Morocco’s energy and 62.2pc of its power in 2023, making the system highly exposed to fuel markets. Coal also generated 42pc of CO₂ emissions from fuel combustion in 2022, underscoring the climate stakes of any delay.

However, Moroccan utilities continue to sign long-term coal contracts while European buyers move away from such deals. This reflects the reality of a still coal-centric system that must guarantee baseload power as renewables scale. Under its new nationally determined contribution, Morocco targets a 53pc cut in greenhouse gas emissions by 2035 versus a business-as-usual path.

Meanwhile, Rabat has pledged to triple renewable capacity to more than 15GW by 2030 and expand grids and storage. These investments align domestic plans with the global Cop28 call to triple renewables. As a result, renewables growth and Morocco coal power phase-out measures are designed to move in parallel, reinforcing energy security while cutting emissions.

Financing drives timelines for coal, phosphates and methane cuts

Morocco’s new climate plan makes clear that money will decide how fast the transition happens. Around 31pc of the planned emissions reductions depend on external finance, including early coal closures and grid upgrades. The Morocco coal power phase-out therefore competes for capital with other decarbonisation priorities across industry and infrastructure.

The phosphate sector, a core pillar of Morocco’s export economy, is expected to deliver 8.35mn t of CO₂-equivalent cuts by 2035. Some of these projects will only proceed if concessional finance becomes available, highlighting the link between industrial decarbonisation and global climate funds. At the same time, Morocco has pledged deep methane reductions in agriculture and waste by 2030 and 2050, adding further investment needs.

Overall, Morocco estimates it will require around $96bn to fund mitigation and adaptation measures through 2035. Therefore, the Morocco coal power phase-out, industrial upgrades and resilience projects will all hinge on how quickly concessional and private capital flows. For international partners, the plan offers a clear pipeline of projects tied directly to measurable climate outcomes.

The Metalnomist Commentary

Morocco is signalling that coal exit timelines are now a negotiable outcome of global climate finance, not a fixed promise. For investors, the country’s combination of large phosphate reserves, ambitious renewables targets and conditional coal phase-out creates a structured opportunity set. How quickly these commitments move from paper to projects will depend on whether climate funds can match the $96bn price tag.

Battery Energy Storage Systems Accelerate Data Center Deployment

Battery Energy Storage Systems

Battery energy storage systems are becoming a practical tool for accelerating data center deployment as hyperscalers search for faster access to power. Industry executives said storage, combined with solar and wind, can help large technology companies bring major facilities online more quickly.

The discussion reflects a growing reality in the power market. Data center demand is rising alongside broader electrification, placing pressure on grids that were not designed for such rapid large-load growth.

Battery energy storage systems help address this problem by providing flexibility where grid connections, peak demand, or local capacity constraints delay projects. For hyperscalers, speed to power is now as important as land, chips, cooling, and fiber connectivity.

Storage Becomes a Bridge Between Hyperscalers and Grid Constraints

Battery energy storage systems can help data centers manage peak demand, reduce grid stress, and support faster deployment when full baseload supply is not immediately available. This makes storage a bridge between large electricity users and constrained power systems.

Invenergy said a mix of solar, wind, and storage can give hyperscalers strong speed-to-power advantages while remaining affordable. That combination is increasingly attractive because data centers need large volumes of electricity but also face public scrutiny over power prices.

The affordability issue is becoming more sensitive. US electricity prices rose by 6.3% in January, and rising demand from data centers is one of the factors adding pressure. If households feel they are paying more while large-load users secure cheaper power, the political risk around data center growth will increase.

Flexible Power Models Could Reshape Battery Demand

Technology companies are responding with a wider power strategy. Instead of relying only on large central power plants, they are looking at solar, wind, on-site batteries, demand response, and distributed storage.

Google said that in locations where peaking capacity is the main issue, faster solutions may include ramping down for short periods, switching to on-site batteries, or paying other customers to install batteries in their homes. This approach turns batteries into grid flexibility assets, not only backup systems.

For the materials supply chain, this matters because data center growth could become a stronger demand driver for batteries, lithium, graphite, iron phosphate materials, copper, aluminium, transformers, power electronics, and grid equipment. As AI infrastructure scales, battery storage will increasingly sit at the intersection of digital infrastructure and energy security.

The Metalnomist Commentary

Battery energy storage systems are moving from optional backup equipment to strategic infrastructure for hyperscaler growth. The next bottleneck for AI data centers may not be computing hardware alone, but the ability to secure flexible, affordable, and politically acceptable power.

Weda Bay Power Shift Favors Aluminium as Nickel Pig Iron Margins Weaken

Weda Bay

Weda Bay power shift plans could redirect electricity from nickel pig iron smelters toward aluminium production in Indonesia’s Weda Bay Industrial Park. The move shows how power allocation is becoming a strategic production tool when aluminium margins exceed nickel margins.

Weda Bay power shift discussions involve scaling back output at 22 NPI smelting operations in June. Market sources said the power would be redirected to Juwan, the park’s sole operating aluminium facility.

Weda Bay power shift strategy reflects changing metal economics. NPI producers are under pressure from higher nickel ore costs and weaker margins, while aluminium smelters are benefiting from firmer prices and Middle East supply concerns.

Juwan is a joint venture between Tsingshan and Xinfa, with nameplate capacity of 250,000 t/yr. The timing and scale of any NPI production cuts remain unclear.

Aluminium Margins Pull Power Away From NPI

The planned power reallocation highlights the importance of electricity in Indonesian metals production. Both NPI and aluminium smelting are power-intensive, so the most profitable metal can influence where electricity is directed.

Aluminium prices have strengthened because of supply disruption linked to the Middle East. The region accounts for about 9% of global aluminium output, making any disruption significant for global balance.

The LME aluminium cash official price rose to a four-year high of $3,767.50/t on 14 May before closing at $3,636/t on 18 May. These higher prices have improved aluminium smelting margins.

NPI margins are moving in the opposite direction. Rising nickel ore costs and weaker profitability have reduced the incentive to maintain full output at some Indonesian smelters.

This creates a clear commercial logic. If electricity is constrained or strategically controlled, producers may prefer to allocate power toward aluminium rather than lower-margin NPI.

NPI Cuts Could Tighten High-Grade Nickel Units

Any sustained reduction in Weda Bay NPI output could support nickel pig iron prices, especially for higher-grade material. Higher-grade NPI remains important for stainless steel producers that need nickel-rich blending units.

Demand for higher-grade NPI has stayed relatively firm because stainless mills are using more scrap. Greater scrap use can increase the need for higher-nickel inputs to balance melt chemistry.

The situation also shows how Indonesia’s nickel and aluminium industries are becoming increasingly connected through infrastructure. Power, ports, industrial parks and Chinese-backed investment now shape multiple metal supply chains at once.

Tsingshan is also building a new aluminium project at Weda Bay with designed capacity of 800,000 t/yr. The first 400,000 t/yr phase is expected to start by the end of this year or in early 2027.

That expansion could make power allocation even more important. If aluminium capacity grows while NPI margins remain weak, Weda Bay may increasingly prioritise aluminium production over nickel pig iron during periods of electricity constraint.

The Metalnomist Commentary

Weda Bay shows that Indonesia’s industrial parks are becoming flexible metal platforms, not single-commodity hubs. When aluminium margins beat NPI margins, electricity itself becomes the deciding raw material.

IMFA Ferro-Chrome Capacity Expansion to Make It India’s Largest Producer

Ferro-Chrome

IMFA ferro-chrome capacity is set to nearly double by the end of 2026 as Indian Metals and Ferro Alloys combines a Tata Steel asset acquisition with new furnace capacity at Kalinganagar in Odisha. The expansion will lift installed capacity beyond 500,000 t/yr, positioning IMFA as India’s largest ferro-chrome producer.

IMFA ferro-chrome capacity growth comes at a strategic moment for stainless steel raw materials. Ferro-chrome is a critical alloying input for stainless steel, and India’s rising stainless output requires more secure domestic alloy supply.

IMFA ferro-chrome capacity expansion also strengthens the company’s global position. Once complete, IMFA expects to rank among the foremost ferro-chrome producers worldwide.

The company is expanding while also restructuring its power mix. This matters because electricity is the dominant cost in ferro-chrome smelting and can decide competitiveness during weak pricing cycles.

Kalinganagar Expansion Strengthens India’s Ferro-Chrome Base

IMFA’s greenfield Kalinganagar project, known as KNR 1, will increase installed capacity to 384,000 t/yr by September from 284,000 t/yr at present. Pre-commissioning of the first furnace is scheduled for June.

The company also brought all four furnaces at its 100,000 t/yr Kalinganagar facility, known as KNR 2, on stream in March 2026. Together with the Tata Steel acquisition, these additions will significantly expand India’s domestic ferro-chrome platform.

This is industrially important because ferro-chrome supply links directly to stainless steel competitiveness. Domestic alloy availability can reduce exposure to imported material, freight costs and external supply shocks.

IMFA produced 267,300t of ferro-chrome in the April 2025-March 2026 financial year, up 2.7% from a year earlier. Sales rose by 3.9% to around 270,125t.

Quarterly output reached 68,506t in January-March, the strongest level in the period. That operating momentum gives IMFA a stronger base before the larger capacity increase takes full effect.

Captive Ore and Renewable Power Improve Cost Position

IMFA’s captive chrome ore position is central to its expansion strategy. Chrome ore output from its mines exceeded 800,000t for the first time, reaching 810,612t in 2025-26, up 15.5% from a year earlier.

Underground mining accounted for 536,000t of output. This captive supply gives IMFA better raw material control as it scales ferro-chrome production.

Energy strategy is the other major factor. IMFA plans to start 70MWp of hybrid renewable energy supply in July-September and has a binding deal for another 65MWp by June 2027.

Renewable power is expected to account for about 40% of the company’s power mix by March 2027. That shift could improve cost stability and reduce exposure to volatile power markets.

The move also supports lower-carbon ferro-alloy production. Stainless steel customers are increasingly watching the emissions profile of upstream alloy inputs, especially as export markets apply stricter carbon and sustainability rules.

IMFA also said it is exploring opportunities in critical minerals. That signals a broader growth strategy beyond ferro-chrome, although the core business remains the main focus.

For India, the expansion strengthens domestic alloy security. For IMFA, the challenge will be to ramp capacity while protecting margins, securing power and maintaining chrome ore supply discipline.

The Metalnomist Commentary

IMFA’s expansion shows that ferro-alloys are becoming part of India’s industrial security agenda, not just a stainless steel input. The real advantage will come from combining scale, captive chrome ore and lower-cost renewable power before global ferro-chrome competition tightens again.

EGA aluminium decarbonisation agreements reshape Abu Dhabi’s power model for low-carbon metal

EGA Aluminium

EGA aluminium decarbonisation agreements will rewire how Emirates Global Aluminium sources power and markets greener metal. The deal package links asset sales, long-term power purchasing, and grid upgrades into one decarbonisation roadmap. However, the strategy also locks in multi-decade electricity arrangements to protect smelter stability. Therefore, customers seeking certified low-carbon premium aluminium may see more supply and clearer contracting signals.

The headline move shifts power and water assets at Al Taweelah into new hands for $1.9bn. Abu Dhabi National Energy Company and Dubal Holding will acquire the assets, while Emirates Water and Electricity Company signs a power purchase agreement for the gas-fired plant through 2049. Meanwhile, TAQA Transmission will acquire EGA’s electricity transmission assets. As a result, EGA can focus capital on production and decarbonisation execution, rather than owning and operating utility infrastructure.

Abu Dhabi clean power deal locks long-term electricity while raising renewables share

Abu Dhabi clean power deal terms extend across the next 24 years. TAQA Distribution and Emirates Water and Electricity Company will supply power under new agreements that gradually lift renewable and clean energy share. Meanwhile, solar generation projects coming online under EWEC will drive that shift over time. Therefore, EGA can reduce its carbon intensity without destabilising baseload operations.

This structure also signals a maturing industrial power model in the UAE. The deal uses long-term contracting to de-risk both grid investment and smelter continuity. However, the pace of decarbonisation will still depend on project delivery and grid integration. As a result, procurement teams may track renewables ramp milestones as closely as aluminium premiums.

Low-carbon premium aluminium expands via CelestiAL and MinimAL output targets

Low-carbon premium aluminium will become a bigger share of EGA’s sales mix if the plan holds. EGA aims to raise production of its CelestiAL solar aluminium and MinimAL nuclear-powered aluminium to almost half of total primary output by end-2028, subject to market demand. Meanwhile, that scale-up could tighten differentiation between commodity metal and verified low-carbon units. Therefore, buyers in automotive, packaging, and construction can build greener supply chains with fewer sourcing compromises.

EGA aluminium decarbonisation agreements also influence regional competition. The move may pressure other producers to secure cleaner power, improve disclosures, and justify carbon premiums. However, premium markets will still test whether customers pay consistently for lower emissions. As a result, contract structures and traceability claims will matter as much as headline capacity.

The Metalnomist Commentary

EGA aluminium decarbonisation agreements look designed to industrialise decarbonisation, not just pilot it. However, long-dated power structures can create rigidity if policy or technology shifts quickly. Therefore, the winners will be buyers who lock in low-carbon premium aluminium with credible attributes and flexible delivery terms.

India Semiconductor Mission Adds GaN Micro-LED and Power Chip Projects

India, Semiconductor

India Semiconductor Mission has approved two additional semiconductor manufacturing projects in Gujarat, strengthening India’s push into compound semiconductors, advanced displays and power electronics. The new projects represent combined investment of about 39.36bn rupees.

India Semiconductor Mission support now includes the country’s first commercial mini/micro-LED display facility based on gallium nitride technology. This moves India beyond conventional chip assembly and into higher-value compound semiconductor manufacturing.

India Semiconductor Mission approvals have now reached 12 projects, with cumulative planned investment of about Rs1.64 trillion. The programme is becoming a central tool for reducing import dependence and building domestic semiconductor capability.

The two new projects will be developed by Crystal Matrix and Suchi Semicon. Their focus areas differ, but both support India’s broader objective of building a more complete electronics and semiconductor value chain.

GaN Micro-LED Facility Moves India Into Compound Semiconductors

Hyderabad-based Crystal Matrix will build an integrated compound semiconductor fabrication and assembly, testing, marking and packaging facility at Dholera. The plant will produce mini/micro-LED display modules and provide GaN foundry services.

The project will include epitaxy on 6-inch wafers, which is strategically important. Epitaxy is a core upstream process for compound semiconductor devices and can determine performance, yield and scalability.

The facility’s planned capacity is 72,000 m²/yr of mini/micro-LED display panels. These products can serve large-format televisions and signage, medium-sized screens for tablets, smartphones and vehicles, and micro-displays for smart glasses, smartwatches and extended-reality devices.

Gallium nitride gives the project industrial significance beyond display manufacturing. GaN is a critical material for high-brightness LEDs, power electronics, radio-frequency systems and advanced optoelectronics.

The Dholera project therefore adds a materials dimension to India’s semiconductor strategy. It links chip manufacturing policy with gallium-based compound semiconductor supply chains, where China, Taiwan, Japan, the US and Europe remain important competitors.

Power Semiconductor Assembly Supports Automotive and Industrial Demand

Suchi Semicon will establish an outsourced semiconductor assembly and test plant in Surat. The facility will focus on discrete semiconductor manufacturing for power electronics, analogue integrated circuits and industrial systems.

The planned capacity is 1.03bn chips/yr. This scale matters because India’s automotive, industrial automation and consumer electronics sectors need reliable domestic access to power and analogue components.

Power electronics are becoming more important as electrification spreads across vehicles, factories, appliances, renewable energy systems and charging infrastructure. Even basic discrete devices can become supply-chain bottlenecks when manufacturing is concentrated overseas.

The approval also strengthens Gujarat’s role as a semiconductor manufacturing hub. Dholera and Surat now join a growing cluster of projects intended to support fabrication, packaging, testing and electronics manufacturing.

Of the 10 projects approved earlier under the programme, two have started commercial shipments and two more are expected to begin operations soon. The government has also approved 104 start-ups to expand domestic chip design capability.

That combination is important. Manufacturing capacity alone is not enough. India also needs design companies, materials suppliers, equipment support, packaging capability and customers willing to qualify domestic semiconductor products.

The latest approvals show that India is trying to build depth across the value chain. GaN micro-LED fabrication brings advanced materials capability, while Suchi’s assembly and test plant supports volume supply for industrial and automotive electronics.

The Metalnomist Commentary

India’s semiconductor strategy is becoming more materials-driven, with GaN now entering the centre of its manufacturing push. The real test will be whether India can connect fabrication, epitaxy, packaging and design into a reliable domestic supply chain rather than isolated projects.

Johnson Matthey Cormetech Acquisition Strengthens Clean Air Catalyst Business

Johnson Matthey

Johnson Matthey Cormetech acquisition will expand the UK chemicals group’s clean air solutions business and strengthen its position in stationary emissions control. Johnson Matthey has agreed to buy US-based Cormetech for an enterprise value of $360mn in cash.

Johnson Matthey Cormetech acquisition terms also include a potential earn-out of up to $100mn linked to Cormetech’s performance in 2028-29. The transaction is expected to close by the end of June or July, subject to regulatory approvals.

Johnson Matthey Cormetech acquisition is strategically important because Cormetech produces selective catalytic reduction catalysts used to reduce nitrogen oxide emissions from gas and coal-fired power plants and industrial facilities.

The deal gives Johnson Matthey greater exposure to the US stationary emissions market, where tighter regulation and rising electricity demand are supporting demand for clean air technologies.

SCR Catalysts Gain Relevance as Power Demand Rises

Cormetech produces SCR catalysts that help cut NOx emissions from power generation and industrial processes. These systems remain important as power plants and heavy industrial facilities face stricter air pollution requirements.

The acquisition strengthens Johnson Matthey’s position beyond automotive emissions control. Stationary emissions are becoming more important as electricity demand rises from data centres, industrial electrification and grid reliability needs.

Data centre growth is especially relevant. Artificial intelligence infrastructure requires large amounts of reliable power, and that can support continued use of gas-fired generation in some markets.

If gas-fired power expands or runs at higher utilisation, emissions control systems will become more important. That creates a demand channel for SCR catalysts and related clean air services.

Cormetech generated sales of $129mn in 2025 and expects revenue of around $180mn in 2026. The company also expects Ebitda of about $35mn, giving Johnson Matthey an earnings-accretive platform in a growing market.

Catalyst Deal Supports Johnson Matthey’s Materials Strategy

Johnson Matthey expects the deal to increase earnings in the first full year after completion. It also expects at least $20mn in annual cost savings and revenue gains by 2030 from combining the businesses.

The transaction supports Johnson Matthey’s wider materials strategy. The company has deep expertise in catalysts, precious metals and emissions control, and Cormetech adds a stronger US industrial emissions platform.

Catalyst production also connects to platinum group metals markets, where Johnson Matthey remains a major global supplier and processor. This gives the acquisition a metals supply-chain angle beyond clean air regulation alone.

The deal comes as industrial customers face pressure to reduce emissions without compromising operating reliability. Power producers, refiners, chemical plants and industrial facilities need proven technologies that can meet regulatory requirements at scale.

For Johnson Matthey, Cormetech offers customer access, manufacturing capability and technology depth in stationary emissions control. For Cormetech, Johnson Matthey adds global scale, technical resources and commercial reach.

The acquisition shows that clean air technology remains a strategic market even as attention shifts toward batteries, hydrogen and electrification. Emissions control for existing industrial assets will still require investment.

The Metalnomist Commentary

Johnson Matthey’s Cormetech acquisition shows that decarbonisation does not eliminate the need for conventional emissions control. As data centres lift power demand, clean air catalysts could become more important for keeping gas and industrial assets compliant.

Rio Tinto signs new wind deal for Kennecott to lock in 78.5MW renewable power via VPPA

Rio Tinto, Australia

Rio Tinto signs new wind deal for Kennecott to expand renewable power coverage for its Utah copper operations. Rio Tinto signed a 15-year renewable energy supply agreement with Terra-Gen for the Kennecott copper mine near Salt Lake City. Rio Tinto signs new wind deal for Kennecott to secure 78.5MW of renewable energy from TerraGen’s Monte Cristo I wind farm in Texas. Therefore, the miner is tightening the link between low-carbon electricity and copper supply reliability.

TerraGen will supply power from the 238.5MW Monte Cristo I wind farm in Hidalgo County, Texas. The wind facility began commercial operations this week. Meanwhile, Rio Tinto structured the purchase through a virtual power purchase agreement. As a result, the company can decarbonize its electricity footprint without requiring direct physical delivery.

VPPA structure extends the Kennecott decarbonization roadmap

Rio Tinto signs new wind deal for Kennecott as part of a broader decarbonization push at the site. The company installed a 5MW solar plant in 2023 and is close to finishing a 25MW solar plant. Meanwhile, the VPPA adds longer-term renewable coverage and price visibility. Therefore, Kennecott’s energy strategy is moving from pilot assets to portfolio-style procurement.

This approach is increasingly common for energy-intensive metals. VPPAs can hedge power exposure and reduce reported emissions intensity. However, they require careful accounting and contract management. As a result, the structure matters as much as the headline megawatts.

Integrated mining, smelting, and refining makes energy a strategic lever

Kennecott is an integrated copper complex, not only a mine. The site includes a concentrator, smelter, and refinery, plus transport and storage infrastructure. Meanwhile, electricity and heat costs influence operating margins across the chain. Therefore, renewable procurement can support both decarbonization targets and resilience during power market volatility.

Copper buyers are also tightening sustainability requirements. Lower-carbon power can help miners defend market access and premium contracts. However, the benefits depend on consistent operations and transparent emissions reporting. As a result, Rio Tinto signs new wind deal for Kennecott with both cost and customer strategy in mind.

The Metalnomist Commentary

Copper is becoming an electricity story as much as a mining story. Meanwhile, integrated smelting sites face greater scrutiny on Scope 2 emissions. Therefore, long-dated VPPAs will keep spreading across the copper industry as customers demand verified low-carbon supply.

Alcoa Massena aluminum smelter investment anchors long-term US primary capacity

Alcoa Massena aluminum smelter

Alcoa Massena aluminum smelter investment marks a renewed commitment to US primary aluminum production and regional industrial jobs. The company has secured a 10-year, 240MW renewable power contract from the New York Power Authority, with extension options. This long-dated Massena renewable power deal underpins operations and gives Alcoa confidence to reinvest capital in the site. As a result, the plant’s future looks more secure in a market focused on low-carbon metal.

Alcoa will pair the new power deal with a $60mn modernization of the smelter’s anode baking furnace. The project, partially supported by a $6mn grant from Empire State Development, will run through 2028. Modern anode technology should improve energy efficiency and process stability, supporting lower emissions per tonne of primary aluminum. Therefore, the Alcoa Massena aluminum smelter investment aligns commercial resilience with decarbonisation goals.

Renewable power underpins Massena smelter competitiveness

The Massena renewable power deal is central to Alcoa’s cost and carbon strategy at the smelter. The 240MW allocation of renewable energy, starting 1 April, lowers exposure to volatile market power prices. It also strengthens Alcoa’s ability to market lower-carbon primary aluminum to automotive and packaging customers. Over time, options for two additional five-year terms could extend that visibility well beyond 2035.

Access to dedicated hydropower and other low-carbon sources is increasingly a competitive advantage in smelting. Many global smelters face pressure from higher fossil-based electricity prices and tightening climate policies. By contrast, Massena’s power structure gives Alcoa a stable platform for long-term contracts with downstream buyers. Consequently, the Massena renewable power deal reinforces the strategic value of US smelting capacity.

Modern anode baking furnace supports capacity and ESG goals

Upgrading the anode baking furnace is a critical part of the Alcoa Massena aluminum smelter investment. Carbon anodes are consumed in the electrolytic process, combining with oxygen from alumina and leaving molten aluminum. Furnace design and performance directly affect energy use, cell stability and overall emissions. New equipment should lift reliability, extend anode life and improve current efficiency in the pots.

It remains unclear whether nameplate capacity of 130,000 t/yr will change after the project. However, better anode performance often translates into higher effective output and lower unit costs. That, in turn, can support longer-term employment and justify further incremental improvements at the site. In a market where buyers increasingly demand traceable low-carbon aluminum, the Alcoa Massena aluminum smelter investment positions the plant as a more attractive supplier.

The Metalnomist Commentary

This package of renewable power and furnace modernisation shows how policy support can unlock private capital for hard-to-abate industries. If Massena’s upgraded profile leads to greener, more competitive primary aluminum, it could become a blueprint for other legacy smelters in North America. For downstream OEMs, a more secure and cleaner US supply base reduces dependence on higher-carbon imports.

South32 Mozal aluminium smelter idling set for March 2026 after power deal failure

Mozal aluminium

South32 Mozal aluminium smelter idling will begin in mid-March 2026, after the producer failed to secure a new electricity contract. The move places the Mozambique asset under care and maintenance once the current supply agreement expires. As a result, South32 Mozal aluminium smelter idling adds fresh uncertainty to regional aluminium supply and power-intensive industrial strategy.

Mozal’s production guidance for April 2025 to March 2026 remains unchanged at 240,000 tonnes on a South32-attributable basis. South32 holds a 63.7% share of Mozal aluminium. Meanwhile, the company kept its July 2025 to June 2026 aluminium guidance unchanged at 1.12mn tonnes attributable.

Mozal power supply agreement breakdown drives operational reset

The Mozal power supply agreement became the defining risk factor for continued operations. South32 could not secure a replacement contract beyond the current term. Therefore, the company chose to idle the smelter rather than operate with unpriced power exposure.

Smelters require stable, long-term electricity to remain competitive. However, power negotiations often tighten when grids face shortages or pricing volatility. Consequently, Mozambique aluminium smelter shutdown risk rises when contract renewals fail.

Portfolio impacts and alumina redirection signal commercial shift

South32 produced 311,000 tonnes of aluminium in July to September, the first quarter of its fiscal year. Output rose 4% year on year and 1% quarter on quarter. Meanwhile, production included 181,000 tonnes from Hillside, 93,000 tonnes from Mozal, and 37,000 tonnes from Brazil Aluminium.

South32 will also redirect alumina volumes previously shipped from Worsley to Mozal. The company plans to sell that alumina to third-party customers under index-linked pricing agreements. As a result, the commercial response reduces internal demand and preserves refinery sales optionality during the South32 Mozal aluminium smelter idling period.

The Metalnomist Commentary

This decision shows how power contracts now sit at the core of aluminium supply security. However, idling Mozal could tighten regional value chains and reduce Mozambique’s industrial export leverage. Therefore, future restarts will likely depend on bankable, long-duration power terms.

UK Industrial Strategy for Aluminium: energy relief expands but gaps remain

Alfed

Energy relief expands, but rules remain unclear

The UK Industrial Strategy offers relief but leaves key questions for aluminium. The UK Industrial Strategy for Aluminium expands the British Industry Supercharger. Relief on electricity network charges rises to 90pc from 60pc. However, eligibility for smaller producers and processors remains unclear. Alfed urges guidance so SMEs can budget and invest. The association warns energy competitiveness decides plant viability in Britain.

Policy gaps challenge investment signals

The paper omits critical policy linkages that affect aluminium. Alignment of the UK CBAM with the EU CBAM is undecided. Scope 2 treatment is also unspecified for reporting. As a result, midstream and secondary manufacturing face uncertainty. The UK Industrial Strategy for aluminium mentions innovation, skills and infrastructure. Yet it avoids materials security and downstream coverage. Industry hopes the coming Critical Minerals Strategy fills these gaps.

Clarity determines capital flows into decarbonised metal. Producers need predictable power relief, emissions rules and CBAM timelines. Meanwhile, recyclers require stable scrap and midstream support frameworks. Without certainty, projects stall and costs rise. Therefore, the UK Industrial Strategy for aluminium must name priorities. Recognising aluminium as strategic would anchor investment. That signal would strengthen UK supply chains and exports.

The Metalnomist Commentary

The strategy’s energy relief is meaningful, but policy silence blunts impact. Rapid guidance on CBAM alignment and SME eligibility would unlock capex. Watch the Critical Minerals Strategy for a definitive signal on aluminium’s status.

CATL LFP feedstock supply strategy accelerates amid global EV demand

CATL

The CATL LFP feedstock supply strategy is accelerating as the battery giant locks in long-term cathode materials. By prepaying key partner Shenghua, the CATL LFP feedstock supply strategy aims to stabilise costs and secure volumes. As EV demand rises, the CATL LFP feedstock supply strategy underpins CATL’s dominance in LFP batteries and its next growth phase.

Prepayments deepen CATL LFP feedstock supply chain integration

CATL has agreed significant prepayments to secure LFP from Jiangxi Shenghua, part-owned by Fulin Precision. It will pay 500mn yuan by September and a further Yn1bn in November to support Shenghua’s capacity expansion. However, supply volumes and pricing remain undisclosed, reflecting competitive sensitivity.

The CATL LFP feedstock supply strategy comes on top of earlier support for Shenghua’s new plants. CATL is backing a 160,000 t/yr LFP facility in Yichun and a 200,000 t/yr LFP plant in Sichuan. As a result, Shenghua’s LFP output already jumped from 42,159t in 2023 to 128,240t in 2024, with sales closely tracking that growth.

Meanwhile, CATL signed a Yn6bn deal with major LFP producer Jiangsu Lopal in mid-September. That contract secures 157,500t of LFP for CATL’s overseas factories from 2025 to 2031. Together, these moves show how the CATL LFP feedstock supply strategy combines prepayments, project finance and multi-year offtake to lock in LFP at scale.

CATL LFP feedstock supply supports EV battery expansion and sodium-ion push

CATL is coupling its LFP security with downstream partnerships and technology upgrades. The firm signed a cooperation agreement with EV maker Li-Auto on safety and ultra-fast charging. Li-Auto has already produced more than 1mn vehicles using CATL battery technology, cementing a deep platform relationship.

Battery installations underline the strength of CATL’s position. The company installed 190.9GWh of power batteries in January-June, up 38pc year on year. Therefore, the CATL LFP feedstock supply strategy is not just about risk management. It is also about sustaining leadership as competitors chase similar EV opportunities.

At the same time, CATL is preparing its next technology step with the Naxin sodium-ion battery. Mass shipments are targeted for 2027, with an energy density of 175Wh/kg. The company says this performance can cover over 40pc of domestic passenger vehicle demand. Sodium-ion will not replace LFP, but combined with a robust CATL LFP feedstock supply base, it gives CATL a wider toolkit across price and performance segments.

The Metalnomist Commentary

CATL is turning LFP procurement into a strategic weapon, using prepayments and capex support to secure future capacity. Its parallel push into sodium-ion suggests a portfolio approach to cathode chemistry rather than a single-bet strategy. For rivals and automakers alike, CATL’s LFP deals with Shenghua and Lopal are a clear signal that upstream security is now central to battery competitiveness.

Mirador copper mine contract extension set for 1H 2026 as Ecuador targets higher output

ECSA

The Mirador copper mine contract extension will be signed in the first half of 2026, according to Ecuador’s mining vice-minister. The deal will extend Ecuador’s agreement with China’s Ecsa-Ecuacorriente to develop the Mirador Norte deposit. As a result, the Mirador copper mine contract extension could unlock a major production step-change at the country’s only large-scale copper mine.

The negotiation has dragged on since 2023 despite expectations for an earlier completion. However, Ecuador’s 2024 power crisis slowed talks and forced new conditions around self-supplied electricity. Therefore, the Mirador copper mine contract extension now hinges on power security as much as geology.

Power constraints reshape Ecuador copper mine operations

Power reliability now dictates operational stability at Mirador. Ecuador faced scheduled blackouts for 88 days in 2024, with outages lasting between four and 14 hours. Meanwhile, harsh drought conditions and a thermoelectric shortfall tightened supply and increased grid risk.

Mirador disconnected from the grid from September to December during the crisis. The mine relied on its own thermoelectric generation, but it could not cover full demand. Consequently, Ecuador required Ecsa to install dedicated power capacity to reduce system exposure.

Mirador Norte deposit expansion targets 140,000 t/d processing

Ecsa has installed 40MW of thermoelectric power and is installing another 40MW to cover current needs. The mine still needs an additional 90MW to operate Mirador Norte at scale. Therefore, the operator plans to source that power from private suppliers developing nearby small hydroelectric plants.

Mirador Norte would lift throughput to 140,000 tonnes per day by 2027–2028, up from 70,000 tonnes per day today. This expansion would materially increase concentrate output and export volumes. Meanwhile, Ecuador’s copper strategy depends on proving it can scale mining without repeating grid disruptions.

The Metalnomist Commentary

This contract extension highlights how electricity now acts as a de-risking requirement for copper expansions. However, reliance on new private hydro supply adds schedule and counterparty risk. Therefore, Mirador’s next growth phase will test Ecuador’s ability to align mining growth with firm power delivery.

EIB and Deutsche Bank to Boost European Wind Power with €1 Billion Investment

In a significant push for renewable energy, the European Investment Bank (EIB) is set to provide a €500 million ($541 million) counter-guarantee to Deutsche Bank. This backing will enable Deutsche Bank to establish a €1 billion portfolio aimed at investing in wind farms across the European Union. This initiative marks the first step in the EIB's broader €5 billion plan to support wind power equipment manufacturers within Europe, a part of the EU's comprehensive wind power strategy designed to sustain a competitive and robust wind energy supply chain.

The EIB and Deutsche Bank's collaboration is expected to trigger private investments amounting to up to €8 billion. The EIB highlighted wind power as a significant success for the EU but acknowledged current challenges such as supply chain disruptions, inflation, and slow project permitting. The EU's net zero industry act, approved in May, aims to address these permitting issues and enhance the production rate of net zero technologies within the bloc.

The EIB's €5 billion initiative is projected to add 32GW of wind power capacity in the EU. According to the International Energy Agency (IEA), the share of wind and solar power in the EU's total energy supply is expected to increase to 30% this year, surpassing the output from fossil fuels.

As the EU's lending arm, owned by its member states, the EIB increased its climate finance to €44.3 billion last year. The bank ensures that all new projects it finances align with the Paris climate agreement and explicitly excludes investments in fossil fuels that do not contribute to CO2 emission reductions.