Lawmakers in Vermont are gearing up for a mileage-based EV tax. There are better ways to raise funds for roads and infrastructure.
Mileage-based EV tax
Vermont as a state is pro-EV – it’s actively incentivizing more environmentally-friendly transportation options through Drive Electric Vermont. The state is busy installing EV chargers, and its first Tesla center was unanimously approved by the city council in South Burlington in December.
However, the state estimates that it will miss out on about $1 million in revenue in 2023 due to the uptake of EVs and hybrids, according to the VT Digger, as the gas tax helps fund road maintenance and improvements.
So Vermont state legislators are now considering a bill, H.479, that proposes a mileage-based tax for electric vehicle owners to make up for this lost revenue. The tax would be based on the number of miles driven by the vehicle rather than the amount of gasoline used.
This proposal was passed in the House on March 30, read for the first time in the Senate, and referred to the Committee on Transportation.
Lawmakers are roughly aiming for July 2025 to launch a mileage-based EV tax because that’s when the state aims for 15% of all new vehicles to be fully electric or plug-in hybrids.
Electrek’s Take
Is this really the best way to skin the cat? We don’t think so.
How do you separate out miles driven out of state versus in-state? For example, I live on the New Hampshire/Vermont border on the Vermont side. My husband drives an EV to New Hampshire every day to go to work. People cross borders in these small states all the time. How do you accurately measure the number of miles driven in-state to ensure that EV owners are not unfairly burdened by the tax? And a tracking device is not going to be popular.
Mileage-based taxes could also disproportionately impact low-income drivers, as they may not have the means to pay a large fee based on the number of miles they drive, which could create an unfair burden. And people drive a lot here, for work or otherwise, due to the fact that it’s rural.
How about perhaps shifting the entire transportation fund away from gas and diesel and figuring out a better way to raise needed funds?
Why not calculate the taxes based on vehicle weight? According to a GAO study, an 80,000-pound 18-wheeler does 9,600 times more damage to roads than a 4,000-pound passenger vehicle. This can be completed when the vehicle is registered.
Eighty percent of EV owners charge their cars at home. People pay tax on their electric bills; why can’t the state tap into that extra tax income through the utilities?
The US has some of the lowest gas taxes in the world. As of February 2023, Vermont’s total state tax on gasoline was 33 cents a gallon and 32 cents for diesel, according to the US Energy Information Administration. How about raising the gas tax so that switching to an EV is further incentivized?
But the proponents of these EV fees wouldn’t advocate for that, because these fees are pushed by the fossil fuel industry. These laws were not conceived of to fix a shortfall in revenue, but rather to target a competitor to the fossil fuel industry. And they’ve spread to many states with this disingenuous motivation.
Of course, state roads and infrastructure need tax revenue for upkeep and improvements. Sierra Club Vermont calls the mileage-based fees idea “regressive,” and we agree. The EV mileage tax idea has too many holes, so it doesn’t feel like the right way to do it – in Vermont or anywhere else.
What do you think about mileage-based EV tax? Let us know in the comments below.
Photo: State of Vermont Agency of Commerce and Community Development
UnderstandSolar is a free service that links you to top-rated solar installers in your region for personalized solar estimates. Tesla now offers price matching, so it’s important to shop for the best quotes. Click here to learn more and get your quotes. — *ad.
FTC: We use income earning auto affiliate links.More.
A growing number of sizable companies, from mining giants to energy majors, are embracing the hype for natural hydrogen.
It comes as buzz continues to build over the potential for a resource that advocates say could radically reshape the global energy landscape.
Natural hydrogen, sometimes known as white, gold or geologic hydrogen, refers to hydrogen gas that is found in its natural form beneath Earth’s surface. The long-overlooked resource, first discovered by accident in Mali nearly 40 years ago, contains no carbon and produces only water when burned.
Investor interest in the nascent natural hydrogen sector has been intensifying in recent months, fueling optimism initially driven by research startups and junior exploration companies.
Over the past year or so, some of the sector’s established backers include mining giants Rio Tinto and Fortescue, Russia’s state-owned energy giant Gazprom, the venture capital arm of British oil giant BP and Bill Gates‘ clean tech investment fund Breakthrough Energy Ventures.
We can use it to make metals, make fuels, you could even make food, and all with far fewer emissions than conventional approaches.
Eric Toone
Chief technology officer at Breakthrough Energy
Exploratory efforts are currently underway in several countries across the globe, with Canada and the U.S. leading the way in terms of project counts over the last year, according to research published by consultancy Rystad Energy.
Analysts expect the year ahead to be a pivotal one, with industry players hoping their exploration campaigns can soon locate the elusive gas.
Not everyone’s convinced about the clean energy potential of natural hydrogen, however, with critics flagging environmental concerns and distribution challenges. For its part, the International Energy Agency has warned there is a possibility that the resource “is too scattered to be captured in a way that is economically viable.”
A global scramble for ‘white gold’
Minh Khoi Le, head of hydrogen research at Rystad Energy, said it’s difficult to predict whether natural hydrogen can live up to its promise in 2025.
“I guess last year was the year that things got really interesting for the natural hydrogen space because that’s when many companies started to plan drilling campaigns, extraction testing and we started to see some major players start to get involved as well,” Le told CNBC by video call.
“Since then, I would say the progress has been relatively slow. There are only a few companies that have actually started drilling,” he added.
Gauges that are part of the electrolysis plant of the geological hydrogen H2 storage facility.
Alex Halada | Afp | Getty Images
Rystad’s Le, who characterized the global pursuit of natural hydrogen as a “white gold rush” last year, said that while there’d been no major progress over the last 12 months, an upswing in investor interest could help to deliver some meaningful results.
“Now, we are starting to see companies getting investment, so they have money to fund their drilling campaigns. So, if we are to get an answer of whether this thing will work, we’ll get to that conclusion a bit faster this year,” Le said.
Hydrogen has long been billed as one of many potential energy sources that could play a key role in the energy transition, but most of it is produced using fossil fuels such as coal and natural gas, a process that generates significant greenhouse gas emissions.
Green hydrogen, a process that involves splitting water into hydrogen and oxygen using renewable electricity, is one exception to the hydrogen color rainbow. However, its development has been held back by soaring costs and a challenging economic environment.
Clean, homegrown energy
Australia’s HyTerra announced an investment of $21.9 million from Fortescue in August last year, noting that the proceeds would be used to fully fund expanded exploration projects.
A spokesperson for Fortescue, one of the leading green hydrogen developers, said its push into the natural hydrogen sector was in line with its “strategic commitment to exploring zero emissions fuels.”
Acknowledging that more work is required to fully assess natural hydrogen’s emissions profile, Fortescue’s spokesperson described the technology as a “promising opportunity” to accelerate industrial decarbonization.
A hydrogen-powered haul truck, right, at the Fortescue Metals Group Ltd. Christmas Creek mine in the Pilbara region of Western Australia, Australia, on Tuesday, Oct. 17, 2023.
Bloomberg | Bloomberg | Getty Images
Elsewhere, BP Ventures, the venture capital arm of BP, led a Series A funding round of U.K.-based natural hydrogen exploration startup Snowfox Discovery earlier this year, while France-based start-up Mantle8 recently received 3.4 million euros ($3.9 million) in seed funding from investors, including Breakthrough Energy Ventures, a climate and technology fund founded by Bill Gates in 2015.
Eric Toone, chief technology officer at Breakthrough Energy, said the fund had backed the likes of Mantle8 and U.S.-based startup Koloma because the promise of natural hydrogen is such that it “could unlock a new era of clean, homegrown energy.”
“Hydrogen is pure reactive chemical energy. If we have enough hydrogen and it’s cheap enough, we can do almost anything. We can use it to make metals, make fuels, you could even make food, and all with far fewer emissions than conventional approaches,” Toone told CNBC via email.
“We know it’s out there and not just in isolated pockets. Early exploration has identified natural hydrogen across six continents. The challenge now is figuring out how to extract it efficiently, move it safely, and build the systems to put it to work,” he added.
In search of the ‘eureka moment’
Aurian Durbuis, chief of staff at France’s Mantle8, said momentum certainly appears to be building from a venture capital perspective.
“There is a growing interest, indeed, especially given the dynamics with green hydrogen right now, unfortunately. People are turning their eyes to other solutions, which is in our favor,” Durbuis told CNBC by video call.
Taking the evolution of US shale-gas as an analogy, even if large finds are made, it will likely take decades to achieve industrial production.
Arnout Everts
Member of the Hydrogen Science Coalition
Based in Grenoble, in the foothills of the French Alps, Mantle8 is targeting the discovery of 10 million tons of natural hydrogen by 2030 to complement the European Union’s goals.
“The question is can we find producible reservoirs, in the oil and gas terminology. That’s really what we need to figure out as an industry,” Durbuis said.
“We think we can drill in 2028 and hopefully that is the eureka moment because if we can find something at that time, then it could obviously be a game changer. If we find highly concentrated hydrogen, with pressure, then this just changes everything,” he added.
What’s next for natural hydrogen?
The Hydrogen Science Coalition, a group of academics, scientists and engineers seeking to bring an evidence-based view to hydrogen’s role in the energy transition, said exploration for natural hydrogen is still at an “embryonic stage” — but even so, the likelihood of locating large finds of nearly pure hydrogen that can be extracted at scale look “relatively slim.”
The world’s only producing hydrogen well in Mali, for example, supplies “just a fraction of the daily energy output of a single wind turbine,” Arnout Everts, a geoscientist and member of the Hydrogen Science Coalition, told CNBC via email.
The team from the Geological Agency of the Ministry of Energy and Mineral Resources (ESDM) took samples of natural hydrogen gas found in One Pute Jaya Village, Morowali Regency, Central Sulawesi Province, Indonesia, 23 October 2023.
Nurphoto | Nurphoto | Getty Images
“Taking the evolution of US shale-gas as an analogy, even if large finds are made, it will likely take decades to achieve industrial production,” Everts said.
Ultimately, the Hydrogen Science Coalition said the pursuit of natural hydrogen risks distracting focus from the renewable hydrogen needed to decarbonize industries today.
On Inauguration Day, President Donald Trump issued an executive order indefinitely halting permits for new onshore wind energy projects on federal land, as well as new leases for offshore wind farms in U.S. coastal waters. The action not only fulfilled Trump’s “no new windmills” campaign pledge, but struck yet another blow to the wind industry, which has been hit hard over the past few years by supply chain snags, price increases upending project economics, public opposition and political backlash against federal tax credits, especially those spurring the fledgling offshore wind sector.
Nonetheless, the nation’s well-established onshore wind industry, built out over several decades, is generating nearly 11% of America’s electricity, making it the largest source of renewable energy and at times last year exceeding coal-fired generation. On April 8, the fossil-fuels-friendly Trump administration took measures to bolster coal mining and power plants, but as the infrastructure driving wind energy ages, efforts to “repower” it are creating new business opportunities for the industry’s key players.
This repowering activity has emerged as a bright spot for the wind industry, giving a much-needed boost to market leaders GE Vernova, Vestas and Siemens Gamesa, a subsidiary of Munich-based Siemens Energy. Following several challenging years of lackluster performance — due in particular to setbacks in both onshore and offshore projects — all three companies reported revenue increases in 2024, and both GE Vernova and Siemens stock have moved higher.
GE Vernova, spun off from General Electric a year ago, led overall onshore wind installations in 2024, with 56% of the U.S. market, followed by Denmark’s Vestas (40%) and Siemens Gamesa (4%).
Stock Chart IconStock chart icon
GE Vernova stock performance over the past one-year period.
According to the U.S. Energy Information Administration, installed wind power generating capacity grew from 2.4 gigawatts (GW) in 2000 to 150.1 GW as of April 2024. Although the growth rate for launching new greenfield onshore wind farms has slowed over the last 10 years, the U.S. is still poised to surpass 160 GW of wind capacity in 2025, according to a new report from energy research firm Wood Mackenzie.
There currently are about 1,500 onshore wind farms — on which more than 75,600 turbines are spinning — across 45 states, led by Texas, Iowa, Oklahoma, Illinois and Kansas. Virtually all of the wind farms are located on private land, and many of the largest ones are owned and operated by major energy companies, including NextEra Energy, RWE Clean Energy, Pattern Energy, Clearway Energy, Xcel Energy and Berkshire Hathaway‘s MidAmerican Energy, which generates 59% of it renewable energy from wind, including 3,500 turbines operating across 38 wind projects in Iowa.
A growing number of the turbines are 20-plus years old and nearing the end of their lifecycle. So increasingly, operators have to decide whether to upgrade or replace aging turbines’ key components, such as blades, rotors and electronics, or dismantle them altogether and erect new, technologically advanced and far more efficient models that can increase electricity output by up to 50%.
“What’s becoming clear is that more and more of the U.S. installed base [of onshore turbines] has exceeded its operational design life,” said Charles Coppins, research analyst for global wind at Wood Mackenzie, “and now operators are looking to replace those aging turbines with the latest [ones].”
To date, approximately 70 GW of onshore wind capacity has been fully repowered in the U.S., according to Wood Mackenzie, while an additional 12 GW has been partially repowered. The firm estimates that around 10,000 turbines have been decommissioned and that another 6,000 will be retired in the next 10 years, Coppins said.
Damaged wind turbine that was first hit by a tornado then lightning.
Ryan Baker | Istock | Getty Images
Beyond the fact that aged-out turbines need to be upgraded or replaced, repowering an existing wind farm versus building a new site presents economic benefits to operators and OEMs. To begin with, there’s no need to acquire property. In fact, in certain situations, because today’s turbines are larger and more efficient, fewer turbines are needed. And they’ll generate additional electricity and have longer lifecycles, ultimately delivering higher output at a lower cost.
Even so, “there are some limitations on how much capacity you could increase a project by without having to go through new permitting processes or interconnection queues” to the power grid, said Stephen Maldonado, Wood Mackenzie’s U.S. onshore analyst. As long as the operator is not surpassing the allowed interconnection volume agreed to with the local utility, they can add electricity to the project and still send it to the grid.
Public opposition, Maldonado said, may be another hurdle to get over. Whether it’s a new or repower wind project, residents have expressed concerns about environmental hazards, decreased property values, aesthetics and general anti-renewables sentiment.
RWE, a subsidiary of Germany’s RWE Group, is the third largest renewable energy company in the U.S., owning and operating 41 utility-scale wind farms, according to its CEO Andrew Flanagan, making up 48% of its total installed operating portfolio and generating capacity, which also includes solar and battery storage.
One of RWE’s two repower projects underway (both are in Texas), is its Forest Creek wind farm, originally commissioned in 2006 and featuring 54 Siemens Gamesa turbines. The project will replace them with 45 new GE Vernova turbines that will extend the wind farm’s life by another 30 years once it goes back online later this year. Simultaneously, RWE and GE Vernova are partnering on a new wind farm, immediately adjacent to Forest Creek, adding another 64 turbines to the complex. When complete, RWE will deliver a total of 308 MW of wind energy to the region’s homes and businesses.
Flanagan noted that the combined projects are related to increased electricity demands from the area’s oil and gas production. “It’s great to see our wind generation drive the all-of-the-above energy approach,” he said. What’s more, at its peak, the repower project alone will employ 250 construction workers and over its operating period bring in $30 million in local tax revenue, he added.
In turn, the twin projects will support advanced manufacturing jobs at GE Vernova’s Pensacola, Florida, facility, as well as advancing the OEM’s repower business. In January, the company announced that in 2024 it received orders to repower more than 1 GW of wind turbines in the U.S.
Koiguo | Moment | Getty Images
Siemens Gamesa has executed several large U.S. repowering projects, notably MidAmerican’s expansive Rolling Hills wind farm in Iowa, which went online in 2011. In 2019, the company replaced 193 older turbines with 163 higher-capacity models produced at its manufacturing plants in Iowa and Kansas.
Last year, Siemens Gamesa began repowering RWE’s 17-year-old Champion Wind, a 127-MW wind farm in West Texas. The company is upgrading 41 of its turbines with new blades and nacelles (the housing at the top of the tower containing critical electrical components) and adding six new turbines.
In early April, Clearway announced an agreement with Vestas to repower its Mount Storm Wind farm in Grant County, West Virginia. The project will include removing the site’s 132 existing turbines and replacing them with 78 new models. The repower will result in an 85% increase in Mount Storm’s overall electricity generation while using 40% fewer turbines.
Preparing for ‘megatons’ of turbine recycling and tariffs
Another benefit of repowering is invigorating the nascent industry that’s recycling megatons of components from decommissioned turbines, including blades, steel, copper and aluminum. Most of today’s operational turbines are 85% to 95% recyclable, and OEMs are designing 100% recyclable models.
While the majority of mothballed blades, made from fiberglass and carbon fiber, have historically ended up in landfills, several startups have developed technologies recycle them. Carbon Rivers, for example, contracts with the turbine OEMs and wind farm operators to recover glass fiber, carbon fiber and resin systems from decommissioned blades to produce new composites and resins used for next-generation turbine blades, marine vessels, composite concrete and auto parts.
Veolia North America, a subsidiary of the French company Veolia Group, reconstitutes shredded blades and other composite materials into a fuel it then sells to cement manufacturers as a replacement for coal, sand and clay. Veolia has processed approximately 6,500 wind blades at a facility in Missouri, and expanded its processing capabilities to meet demand, according to David Araujo, Veolia’s general manager of engineered fuels.
Trump’s new-project moratorium isn’t his only impediment to the wind industry. The president’s seesaw of import tariffs, especially the 25% levy on steel and aluminum, is impacting U.S. manufacturers across most sectors.
The onshore wind industry, however, “has done a really good job of reducing geopolitical risks,” said John Hensley, senior vice president for markets and policy analysis at the American Clean Power Association, a trade group representing the clean energy industry. He cited a manufacturing base in the U.S. that includes hundreds of plants producing parts and components for turbines. Although some materials are imported, the investment in domestic manufacturing “provides some risk mitigation to these tariffs,” he said.
Amidst the headwinds, the onshore wind industry is trying to stay focused on the role that repowering can play in meeting the nation’s exponentially growing demand for electricity. “We’re expecting a 35% to 50% increase between now and 2040, which is just incredible,” Hensley said. “It’s like adding a new Louisiana to the grid every year for 15 years.”
GE Vernova CEO Scott Strazik recently told CNBC’s Jim Cramer that the growth of the U.S.’s electric load is the largest since the industrial boom that followed the end of the second world war. “You’ve got to go back to 1945 and the end of World War II, that’s the infrastructure buildout that we’re going to have,” he said.
As OEMs and wind farm developers continue to face rising capital costs for new projects, as well as a Trump administration averse to clean energy industries, “repowering offers a pathway for delivering more electrons to the grid in a way that sidesteps or at least minimizes some of the challenges associated with all these issues,” Hensley said.
Capable of delivering up to 1,200 kW of power to get electric commercial trucks back on the road in minutes, the new ABB MCS1200 Megawatt Charging System is part of an ecosystem of electric vehicle supply equipment (EVSE) that ABB’s bringing to this year’s ACT Expo.
ABB E-mobility is using the annual clean trucking conference to showcase the expansion of its EVSE portfolio with three all-new charger families: the field-upgradable A200/300 All-in-One chargers, the MCS1200 Megawatt Charging System for heavy-duty vehicles shown (above), and the ChargeDock Dispenser for flexible depot charging.
The company said its new product platform was built by applying a computer system-style domain separation to charger design, fundamentally improving subsystem development and creating a clear path forward for site and system expansion. In other words, ABB is selling a system with both future-proofing and enhanced dependability baked in.
“We have built a system by logically separating a charger into four distinct subsystems … each functioning as an independent subsystem,” explains Michael Halbherr, CEO of ABB E-mobility. “Unlike conventional chargers, where a user interface failure can disable the entire system, our architecture ensures charging continues even if the screen or payment system encounters issues. Moreover, we can improve each subsystem at its own pace without having to change the entire system.”
Advertisement – scroll for more content
The parts of ABB’s new EVSE portfolio that have been made public so far have already been recognized for design excellence, with the A400 winning the iF Gold Award and both the A400 and C50 receiving Red Dot Design Awards.
New ABB chargers seem pretty, good
ABB’s good-looking family; via ABB.
ABB says the systemic separation of its EVSE enhances both reliability and quality, while making deployed chargers easier to diagnose and repair, in less time. Each of the chargers’ subsystems can be tested, diagnosed, and replaced independently, allowing for quick on-site repairs and update cycles tailored to the speed of each systems’ innovation. The result is 99% uptime and a more future-proof product.
“The EV charging landscape is evolving beyond point products for specific use cases,” continued Halbherr. “By implementing this modular approach with the majority of our R&D focused on modular platforms rather than one-off products … it reduces supply chain risks, while accelerating development cycles and enabling deeper collaboration with critical suppliers.”
Key markets ABB is chasing
HVC 360 Charge Dock Dispenser depot deployment; via ABB.
PUBLIC CHARGING – with the award winning A400 being the optimal fit for high power charging from highway corridors to urban locations, the latest additions to the A-Series All-in-One chargers offer a field-upgradable architecture allowing operators to start with the A200 (200kW) with the option to upgrade to 300kW or 400kW as demand grows. This approach offers scalability and protects customer investment, leading to Total Cost of Ownership (TCO) savings over 10 years.
PUBLIC TRANSIT AND FLEET – the new Charge Dock Dispenser – in combination with the already in market available HVC 360 – simplifies depot charging with a versatile solution that supports pantograph-, roof-, and pedestal charging options with up to 360kW of shared power and 150m/490 ft installation flexibility between cabinet and dispensers. The dispenser maintains up to 500A output.
HEAVY TRUCKS – building the matching charging infrastructure for commercial vehicles and fleets represents a critical innovation frontier on our journey to electrify transportation. Following extensive collaboration with industry-leading truck OEMs, the MCS1200 Megawatt Charging System delivers up to 1,200kW of continuous power — 20% more energy transfer than 1MW systems — providing heavy-duty vehicles with purpose-built single-outlet design for the energy they need during mandatory driver breaks. To support other use cases, such as CCS truck charging, a dual CCS and MCS option will also be available.
ABB says that the result of its new approach are chargers that offer 99% plus uptime — a crucial statistic for commercial charging operations and a key factor to ensuring customer satisfaction. The new ABB E-mobility EVSE product family will be on display for the first time at the Advanced Clean Transportation Expo (ACT Expo) in Anaheim, California next week, then again at Power2Drive in Munich, Germany, from May 7-9.
If you’re considering going solar, it’s always a good idea to get quotes from a few installers. To make sure you find a trusted, reliable solar installer near you that offers competitive pricing, check out EnergySage, a free service that makes it easy for you to go solar. It has hundreds of pre-vetted solar installers competing for your business, ensuring you get high-quality solutions and save 20-30% compared to going it alone. Plus, it’s free to use, and you won’t get sales calls until you select an installer and share your phone number with them.
Your personalized solar quotes are easy to compare online and you’ll get access to unbiased Energy Advisors to help you every step of the way. Get started here.
FTC: We use income earning auto affiliate links.More.