CSA receives EPA ENERGY STAR recognition

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CSA International, a leading testing and certification organization, today announced that it has received recognition by the Environmental Protection Agency EPA as a Certification Body under the enhanced ENERGY STAR program and is doubling its capacity to accommodate the increased demand for energy efficiency qualification and verification services.

This recognition by the EPA establishes CSA International as an independent third-party eligible to certify products to the ENERGY STAR requirements.

“As a leading provider of energy efficiency verification services for more than 32 years in Canada, this recognition allows CSA International to expand its services in the U.S. and globally to enable our customers in obtaining the highly-respected ENERGY STAR mark for their products,” says Terry Drew, director, energy efficiency and sustainability, CSA International.

Under this recognition, CSA International is able to qualify and verify that products meet ENERGY STAR requirements by testing them in its EPA recognized laboratories, by witness or supervised testing at manufacturersÂ’ labs, or by verifying testing data from other EPA recognized independent third-party laboratories. As a Certification Body, CSA International will confirm a manufacturerÂ’s compliance with ENERGY STAR requirements and upload the data required for EPA to authorize the use of the ENERGY STAR mark by a specific manufacturer for a specific product.

The EPA recognition covers a broad range of products including: home appliances heating, ventilating and air conditioning equipment consumer electronics information technology lighting and commercial food service equipment. In addition to being recognized as an ENERGY STAR Certification Body, CSA International is also working to ensure that its facilities in Toronto, Cleveland, Vancouver and Irvine, CA are recognized for testing to ENERGY STAR requirements. CSAÂ’s Atlanta Laboratory received accreditation in September 2010.

In November 2009, the EPA announced that the ENERGY STAR program was to require third-party testing of all eligible products starting in 2011. Previously, the program allowed companies to self-declare their compliance with ENERGY STAR requirements. ENERGY STAR was launched in 1992 and has set efficiency levels that are 10 to 25 per cent higher than basic regulatory compliance.

Recognition by EPA applies only to the energy efficiency requirements of the ENERGY STAR program. For certification to applicable standards, CSA International is accredited as a Nationally Recognized Testing Laboratory in the U.S. and an Accredited Certification Organization by Standards Council of Canada.

With these combined accreditations, CSA will now offer clients a single source for testing, certification and energy verification services for both Canada and the U.S.

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Trump unveils landmark rewrite of NEPA rules

Trump NEPA Overhaul streamlines environmental reviews, tightening 'reasonably foreseeable' effects, curbing cumulative impacts, codifying CEQ greenhouse gas guidance, expediting permits for pipelines, highways, and wind projects with two-year EIS limits and one lead agency.

 

Key Points

Trump NEPA Overhaul streamlines reviews, trims cumulative impacts, keeps GHG analysis for foreseeable effects.

✅ Limits cumulative and indirect impacts; emphasizes foreseeable effects

✅ Caps EIS at two years; one-year environmental assessments

✅ One lead agency; narrower NEPA triggers for low federal funding

 

President Trump has announced plans for overhauling rules surrounding the nation’s bedrock environmental law, and administration officials refuted claims they were downplaying greenhouse gas emissions, as the administration also pursues replacement power plant rules in related areas.

The president, during remarks at the White House with supporters and Cabinet officials, said he wanted to fix the nation’s “regulatory nightmare” through new guidelines for implementing the National Environmental Policy Act.

“America is a nation of builders,” he said. But it takes too long to get a permit, and that’s “big government at its absolute worst.”

The president said, “We’re maintaining America’s world-class standards of environmental protection.” He added, “We’re going to have very strong regulation, but it’s going to go very quickly.”

NEPA says the federal government must consider alternatives to major projects like oil pipelines, highways and bridges that could inflict environmental harm. The law also gives communities input.

The Council on Environmental Quality has not updated the implementing rules in decades, and both energy companies and environmentalists want them reworked, even as some industry groups warned against rushing electricity pricing changes under related policy debates.

But they patently disagree on how to change the rules.

A central fight surrounds whether the government considers climate change concerns when analyzing a project.

Environmentalists want agencies to look more at “cumulative” or “indirect” impacts of projects. The Trump plan shuts the door on that.

“Analysis of cumulative effects is not required,” the plan states, adding that CEQ “proposes to make amendments to simplify the definition of effects by consolidating the definition into a single paragraph.”

CEQ Chairwoman Mary Neumayr told reporters during a conference call that definitions in the current rules were the “subject of confusion.”

The proposed changes, she said, do in fact eliminate the terms “cumulative” and “indirect,” in favor of more simplified language.

Effects must be “reasonably foreseeable” and require a “reasonably close causal relationship” to the proposed action, she added. “It does not exclude considerations of greenhouse gas emissions,” she said, pointing to parallel EPA proposals for new pollution limits on coal and gas power plants as context.

Last summer, CEQ issued proposed guidance on greenhouse gas reviews in project permitting. The nonbinding document gave agencies broad authority when considering emissions (Greenwire, June 21, 2019).

Environmentalists scoffed and said the proposed guidance failed to incorporate the latest climate science and look at how projects could be more resilient in the face of severe weather and sea-level rise.

The proposed NEPA rules released today include provisions to codify the proposed guidance, which has also been years in the making.

Other provisions

Senior administration officials sought to downplay the effect of the proposed NEPA rules by noting the underlying statute will remain the same.

“If it required NEPA yesterday, it will require NEPA under the new proposal,” an official said when asked how the changes might apply to pipelines like Keystone XL.

And yet the proposed changes could alter the “threshold consideration” that triggers NEPA review. The proposal would exclude projects with minimal federal funding or “participation.”

The Trump plan also proposes restricting an environmental impact statement to two years and an environmental assessment to one.

Neumayr said the average EIS takes 4 ½ years and in some cases longer. Democrats have disputed those timelines. Further, just 1% of all federal actions require an EIS, they argue.

The proposal would also require one agency to take the lead on permitting and require agency officials to “timely resolve disputes that may result in delays.”

In general, the plan calls for environmental documents to be “concise” and “serve their purpose of informing decision makers.”

Both Interior Secretary David Bernhardt and EPA Administrator Andrew Wheeler, whose agency moved to rewrite coal power plant wastewater limits in separate actions, were at the White House for the announcement.

Reaction

An onslaught of critics have said changes to NEPA rules could be the administration’s most far-reaching environmental rollback, and state attorneys general have mounted a legal challenge to related energy actions as well.

The League of Conservation Voters declared the administration was again trying to “sell out the health and well-being of our children and families to corporate polluters.”

On Capitol Hill, House Speaker Nancy Pelosi (D-Calif.) said during a news conference the administration would “no longer enforce NEPA.”

“This means more polluters will be right there, next to the water supply of our children,” she said. “That’s a public health issue. Their denial of climate, they are going to not use the climate issue as anything to do with environmental decisionmaking.”

Sen. Sheldon Whitehouse (D-R.I.) echoed the sentiment, saying he didn’t need any more proof that the fossil fuel industry had hardwired the Trump administration “but we got it anyway.”

Energy companies, including firms focused on renewable energy development, are welcoming the “clarity” of the proposed NEPA rules, even as debates continue over a clean electricity standard in federal climate policy.

“The lack of clarity in the existing NEPA regulations has led courts to fill the gaps, spurring costly litigation across the sector, and has led to unclear expectations, which has caused significant and unnecessary delays for infrastructure projects across the country,” the Interstate Natural Gas Association of America said in a statement.

Last night, the American Wind Energy Association said NEPA rules have caused “unreasonable and unnecessary costs and long project delays” for land-based and offshore wind energy and transmission development.

Trump has famously attacked the wind energy industry for decades, dating back to his opposition to a Scottish wind turbine near his golf course.

The president today said he won’t stop until “gleaming new infrastructure has made America the envy of the world again.”

When asked whether he thought climate change was a “hoax,” as he once tweeted, he said no. “Nothing’s a hoax about that,” he said.

The president said there’s a book about climate he’s planning to read. He said, “It’s a very serious subject.”

 

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Should California classify nuclear power as renewable?

California Nuclear Renewable Bill AB 2898 seeks to add nuclear to the Renewables Portfolio Standard, impacting Diablo Canyon, PG&E compliance, carbon-free targets, and potential license extensions while addressing climate goals and natural gas reliance.

 

Key Points

A bill to add nuclear to California's RPS, influencing Diablo Canyon, PG&E planning, and carbon-free climate targets.

✅ Reclassifies nuclear as renewable in California's RPS.

✅ Could influence Diablo Canyon license extension and ownership.

✅ Targets carbon-free goals while limiting natural gas reliance.

 

Although he admits it's a long shot, a member of the California Legislature from the district that includes the Diablo Canyon nuclear plant has introduced a bill that would add nuclear power to the state's list of renewable energy sources.

"I think that nuclear power is an important component of generating large-scale electricity that's good for the environment," said Jordan Cunningham, R-San Luis Obispo. "Without nuclear as part of the renewable portfolio, we're going to have tremendous difficulty meeting the state's climate goals without a significant cost increase on electricity ratepayers."

Established in 2002, California's Renewables Portfolio Standard spells out the power sources eligible to count toward the state's goals to wean itself of fossil fuels. The list includes solar, wind, biomass, geothermal, small hydroelectric facilities and even tidal currents. The standard has been updated, currently calling for 60 percent of California's electricity to come from renewables by 2030 and 100 percent from carbon-free sources by 2045, even as some analyses argue net-zero emissions may be difficult to achieve without nuclear power.

Nuclear power is not part of the portfolio standard and Diablo Canyon — the only remaining nuclear plant in California — is scheduled to stop producing electricity by 2025, even as some Southern California plant closures face postponement to maintain grid reliability.

Pacific Gas & Electric, the operators of Diablo Canyon, announced in 2016 an agreement with a collection of environmental and labor groups to shut down the plant, often framed as part of a just transition for workers and communities. PG&E said Diablo will become uneconomical to run due to changes in California's power grid — such as growth of renewable energy sources, increased energy efficiency measures and the migration of customers from traditional utilities to community choice energy programs.

But Cunningham thinks the passage of Assembly Bill 2898, which he introduced last week, — as innovators like Bill Gates' mini-reactor venture tout new designs — could give the plant literally a new lease on life.

"If PG&E were able to count the power produced (at Diablo) toward its renewable goals, it might — I'm not saying it will or would, but it might — cause them to reconsider applying to extend the operating license at Diablo," Cunningham said.

Passing the bill, supporters say, could also make Diablo Canyon attractive to an outside investor to purchase and then apply to the Nuclear Regulatory Commission for a license extension.

But nuclear power has long generated opposition in California and AB 2898 will face long odds in Sacramento, and similar efforts elsewhere have drawn opposition from power producers as well. The Legislature is dominated by Democrats, who have expressed more interest in further developing wind and solar energy projects than offering a lifeline to nuclear.

And if the bill managed to generate momentum, anti-nuclear groups will certainly be quick to mobilize, reflecting a national energy debate over Three Mile Island and whether to save struggling plants.

When told of Cunningham's bill, David Weisman, outreach coordinator for the Alliance for Nuclear Responsibility, said flatly, "Diablo Canyon has become a burdensome, costly nuclear white elephant."

Critics say nuclear power by definition cannot be considered renewable because it leaves behind waste in the form of spent nuclear fuel that then has to be stored, while supporters point to next-gen nuclear designs that aim to improve safety and costs. The federal government has not found a site to deposit the waste that has built up over decades from commercial nuclear power plants.

Even though Diablo Canyon is the only nuclear plant left in the Golden State, it accounts for 9 percent of California's power mix. Cunningham says if the plant closes, the state's reliance on natural gas — a fossil fuel — will increase, pointing to what happened when the San Onofre Nuclear Generating Station closed.

In 2011, the final full year operations for San Onofre, nuclear accounted for 18.2 percent of in-state generation and natural gas made up 45.4 percent. The following year, nuclear dropped to 9.3 percent and gas shot up to 61.1 percent of in-state generation.

"If we're going to get serious about being a national leader as California has been on dealing with climate change, I think nuclear is part of the answer," Cunningham said.

But judging from the response to an email from the Union-Tribune, PG&E isn't exactly embracing Cunningham's bill.

"We remain focused on safely and reliably operating Diablo Canyon Power Plant until the end of its current operating licenses and planning for a successful decommissioning," said Suzanne Hosn, a PG&E senior manager at Diablo Canyon. "The Assemblyman's proposal does not change any of PG&E's plans for the plant."

Cunningham concedes AB 2898 is "a Hail Mary pass" but said "it's an important conversation that needs to be had."

The second-term assemblyman introduced a similar measure late last year that sought to have the Legislature bring the question before voters as an amendment to the state constitution. But the legislation, which would require a two-thirds majority vote in the Assembly and the Senate, is still waiting for a committee assignment.

AB 2898, on the other hand, requires a simple majority to move through the Legislature. Cunningham said he hopes the bill will receive a committee assignment by the end of next month.
 

 

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Texas lawmakers propose electricity market bailout after winter storm

Texas Electricity Market Bailout proposes securitization bonds and ERCOT-backed fees after Winter Storm Uri, spreading costs via ratepayer charges on power bills to stabilize generators, co-ops, and retailers and avert bankruptcies and investor flight.

 

Key Points

State plan to securitize storm debts via ERCOT fees, adding bill charges to stabilize Texas power firms.

✅ Securitization bonds finance unpaid ancillary services and energy costs

✅ ERCOT fee spreads Winter Storm Uri debts across ratepayers statewide

✅ Aims to prevent bankruptcies, preserve grid reliability, reassure investors

 

An approximately $2.5 billion plan to bail out Texas’ distressed electricity market from the financial crisis caused by Winter Storm Uri in February has been approved by the Texas House.

The legislation would impose a fee — likely for the next decade or longer — on electricity companies, which would then get passed on to residential and business customers in their power bills, even as some utilities waived certain fees earlier in the crisis.

House lawmakers sent House Bill 4492 to the Senate on Thursday after a 129-15 vote. A similar bill is advancing in the Senate.

Some of the state’s electricity providers and generators are financially underwater in the aftermath of the February power outages, which left millions without power and killed more than 100 people. Electricity companies had to buy whatever power was available at the maximum rate allowed by Texas regulations — $9,000 per megawatt hour — during the week of the storm (the average price for power in 2020 was $22 per megawatt hour). Natural gas fuel prices also spiked more than 700% during the storm.

Several companies are nearing default on their bills to the Electric Reliability Council of Texas, which manages the Texas power grid that covers most of the state and facilitates financial transactions in it.

Rural electric cooperatives were especially hard hit; Brazos Electric Power Cooperative, which supplies electricity to 1.5 million customers, filed for bankruptcy citing a $1.8 billion debt to ERCOT.

State Rep. Chris Paddie, R-Marshall, the bill’s author, said a second bailout bill will be necessary during the current legislative session for severely distressed electric cooperatives.

“This is a financial crisis, and it’s a big one,” James Schaefer, a senior managing director at Guggenheim Partners, an investment bank, told lawmakers at a House State Affairs Committee hearing in early April. He warned that more bankruptcies would cause higher costs to customers and hurt the state’s image in the eyes of investors.

“You’ve got to free the system,” Schaefer said. “It’s horrible that a bunch of folks have to pay, but it’s a system-wide failure. If you let a bunch of folks crash, it’s not a good look for your state.”

If approved by the Senate and Gov. Greg Abbott, a newly-created Texas Electric Securitization Corp. would use the money raised from the fees for bonds to help pay the companies’ debts, including costs for ancillary services, a financial product that helps ensure power is continuously generated and improve electricity reliability across the grid.

Paddie told his colleagues Wednesday that he could not yet estimate how long the new fee would be imposed, but during committee hearings lawmakers estimated it’s likely to be at least a decade. Several other bills to spread out the costs of the winter storm and consider market reforms are also moving through the Legislature.

ERCOT’s independent market monitor recommended in March that energy sold during that period be repriced at a lower rate, which would have allowed ERCOT to claw back about $4.2 billion in payments to power generators, but the Public Utility Commission declined to do so, even as a court ruling on plant obligations in emergencies drew scrutiny among market participants.

Instead, lawmakers are pushing for bailouts that several energy experts have said is needed, both to ensure distressed companies don’t pass enormous costs on to their customers and to prevent electricity investors and companies from leaving the state if it’s viewed as too risky to continue doing business.

Becky Klein, an energy consultant in Austin and former chair of the Public Utility Commission who played a key role in de-regulating Texas’ electricity market two decades ago, said during a retail electricity panel hosted by Integrate that legislation is necessary to provide “some kind of backstop during a crazy market crisis like this to show the financial market that we’re willing to provide some relief.”

Still, some lawmakers are concerned with how they will win public support, including potential voter-approved funding measures, for bills to bail out the state’s electricity market.

“I have to go back to Laredo and say, ‘I know you didn’t have electricity for several days, but now I’m going to make you pay a little more for the next 20 years,’” state Rep. Richard Peña Raymond, D-Laredo, said during an early April discussion on the plan in the House State Affairs Committee. He said he voted for the bill because it’s in the best interest of the state.

Paddie, during the same committee hearing, acknowledged that “none of us want to increase fees or taxes.” However, he said, “We have to deal with the reality set before us.”

 

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UK families living close to nuclear power stations could get free electricity

UK Nuclear Free Electricity Incentive proposes community benefits near reactors, echoing France, supporting net zero goals, energy security, and streamlined planning, while addressing regulation and judicial review challenges for Sizewell C and future nuclear projects.

 

Key Points

A proposed policy to give free power to residents near reactors, supporting net zero and energy security.

✅ Free power for communities near nuclear plants

✅ Aligns with net zero and energy security goals

✅ Seeks streamlined planning and fewer approvals

 

UK Business Secretary Jacob Rees-Mogg has endorsed a French-style nuclear system that sees people living near nuclear power stations receive free electricity.

Speaking at an event organised by Policy Exchange think tank, Jacob Rees-Mogg said: “Nuclear power is just fundamental. There’s no way we can get to net zero emissions, or even have an intelligent electricity strategy and grid reform in the UK, without nuclear.”

Highlighting that this was his view and not a government policy announcement, he said: “We should copy the French. As I understand, if you live near a nuclear power station in France, you get free electricity and that’s great because then, I’ll have two in my garden if I get free electricity for my children as well.

“I think you want to recognise that things you do that are in the national interest, such as a state-owned generation company, must benefit those who make the sacrifice for the national interest.”

Earlier Mr Rees-Mogg stressed that he would like to see a simpler development consent process for new nuclear power plants to enable the next waves of reactors in the UK, amid concerns that Europe is losing nuclear power just when it really needs energy.

He said: “That’s a lot of regulation around that, as seen when nuclear plant plans collapsed in Wales and impacted the local economy. Did you know that Sizewell C will require 140 individual approvals from arms of the state, each one of which is potentially subject to judicial review.”

 

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European responses to Covid-19 accelerate electricity system transition by a decade - Wartsila

EU-UK Coal Power Decline 2020 underscores Covid-19's impact on power generation, with renewables rising, carbon emissions falling, and electricity demand down, revealing resilient grids and accelerating the energy transition across European markets.

 

Key Points

Covid-19's impact on EU-UK power: coal down, renewables up, lower emissions intensity and reduced electricity demand.

✅ Coal generation down 25.5% EU-UK; 29% in March 10-April 10 period

✅ Renewables share up to 46%; grids remained stable and flexible

✅ Electricity demand fell 10%; emissions intensity dropped 19.5%

 

Coal based power generation has fallen by over a quarter (25.5%) across the European Union (EU) and United Kingdom (UK) in the first three months of 2020, compared to 2019, as a result of the response to Covid-19, with renewable energy reaching a 43% share, as wind and solar outpaced gas across the EU, according to new analysis by the technology group Wärtsilä.

The impact is even more stark in the last month, with coal generation collapsing by almost one third (29%) between March 10 and April 10 compared to the same period in 2019, making up only 12% of total EU and UK generation. By contrast, renewables delivered almost half (46%) of generation – an increase of 8% compared to 2019.

In total, demand for electricity across the continent is down by one tenth (10%), mirroring global demand declines of around 15%, due to measures taken to combat Covid-19, the biggest drop in demand since the Second World War. The result is an unprecedented fall in carbon emissions from the power sector, with emission intensity falling by 19.5% compared to the same March 10-April 10 period last year. The analysis comes from the Wärtsilä Energy Transition Lab, a new free-to-use data platform developed by Wärtsilä to help the industry, policy makers and the public understand the impact of Covid-19 on European electricity markets and analyse what this means for the future design and operation of its energy systems. The goal is to help accelerate the transition to 100% renewables.

Björn Ullbro, Vice President for Europe & Africa at Wärtsilä Energy Business, said: “The impact of the Covid-19 crisis on European energy systems is extraordinary. We are seeing levels of renewable electricity that some people believed would cause systems to collapse, yet they haven’t – in fact they are coping well. The question is, what does this mean for the future?”

“What we can see today is how our energy systems cope with much more renewable power – knowledge that will be invaluable, aligning with IAEA low-carbon insights, to accelerate the energy transition. We are making this new platform freely available to support the energy industry to adapt and use the momentum this tragic crisis has created to deliver a better, cleaner energy system, faster.”

The figures mark a dramatic shift in Europe’s energy mix – one that was not anticipated to occur until the end of the decade. The impact of the Covid-19 crisis has effectively accelerated the energy transition in the short-term, even as later lockdowns saw power demand hold firm in parts of Europe, providing a unique opportunity to see how energy systems function with far higher levels of renewables.

Ullbro added: “Electricity demand across Europe has fallen due to the lockdown measures applied by governments to stop the spread of the coronavirus. However, total renewable generation has remained at pre-crisis levels with low electricity prices, combined with renewables-friendly policy measures, crowding out gas and fossil fuel power generation, especially coal. This sets the scene for the next decade of the energy transition.”

These Europe-wide impacts are mirrored at a national level, for example:

  • In the UK, renewables now have a 43% share of generation, following a stall in low-carbon progress in 2019 (up 10% on the same March 10-April 10 period in 2019) with coal power down 35% and gas down 24%.
  • Germany has seen the share of renewables reach 60% (up 12%) and coal generation fall 44%, resulting in a fall in the carbon intensity of its electricity of over 30%.
  • Spain currently has 49% renewables with coal power down by 41%.
  • Italy has seen the steepest fall in demand, down 21% so far.

An industry first, the Wärtsilä Energy Transition Lab has been specifically developed as an open-data platform for the energy industry to understand the impact of Covid-19 and help accelerate the energy transition. The tool provides detailed data on electricity generation, demand and pricing for all 27 EU countries and the UK, combining Entso-E data in a single, easy to use platform. It will also allow users to model how systems could operate in future with higher renewables, as global power demand surpasses pre-pandemic levels, helping pinpoint problem areas and highlight where to focus policy and investment.

 

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Egypt, Eni ink MoU on hydrogen production projects

Egypt-ENI Hydrogen MoU outlines joint feasibility studies for green and blue hydrogen using renewable energy, carbon capture, and CO2 storage, targeting domestic demand, exports, and net-zero goals within Egypt's energy transition.

 

Key Points

A pact to study green and blue hydrogen in Egypt, leveraging renewables, CO2 storage, and export/demand pathways.

✅ Feasibility study for green and blue hydrogen projects

✅ Uses renewables, SMR, carbon capture, and CO2 storage

✅ Targets local demand, exports, and net-zero alignment

 

The Egyptian Electricity Holding Company (EEHC) and the Egyptian Natural Gas Holding Company (EGAS) signed a memorandum of understanding (MoU) with the Italian energy giant Eni to assess the technical and commercial feasibility of green and blue hydrogen production projects in Egypt, which many see as central to power companies' future strategies worldwide today.

Under the MoU, a study will be conducted to assess joint projects for the production of green hydrogen using electricity generated from renewable energy and supported by regional electricity interconnections where relevant, and blue hydrogen using the storage of CO2 in depleted natural gas fields, according to a statement by the Ministry of Petroleum on Thursday.

The study will also estimate the potential local market consumption of hydrogen and export opportunities, taking cues from Ontario's hydrogen economy proposal to align electricity rates for growth.

This agreement is part of Eni's objective to achieve zero net emissions by 2050 and Egypt's strategy towards diversifying the energy mix and developing hydrogen projects in collaboration with major international companies, taking note of Italy's green hydrogen initiatives in Sicily as a comparable effort.

It signed the deal with Egyptian Natural Gas Holding (EGAS) and Egyptian Electricity Holding Co. (EEHC).

The companies will carry out a joint study on producing renewable energy powered green hydrogen, informed by electrolyzer investments in similar projects, where applicable. They will also work on blue hydrogen. This involves reforming natural gas and capturing the resulting CO2, in this instance in depleted natural gas fields.

The study will also consider domestic hydrogen use and export options, including funding models like the Hydrogen Innovation Fund now in Ontario.

Eni said the MoU was in line with its plans to eliminate net emissions and emissions cancel emission intensity by 2050. The company noted the agreement was in line with Egypt’s plan for the energy transition, in which it pursues hydrogen plans with major international companies, alongside broader clean-tech collaboration such as Tesla cooperation discussions in Dubai, to accelerate progress.

 

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