Thursday, July 03, 2025

 

Plenitude Breaks Ground on 200 MW Solar Park in Spain's Andalusia Region

Italian energy company Plenitude has commenced construction of the Entrenúcleos solar park, a 200-megawatt (MW) photovoltaic project located between the Andalusian municipalities of Dos Hermanas and Coria del Río. The project underscores Plenitude’s growing commitment to Spain’s renewable energy sector and is expected to generate over 435 gigawatt-hours (GWh) of clean electricity annually once operational in 2026.

The solar park, which spans more than 300 hectares and will install 326,000 solar panels, is one of the largest renewable projects currently under development in the region. Entrenúcleos will connect to the national grid via a shared substation and is part of Plenitude’s broader portfolio of approximately 580 MW under construction in Andalusia, including the Guillena and Caparacena plants.

Mariangiola Mollicone, Plenitude’s Head of Renewables in Western Europe, said the project “reflects our deep and ongoing commitment to Andalusia, a region that plays a key role in the country’s renewable energy landscape.”

The investment aligns with Spain’s national push to rapidly scale renewable energy capacity as the country targets a 74% share of renewables in its electricity mix by 2030, according to the Spanish government’s climate strategy. Spain has emerged as one of Europe’s leaders in solar power, trailing only Germany in installed photovoltaic capacity, according to the International Energy Agency.

The Andalusian government views renewables as a transformative opportunity for regional development. "Renewable energies are the oil that Andalusia never had," said Manuel Larrasa, General Secretary of the region's Energy Department, highlighting Andalusia’s potential to deliver reliable, low-cost clean energy to support Europe’s decarbonization goals.

Entrenúcleos will also serve as a testing ground for innovative construction materials, including the use of “green steel,” a zero-carbon recycled material produced in Spain. The company has committed to environmental stewardship throughout the project, incorporating vegetation screens, habitat enhancements for endangered bird species, and dedicated land for sustainable agriculture alongside the solar arrays.

Local officials welcomed the investment as a catalyst for economic growth and job creation. Francisco Rodríguez, Mayor of Dos Hermanas, said the project positions the city as "a benchmark for attracting major industrial and business projects" in the renewable sector.

Plenitude, a subsidiary of Italy’s Eni, is rapidly scaling its global renewables portfolio with a target of reaching 10 gigawatts of installed capacity by 2028. In Spain, the company currently has around 1,300 MW of operational solar and wind assets and is advancing a project pipeline exceeding 2 GW across multiple regions.

As the European Union accelerates its energy transition, large-scale projects like Entrenúcleos play a critical role in reducing dependence on fossil fuels and bolstering the continent’s clean energy infrastructure.

Biden’s Climate Legacy in Jeopardy as Trump Targets LPO Spending

  • In its final days, the Biden administration’s Energy Department rushed to approve $93 billion in clean energy loans.

  • Several recipients, including Sunnova and Li-Cycle, have already filed for bankruptcy, while others face construction delays, inflated costs, or limited financial backing.

  • The incoming Trump administration has launched a review of these loans, pledging stricter safeguards, more transparency, and a reorientation of the Loan Programs Office (LPO) toward nuclear and national-security-related energy goals.


In its last two working days, the Biden administration’s Energy Department signed off on nearly $42 billion for green energy projects – a sum that exceeded the total amount its Loan Programs Office (LPO) had put out in the past decade.

The frenzied activity on Jan. 16 and 17, 2025, capped a spending binge that saw the LPO approve at least $93 billion in current and future disbursements after Vice President Kamala Harris lost the 2024 election in November, according to documents provided by the department to RealClearInvestigations. It appears that Biden officials were rushing to deploy billions in approved funding in anticipation that the incoming Trump administration would seek to redirect uncommitted money away from clean energy projects.

In just a few months, some of the deals have already become dicey, leading to fears that the Biden administration has created multiple Solyndras, the green energy company that went bankrupt after the Obama administration gave it $570 million. These deals include:

  • Sunnova, a rooftop solar outfit that thus far had $382 million of its $3.3 billion loan guaranteed, filed for bankruptcy this month. The company did not respond to a request for comment.
  • Li-Cycle, a battery recycling facility, had a $445 million loan approved in November, but since then, the company was put up for sale and has filed for bankruptcy. The Energy Department said no money has been disbursed on that deal. Li-Cycle did not respond to a request for comment.
  • A $705 million loan was approved on Jan. 17 for Zum Energy, an electric school bus company in California, and its “Project Marigold.” At $350,000 and more, electric school buses currently cost more than twice as much as their diesel counterparts. So far, Zum has received $21.7 million from the government, according to usaspending.gov. The company did not respond to a request for comment.
  • A $9.63 billion Blue Oval SK loan on Jan. 16 was the second largest post-election deal, topped only by a $15 billion loan the next day to Pacific Gas & Electric, with most of that for renewables. The Blue Oval project in Kentucky – a joint venture between Ford Motor Co. and a South Korean entity – has been dealing with numerous workplace complaints, and construction of a second EV battery manufacturing plant there has been delayed. More than $7 billion has been obligated on that deal, according to the Energy Department. Blue Oval did not respond to a request for comment.

The money and the hasty way in which it was earmarked have drawn the attention of the Trump administration. “It is extremely concerning how many dozens of billions of dollars were rushed out the door without proper due diligence in the final days of the Biden administration,” Energy Secretary Chris Wright said in a statement to RCI. “DOE is undertaking a thorough review of financial assistance that identifies waste of taxpayer dollars.”

The enormous sums came from the 2022 Inflation Reduction Act, which injected $400 billion into the LPO, a previously sleepy Energy Department branch originally intended to spur nuclear energy projects. That total represented more than 10 times the amount the LPO had ever committed in any fiscal year of its existence. Prior to the post-election blowout, the office’s biggest fiscal year was 2024, when it committed $34.8 billion, records show.

Even with the rush to push billions out the door in its last months, close to $300 billion of the Inflation Reduction Act money remains uncommitted by the LPO. Trump administration officials have already nixed some smaller deals. Secretary Wright recently urged Congress to keep the money in place as the LPO now aims to use it to further the Trump administration’s energy policy, particularly with nuclear projects.

That unprecedented gusher of cash from the LPO echoes the efforts of the Biden administration’s Environmental Protection Agency to push $20 billion out the door before it left office. As RCI has previously reported, the EPA – which had never been a consequential grant-making operation – was tasked with awarding $27 billion in Inflation Reduction Act funding through the Greenhouse Gas Reduction Fund and Solar For All programs. It did so in less than six months in 2024, including an unorthodox arrangement in which Biden officials parked some $20 billion outside the Treasury’s control. That money was earmarked for a handful of nonprofits, some of which had skimpy assets and were linked with politically connected directors.

The LPO’s post-election bonanza was put together in even less time. The Energy Department deals, however, involve mostly for-profit enterprises, which raises questions about whether the Biden administration was propping up companies that would not have survived in the private marketplace. Should any of the companies hit it big in the future, shareholders could get rich, while taxpayers will receive only the interest on the loan.

The loan office should not be in the virtual venture business,” said Mark Mills, executive director of the National Center on Energy Analytics. “But in a few cases, it could make sense to serve as a catalyst or backstop for viable and important projects from a national security or policy perspective.”

RCI spoke with several Trump administration officials who declined to comment on the record, given the extensive ongoing review of both the LPO’s post-election arrangements and other Energy Department projects linked to Biden’s climate agenda.

They wanted to get the billions to companies that probably wouldn’t exist unless they could get money from the government,” one current official said. “The business plans, such as they were, were ‘how do we secure capital from the government?’”

During Biden’s tenure, the office was run by Jigar Shah, who on June 17 was named to the board of directors of the nonprofit Center for Sustainable Energy. Bloomberg News reported last month that Shah “helped select roughly 400 companies with development plans to receive grants and loans upwards of $100 million each.” In response to the Trump administration’s pushback on green subsidies, Bloomberg reported that Shah is working to help some of the companies he bankrolled shift operations to Europe.

The Center relies chiefly on government contracts instead of donations, and it saw that revenue jump from $274.1 million in 2023 to more than $500 million in 2024, according to tax records. The center did not respond to a request to speak with Shah.

Thus far, no entity has received the entire amount of the deals the Biden administration struck since last November, according to the Energy Department and usaspending.gov. In a handful of cases, companies have come to the current administration and opted out of the deals.

Still, millions of taxpayer dollars have already been distributed, in some instances, to deals the department listed as “conditional commitments.”  Wright has said there are “reasons to be worried and suspicious” about the post-election binge, and vowed some of the deals will be scrubbed. 

In 2023, the Biden administration made subtle changes to the LPO’s regulations, cutting strings and stipulations that traditionally attach to loans. Consequently, the office cut deals after the election on terms more favorable to the recipient than the taxpayer, and in several cases, making a “conditional commitment” the same as a loan, according to Trump officials. The changes also moved money that a later administration could have cut into “obligated” silos, making the deals harder to cancel, according to the current Energy Department.

Essentially, they had the Loan Program Office operating like a graveyard energy venture capital fund,” one Trump official told RCI. “This was all tied to the religious fervor for any green energy project in the prior administration, and the goal was not to get the government repaid but to advance the ‘green new deal.’”

The $93 billion under review represents a separate “green bank” from smaller Biden administration deals that the Energy Department has already canceled. Last month, the Government Accounting Office said the department was not on track to “issue loans and guarantees before billions of dollars of new funding expires.”

As part of the review, Wright issued policy guidelines in May that he said offer more protection to taxpayers. The department may now require significantly more information from loan recipients and applicants, such as “a project’s financial health, a project’s technological and engineering viability, market conditions, compliance with award terms and conditions and compliance with legal requirements, including those related to national security.”

The department declined to provide the terms of specific deals, again citing the ongoing review. Trump administration officials claim the business plans for many of these deals were threadbare, that term sheets were essentially tossed out, and the entire process could be described, in the words of a Biden EPA official in December, as “throwing gold bars” off the Titanic “as an insurance policy against Trump winning.”

Despite these dubious outcomes and the alleged removal of taxpayer protections that accompanied the deals, Trump administration officials said they remain committed to the LPO. The office has a valuable role to play in fulfilling energy policy goals, which include nuclear projects, strengthening the nation’s power grid, and limiting the U.S. reliance on Chinese supply chains for key minerals and elements.

“It’s as if you went away and the kids threw a rager in the house,” one official told RCI. “You may need some new furniture and the like, but it’s still a really nice home. The Office can be a critical resource for the manufacturing base of this country, and our goal is not to end the LPO but to improve it.”

The Trump administration could face some of the same financial issues if it rejiggers the LPO along lines that support its energy policy goals, particularly within the nuclear industry. Projects there have been marred by unprofitable plants and massive cost overruns and delays in construction, making federal loans to the section inherently risky. 

Prominent voices – and investors –  like Bill Gates have also encouraged the government to back new sources of energy and minerals. Geothermal projects are one such field, and there appears to be bipartisan support in Washington for capital that will shore up U.S. energy independence. On Jan. 15, the Biden administration approved a $1.2 billion “conditional commitment” with a subsidiary of EnergySource Minerals LLC (ESM), which hopes to extract lithium from geothermal brine.

A deal with ioneer Ltd. appears to match some of the professed goals of the Trump administration, but it has also been plagued by financial setbacks since Biden’s LPO approved it in its final days. The company's deal grew from an original $700 million "conditional commitment" in 2023, to the $996 million approved on Jan. 17, 2025."

The Rhyolite Ridge project is a mining and manufacturing center in Nevada to produce lithium and boron. Those elements have implications for defense and national security in addition to energy, according to ioneer Vice President Chad Yeftich. 

“Ioneer believes government policy should encourage projects if we want critical minerals developed domestically,” Yeftich said. “Time is the key risk for development as China continues to provide financial support to its critical minerals industry and dump critical minerals into the market thereby depressing the price.”

Yeftich noted Rhyolite Ridge has secured $200 million in private capital, but in February, its chief private equity partner broke ties with the project. Finance professionals familiar with big deals told RCI that such a rupture so close in timing to the loan would likely deep-six the arrangement, but Trump officials said Biden’s LPO stripped such boilerplate language from many of the post-election deals. 

Secretary Wright told RCI that these maneuvers suggested the previous administration was more interested in disbursing funds than protecting taxpayers. “Any reputable business would have a process in place for evaluating spending and investments before money goes out the door, and the American people deserve no less from their federal government.”

By Zerohedge.com

Why U.S. Electricity Prices Are Surging Despite Promises of Relief

  • U.S. electricity prices have risen faster than inflation since 2022 and are projected to increase by 13% from 2022 to 2025, driven by infrastructure costs and soaring demand.

  • Rapid growth in energy consumption by data centers and electric vehicles is straining the grid and could soon surpass supply, exacerbating future price hikes.

  • Policy changes, including the potential rollback of renewable energy tax credits, may further disrupt the energy transition and contribute to higher consumer costs.

Despite promises to bring consumer bills down, electricity prices in the United States have surged in recent years. According to the U.S. Energy Information Administration (EIA), retail electricity prices have risen more rapidly than the rate of inflation since 2022, a trend that is expected to continue through 2026. Prices have increased by 4.5 percent over the past year, at almost double the rate of inflation for all goods and services.

The price increases since 2020 can be blamed largely on the disruption of supply chains during the COVID-19 pandemic and the 2022 Russian invasion of Ukraine, which spurred the introduction of sanctions on Russian energy products. Prices have also risen due to several U.S. utilities increasing capital investment for the replacement or upgrade of ageing generation and delivery infrastructure. 

The nominal price of several fuels has declined since 2022, as crude oil prices have declined, particularly gasoline and heating oil, while electricity prices have continued to steadily increase. U.S. consumers spent an average of $1,760 on electricity expenditures in 2023. 

The EIA expects the nominal U.S. average electricity price to increase by 13 percent from 2022 to 2025, although this will vary significantly from region to region. This means that consumers may spend an additional $219 on their household electricity bills in 2025 compared to 2022. Regions such as the Pacific, Middle Atlantic, and New England, which already pay higher electricity prices, could face greater increases. 

The average U.S. household paid around 17 cents per kilowatt-hour of electricity in March 2025. However, this varied from a low of around 11 cents per kWh in North Dakota to around 41 cents per kWh in Hawaii. Looking forward, prices for households in the Pacific region are expected to rise by as much as 26 percent from 2022 to 2025. By contrast, households in the West North Central region could see a price increase of 8 percent.

The forecast price increases will depend heavily on supply and demand. The U.S. demand for electricity is expected to grow significantly over the coming years, as several new energy-guzzling projects suck electricity from the grid. The boom in data centres across the U.S. – giant warehouses of computer servers and other IT equipment that are used to power advanced technologies, such as artificial intelligence (AI), are expected to drive up demand significantly over the coming decades. Some fear that the demand for electricity in the U.S. could soon outstrip supply, as utilities nationwide race to connect new clean energy projects to the grid. This is likely to lead to higher electricity prices over the coming years. 

The growth in U.S. electricity demand was minimal in previous decades, thanks to improvements in energy efficiency. However, the demand for electricity to power data centres tripled between 2013 and 2023, driving the overall demand up at a fast rate, according to the U.S. Department of Energy. Electricity use by data centres is expected to double or triple again by 2028 and then continue growing. Data centres are therefore set to consume as much as 12 percent of the total U.S. electricity demand, a significant increase from 4.4. percent in 2023. By the end of the decade, data centres will likely be consuming greater quantities of electricity than the manufacture of all energy-intensive goods combined, including aluminium, steel, cement, and chemicals. 

In addition, the shift away from fossil fuels to cleaner alternatives, such as renewable energy sources and nuclear power, will lead to the greater electrification of households. Similarly, the anticipated increase in the uptake of electric vehicles will drive up the demand for electricity countrywide. 

One move that could help alleviate the price pressure is the modernisation of the U.S. grid. Most U.S. electricity transmission infrastructure is outdated and not prepared for the influx of renewable energy waiting to be connected. Making the grid system more efficient in delivering power, as well as investing in utility-scale battery storage, could help drive down prices. However, to achieve this, utilities across the country must invest heavily in infrastructure, which will likely lead to a mid-term price hike. 

In June, several media sources reported that, if passed, a Domestic Policy Bill sponsored by Trump may derail several renewable energy sectors and drive up consumer prices. The bill was expected to abruptly end many of the Biden-era federal tax credits for low-carbon sources of electricity such as wind, solar, batteries, and geothermal power. After some amendments, the bill just passed the Senate. It will now be sent back to the House for approval in its updated version, but it could mean a halt in progress for U.S. green energy and may result in higher energy prices for consumers in the coming years, spelling greater uncertainty for the future of the U.S. energy supply.

By Felicity Bradstock for Oilprice.com

 

Offshore Power Agreements Delayed Citing Uncertainties in US Policy

offshore wind farm
While work continues at Vineyard Wind and Revolution Wind, agreements for the next two farms are delayed by uncertainties (Vineyard Wind)

Published Jul 2, 2025 5:57 PM by The Maritime Executive

 


For the fourth time in a year, power purchase agreements that were due to be signed for offshore wind farms to serve Massachusetts and Rhode Island have been postponed. While the states remain anxious to pursue clean energy, the developers cite the continuing uncertainties in U.S. policy and, for the first time, raised the possibility of canceling agreements in their most recent filing.

Massachusetts selected nearly 2.7 GW of offshore power in the 2024 solicitation across three projects. A first-of-its-kind agreement called for Rhode Island to take 200 MW sharing the South Coast Wind project between the two states.

Originally, it was anticipated that the power purchase agreements between the wind farm developers and the state’s utilities would be completed in August 2024 and then submitted to the state’s public utility regulators for final approval. Citing uncertainties and market conditions, the deadline was pushed to November, and after the election of Donald Trump again delayed till January. In March, the two states agreed that the deadline would be moved to June 30.

Creating much of the uncertainty is an Executive Order signed by Donald Trump on January 20, putting leasing under review and pausing further activities. Five months later, there is no progress or word on when the ordered review might be concluded. The administration also briefly this spring stopped work on the Empire Wind project in New York and withdrew an EPA approval related to the construction of a proposed New Jersey offshore wind farm.

Trump has continued to speak out against what he calls “windmills,” contending incorrectly in a recent interview that they are all built in China. While Chinese companies have developed wind turbines, no American or European project has so far agreed to use them for their power generation. The new “big beautiful bill” for funding the U.S. government also contains provisions that, if passed, would impact tax credits for renewable energy.

“Without clarity on when or how issues arising under the Presidential Memorandum will be resolved, it may be impossible for parties to execute the PPAs,” Michael Brown, CEO of Ocean Winds, warned in the most recent filing.

Ocean Winds is the developer for South Coast Wind, a project which would be located over 30 miles south of Martha’s Vineyard and 20 miles south of Nantucket, and providing a total of 1,287 MW between Massachusetts and Rhode Island. While it has gained state approvals, it needs three additional federal approvals before construction can begin.

New England Wind, which is to be developed by Iberdrola’s Avangrid, however, is fully permitted at the state and federal levels. It would be located roughly 30 miles south of Barnstable, Massachusetts, and have a capacity for 791 MW.

Massachusetts had pushed back the deadline for the power agreements now targeting December 31 to finish negotiations. They would then be required to file with the state’s regulator by February 25, 2026.

Similarly, Rhode Island has set a new deadline of November 1 for the negotiations to be completed. This came less than a month before hearings were scheduled for the cable routing for the power supply.

South Coast Wind highlights that it has invested more than $600 million during the past seven years. This was for the permitting, engineering, and other preparations, but it and Rhode Island’s power utility warn if the uncertainties can not be resolved and agreements reached, Ocean Winds is prepared to delay indefinitely or walk away from its selection by Massachusetts and Rhode Island.

In the spring, 17 states and jurisdictions filed a lawsuit against the Trump administration regarding the indefinite pause in permitting for offshore wind projects. A District Court in Massachusetts has scheduled a September hearing on the suit.

In the interim, Vineyard Wind, which has been badly delayed by problems with its turbine blades, continues its construction process, which also involves surveying and replacing problems on the approximately 20 turbines installed before a blade broke last year. It will provide power to Massachusetts. In addition, Ørsted’s Revolution Wind is quietly progressing with its construction. This project will be shared between Rhode Island and Connecticut.

Plans for additional renewable energy solicitations by the states asl remain stalled waiting for resolution from the federal government. One proposal said they could continue to review projects quarterly or else wait till 2029 when Donald Trump is due to leave office.

 

Australia’s Offshore Wind Plans in Limbo as Equinor Leaves Project

Norwegian energy major Equinor has walked away from a third offshore wind development project in Australia in another blow to the federal government’s plan to build an offshore wind industry.

Earlier this year, Equinor quietly walked away from the Bass Offshore Wind Energy project near the coast of Tasmania, as the oil and gas giant reduced its investments in renewables to boost returns for shareholders and adapt to an “uneven energy transition.”

In a short statement to Australia’s Financial Review, Equinor and its partner in BOWE, Australian firm Nexsphere, confirmed on Wednesday the end of their collaboration on the project.

“Equinor and Nexsphere have made the decision not to proceed together with the Bass Offshore Wind Energy project (BOWE) in Tasmania,” the companies said.

Nexsphere continues to pursue the project, which aims to have between 70 and 100 offshore wind turbines installed, capable of generating up to 1,500 megawatts (MW) of renewable energy, which would be enough to power 325,000 homes in the area.

Nexsphere said in a separate statement to the Financial Review that the project is now “100 per cent Australian-owned” and that the company would “work with major international offshore wind partners make the proposal a reality.”

In the latest window in April, BOWE did not obtain a feasibility license—the first required permit for offshore infrastructure in Australia in which the holder has to assess the feasibility of a potential commercial offshore renewable energy project. But Nexsphere is “progressing” an application with the federal government, the company told the Financial Review.

Setbacks in the offshore wind sector are not unique to Australia.

The global offshore wind industry continues to face significant headwinds relating to supply chain, regulatory, and macroeconomic developments. 

Orsted, the world’s biggest offshore wind project developer, in May warned of a continued challenging environment for the industry. 

Due to higher costs and interest rates, the company announced it had decided to discontinue the development of the Hornsea 4 offshore wind project in the UK. 

By Tsvetana Paraskova for Oilprice.com

 

Australia's $6 Trillion Iron Ore Discovery Set to Transform Global Markets

  • A recent discovery of a 55 billion metric ton iron ore reserve in Western Australia's Hamersley region, valued at US $6 trillion, is expected to significantly impact global iron ore markets and prices.

  • A new joint venture mine between China Baowu Steel Group and Rio Tinto has opened in the Paraburdoo mining hub, adding to Australia's iron ore production capacity.

  • These new discoveries and investments are predicted to shift global supply chains, potentially lowering iron ore prices and solidifying Australia's role as a leading supplier, while China is likely to remain a key partner despite efforts for self-reliance.

An abundance of high-quality iron ore and the recent discovery of a 55 billion metric ton reserve have pushed Western Australia into the top spot as the world’s leading iron ore supplier. Now, many are wondering what effects this might have on the country’s export markets as well as global iron ore prices.

Iron Ore Prices: A $6 Trillion Discovery

The newly identified reserve in the Hamersley region is valued at around US $6 trillion and has significantly shaken up the global sector. Experts now expect a surge in investment from major steel-producing nations eager for access to this critical resource. That’s good news for Western Australia, as it means major infrastructure expansion, including new mining operations, transport systems and upgraded port facilities. The state’s ore boasts over 60% iron content, which makes it ideal for industrial use.

China, the world’s largest steel producer, currently imports more than 65% of its iron ore from Australia. The discovery of this new reserve could stabilize long-term iron ore prices and reduce China’s reliance on smaller suppliers.

New Mining Facility Opens in Paraburdoo

And there’s more. Over the weekend, a new mine also launched in the Hamersley region, backed by heavy investments from both Australia and China. The project is a joint venture between China Baowu Steel Group (46%) and Rio Tinto (54%), and will boast an initial capacity of 25 million metric tons following the initial US $2 billion investment. Experts believe it could operate for the next two decades.

Related: U.S. Natural Gas Giants Eye New Appalachia Pipelines

Located in the Paraburdoo mining hub in Pilbara, the new mine sits in one of Australia’s richest iron ore deposits. The Global Times quoted Western Australian Premier Roger Cook as saying that the mine’s opening represented a “significant achievement” and a major boost to the state’s economy. He also emphasized that the project highlights strong trade relationships with key foreign partners. Rio Tinto plans to invest over US $13 billion in Pilbara from 2025 to 2027.

New Discoveries Likely to Lower Iron Ore Prices

As a result of these new discoveries and ongoing investments, analysts now predict a shift in global supply chains. Countries seeking to diversify may lean more on Australia, moving away from Brazil or African sources. Increased exports from Western Australia could also drive down global iron ore prices. This will benefit sectors like construction and automotive, while cementing Australia’s role as a global leader.

As MetalMiner previously reported, iron ore has long driven Australia’s economic growth. Since 2005, national revenue from iron ore has skyrocketed from US $5.2 billion (A$8 billion) to US $80.7 billion (A$124 billion). Still, with many industries shifting toward greener tech, Australia must upgrade its mining and refining practices to meet rising demand for sustainable, high-grade ore.

China Will Likely Remain Heavily Reliant on Australia

Throughout all of this, China has remained a key partner, importing the bulk of its ore from Australia. Brazil ranks second, supplying around 18%. Tensions flared a few years ago when China froze economic talks with Australia, citing its growing ties with Western powers, especially the U.S. But China couldn’t afford to lose access to Australian ore, and relations have since stabilized. In the long term, China aims to become more self-reliant by tapping its own large iron ore reserves, though its ore is of much lower quality than Australia’s.

By Sohrab Darabshaw