Ohio environmental advocates are questioning the intent of a pending state law that would add nuclear power to the state’s legal definition of “green” energy.

House Bill 308’s sponsors say the legislation is meant to signal that Ohio is open for business when it comes to nuclear power research and development, but critics warn the language could have broader implications in the future.

“Legislators don’t just put something into the code unless it has meaning and purpose and value,” said Megan Hunter, an attorney with Earthjustice, one of several environmental groups challenging a similar 2022 state law that classified natural gas as a “green” energy source. “Why would you do this if it has no impact or meaning or effect?”

Critics fear the language could be used to greenwash power plants or divert public funding from renewable energy projects, though the bill’s sponsors deny that motive.

“It doesn’t promise any incentives or anything beyond simply placing nuclear under the category of green energy in the Ohio Revised Code,” said state Rep. Sean Brennan, a Democrat from Parma who co-sponsored the nuclear legislation with Republican state Rep. Dick Stein of Norwalk. 

The General Assembly passed the nuclear legislation on Dec. 11. As of Thursday it was awaiting Gov. Mike DeWine’s signature.

Brennan said the question of why the language should be in a law instead of just a resolution didn’t come up in discussions with Stein, who initially asked him to cosponsor the bill.

Stein said the legislation is “about sending a signal to the market that Ohio wants to be a partner and won’t be an impediment,” in contrast to other states that don’t want nuclear energy. He said he hopes it will help attract jobs and federal funding, building on last year’s creation of a state nuclear development authority.

Stein would not speculate on follow-up steps lawmakers might take, saying his term in the House of Representatives ends this month.

What the law could do

Ohio does not currently have state incentives or policy preferences for “green” energy. The state’s renewable energy standard essentially ended in 2019 as a result of House Bill 6, the coal and nuclear bailout law at the heart of the state’s ongoing corruption scandal. Opponents testifying against the current legislation, though, said they worry the definition will be used to water down future clean energy policies. 

“HB 308 will enable the manipulation of public funds into private, corporate hands,” said Pat Marida, a coordinator for the Ohio Nuclear-Free Network, in her December 13 testimony. Also, she said, “there is nothing ‘green’ about nuclear power,” referring to radioactive waste, which continues to be stored at power plant sites.

Future state programs might offer funding or other advantages for projects that meet the state’s definition of “green” energy, for example. And even if the definition doesn’t open doors to new government funding, it could provide cover to private companies that want to count gas and nuclear energy toward their climate or clean energy targets, another advocate warned.

“Insidiously, it does potentially become important,” said Nathan Alley, conservation manager for the Sierra Club of Ohio. Many companies have adopted clean energy goals, he noted. “This might telegraph to them that they could invest in nuclear energy and achieve the same climate and/or energy goals as if they invest in solar or wind.”

Ohio lawmakers aren’t the only ones who want to define natural gas and nuclear power as “green energy.” Model legislation finalized by the American Legislative Exchange Council this fall does the same thing. ALEC is a Koch-linked group that has long opposed renewable energy and actions to address climate change.

ALEC’s model bill would have its definition “apply to all programs in the state that fund any ‘green energy’ or ‘clean energy’ initiatives.” Another model ALEC bill would define nuclear energy as “clean energy” and put it on a par with renewable energy.

A coalition of environmental groups is currently challenging House Bill 507, Ohio’s 2022 law that labeled natural gas as “green energy,” arguing in court that the way in which it was passed violated the state constitution. The groups say last-minute amendments violated provisions that require bills to deal with a single subject – the initial two-page bill dealt with chickens – and call for at least three hearings in each house of the General Assembly where lawmakers can hear testimony from supporters and opponents.

That lawsuit has been briefed and is currently awaiting a decision from Judge Kimberly Cocroft at the Franklin County Court of Common Pleas. HB 308 should not affect that case, said Hunter and Alley.

As with HB 507, though, lawmakers added last-minute amendments to HB 308. One of those would extend lease terms for drilling under state park and wildlife areas from three years to five years. That was unacceptable to Brennan, who voted against the Senate amendments when it came back to the Ohio House.

Still, he supports what he views as the main purpose of the legislation: attracting more nuclear power to Ohio. In his view, solar and wind won’t be enough to meet growing energy demands while shifting away from fossil fuels in order to address climate change. “I believe nuclear is going to be hugely important for our energy independence, and hopefully Ohio will become an exporter of electricity in the future.”

Hunter wasn’t surprised that lawmakers made last-minute amendments to the bill. For her, it shows the importance of the ongoing litigation over HB 507.

“Those constitutional protections are there for a reason,” she said. “And seeing the General Assembly have blatant disregard for them again and again harms Ohioans. It deprives them of these constitutional rights.”

A symbolic gesture or Trojan horse? Ohio groups question purpose of ‘green’ nuclear bill  is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Two community-based geothermal pilot projects, each led by equity-focused nonprofits, have advanced to the second phase of funding through a U.S. Department of Energy program. 

Blacks in Green, a community organization based in Chicago, and Home Energy Efficiency Team, a Boston-based nonprofit dedicated to promoting an equitable transition to clean energy, were included last week in a set of five projects across the country that have been awarded a total of more than $35 million from the DOE’s Geothermal Technologies Office to implement geothermal installations.

The five project teams advancing to the next phase of the DOE project were among a cohort of 11 projects participating in the initial phase of the program, where coalitions selected project sites, assessed geothermal resource and permitting needs, conducted feasibility analysis and local engagement, and identified workforce and training needs. The selected projects’ range of sizes, technologies, and innovations will provide potential templates for other communities considering implementing geothermal systems. 

Three of the five projects are located in urban or suburban areas; two are in rural communities. The other three recipients are the city of Ann Arbor, Michigan; the University of Oklahoma, for a project in the town of Shawnee; and GTI Energy, for a project in Hinesburg, Vermont. 

Tapping into Chicago’s alleys

Blacks in Green, located in West Woodlawn, a predominantly Black community on Chicago’s South Side, serves as the lead for a coalition which was awarded $9.9 million for its Sustainable Chicago Geothermal pilot. Other coalition partners are the City of Chicago, University of Illinois, The Accelerate Group, Citizens Utility Board, Climate Jobs Illinois, dbHMS, GeoExchange, and Illinois AFL-CIO.

The pilot, also located in West Woodlawn, utilizes alleys to circumvent the need for vast open plots for subterranean loop fields that form the heart of a geothermal array. Locating the bulk of geothermal loop lines in alleyways also sidesteps the underground congestion of existing utility infrastructure typically located underneath city streets.

It’s among an assortment of elements in the Sustainable Square Mile approach that advances BIG’s vision for energy justice through clean energy and microgrid/VPP systems owned and managed by the community, said Naomi Davis, BIG’s founder and CEO.

“BIG launched in 2007 with a goal of increasing household income and community resilience against the harms of climate crisis at neighborhood scale using the new green economy — so we’re grateful for this chance to make it manifest,” Davis said in a news release. 

Along with installation of the needed infrastructure within the multiblock footprint, year two of the West Woodlawn project will focus on community outreach and job programs. Once construction is complete, the geothermal system will provide heating and cooling, not to mention lower utility bills, for potentially more than 200 households. 

“The Sustainable Chicago Geothermal project will be a transformational investment in the West Woodlawn community. The effort to eliminate harmful emissions from homes and businesses, while lowering energy burden, has proven to be a community-wide challenge, and requires a community-wide solution,” said Andrew Barbeau, president of The Accelerate Group and principal investigator of the Blacks in Green project, in a news release. 

The need to reconstruct the alleyways after installation of the geothermal array also presents the opportunity to replace asphalt or concrete with permeable pavers. This would work to promote climate resiliency through mitigation of urban flooding, a persistent occurrence in many of Chicago’s South and West Side communities, said Nuri Madina, the director of Sustainable Square Mile, who serves as point person for the pilot.

“All of our programs are designed to create multiple benefits,” Madina told the Energy News Network in September.

A first-of-its kind project in suburban Boston

Home Energy Efficiency Team, commonly referred to by the acronym HEET, in partnership with Eversource Energy; the city of Framingham, Massachusetts; and engineering consultant Salas O’Brien; was awarded $7.8 million toward construction of a utility-based,community-scale geothermal system.

“We are honored to receive this funding from the DOE’s Geothermal Technologies Office as part of the Community Geothermal Heating and Cooling initiative, and to show how geothermal energy networks can be interconnected to increase efficiency, build resilience, and decarbonize at the scale and speed we need to achieve our climate goals,” said Zeyneb Magavi, executive director for HEET, in a news release.

The proposed plans by HEET and its partners would connect to the first Framingham geothermal network, which was commissioned earlier this year. Once approved by the state Department of Public Utilities and upon completion, it would represent the first utility-owned community geothermal network to connect to an adjacent operational loop, establishing guidelines for the interconnection and growth of geothermal networks. 

“This innovative project not only showcases Framingham’s commitment to sustainable energy solutions but also sets a precedent for other communities across the nation. By harnessing the natural heat from the earth, we are taking a significant step towards reducing our carbon footprint and promoting renewable energy sources. Our collaboration with HEET and Eversource exemplifies the power of partnerships in driving forward clean energy initiatives,” said Framingham Mayor Charlie Sisitsky in a news release. 

The HEET-led program operates on the principle that utility-scale geothermal systems could operate on a billing model similar to that of natural gas or electrical utilities, and ultimately replace them, Magavi told the Energy News Network in October 2022.

“So instead of feeding natural gas into these buildings, we could feed geothermal water,” Magavi said. “And then we could meter that and sell that. It’s no different than when you pay your water bill.”

Department of Energy funding to boost community-led geothermal projects  is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

When a solar energy developer approached Halifax County, North Carolina, in the early 2010s about renting its former airfield in Roanoke Rapids, community leaders had a condition. 

“If they were willing to lease this land for the very first solar project in the area, the county needed to get something back in return,” said Mozine Lowe from her office, which overlooks the 20 megawatt solar farm now atop the old airport. “What they got was this building.”

Of course, it’s more than a building. It’s the headquarters for the Center for Energy Education, the nonprofit Lowe has run since 2016 that works to maximize the benefits of large solar farms in rural America — one community, one school child, and one worker at a time. 

Lowe, who grew up about five miles from where she now works, had graduated from Greensboro’s North Carolina Agricultural and Technical State University but worked across the country, from California to Washington, D.C. 

When she returned to this rural county of less than 50,000 near the Virginia border, formerly a hub of farming and textiles, she said she didn’t see a lot of change.  

“The jobs were the same,” she said. “I didn’t see people making the connection between solar energy and what’s happening with the climate and the impact on rural communities, and I just wanted to try and help from that angle.” 

The Center conducts educational programs for children of all ages, who come in by the busload from surrounding schools both public and private. It holds a Solar Fest every year to celebrate clean energy with community leaders, drawing hundreds.

Through collaborations with local educational institutions like community colleges, the center has also helped to train a new workforce in jobs that pay roughly twice what workers are earning at the fast-food chains off Interstate 95. 

“We have trained more people than most other people around here to become solar installers,” Lowe said. “We want them to be first in line for our jobs.”

And there’s outreach to solar companies themselves in North Carolina as well as Kentucky, Ohio, and Indiana, where the Center also has offices. The goal is to help them become better community partners.

Only a few ‘good players’ 

Geenex, the Charlotte-based developer who built the solar farm at the airport and over a dozen others in the vicinity, is still involved in the Center, and the company’s chairman also chairs the nonprofit’s board.  

But Lowe and other staff at the organization say not every solar developer is committed — at least at first — to working with community leaders in Eastern North Carolina. 

“Geenex is a very good partner,” said Reginald Bynum, the Center’s community outreach manager. “They’re a good player. But there are only a few of them. Other companies will say, ‘This is your ordinance? Great. This is all I have to do.’” 

Some county ordinances, like that in Halifax, need to be updated, Bynum said. Many still call for a 75-foot buffer between the rows of solar panels and neighboring properties. That figure is “so 2018,” said Bynum. It should be doubled, he said. 

Most solar farms are also built on private land — often bits of farmland that can help cotton growers and other farmers guarantee income. But developers usually obtain the leases first, before airing the project in public. 

“That’s the backwards process of solar,” Bynum said. “They’re talking to landowners and securing that land, and then they’re coming to commissioners.” 

What’s more, simply following ordinances isn’t enough, Bynum says. What’s needed is for solar developers to work with local residents to develop community benefits agreements — documents that memorialize pluses to the area, from minimizing construction impacts to providing jobs. 

“It’s a 30-year commitment to the community,” he said, “because your farm’s going to be here 30 years. They’re asking for that, and they deserve that.” 

Critically, say Bynum and other advocates, solar developers need to work with community leaders to provide benefits beyond tax revenue — an undeniable good, but one that isn’t “seen” by anyone except county bookkeepers.

And though a recent study from the North Carolina Sustainable Energy Association shows that solar farms today take up a fraction of a percent of the state’s farmland, the figure is a full 1% in Halifax County, and on pace to triple in the coming years, according to the Center’s research. 

“From rural citizens’ standpoint, that’s a lot,” Bynum said. “You have to really understand what they’re seeing.” 

‘Projects have gotten bigger’

Part of what they’re seeing is the result of a simple fact: solar farms aren’t just growing more abundant in parts of rural America. They’re also much larger.

In North Carolina up until 2016, the average utility-scale solar development was 5.8 megawatts covering 35 acres of land, per the Sustainable Energy Association. After a 2017 state law made larger solar farms easier to build, the average system size increased to 13.6 megawatts and covered 115 acres of land.

“Projects have gotten bigger,” said Carson Harkrader, the CEO of Durham-based Carolina Solar Energy, who appeared on a recent clean energy panel with Bynum. “As they’ve gotten bigger, people freak out a little bit.” 

And while many folks’ worries about the visual impact of solar panels can be mollified — with tree buffers, setbacks, and information about the safety of the structures — some are easy targets for opponents. 

“The opposition has become much, much, more organized. There are national groups, funded by the oil and gas industry,” Harkrader said. “With this opposition that is more organized and has more resources, it’s much harder.” 

In some cases, opponents may fill a vacuum left by solar companies who lined up projects before the pandemic and have only recently begun to start construction. 

That’s what happens, said Bynum, “when you miss steps in keeping citizens updated with the project — particularly when you started talking about it five years before. Commissioners change, a lot of tribal knowledge evaporates.” 

More success stories?

And sometimes, it only takes one or two community members to force the issue with local politicians. Both neighboring Northampton and Halifax counties have passed moratoriums on new solar farms recently. Halifax acted after just a few people appeared at their meeting, concerned about the loss of trees.

Having talked with county commissioners, staff at the Center are hopeful the moratorium will end quickly as planned, after the county has updated its ordinance. But the “pause” on solar farms is an example of the constant game of whack-a-mole solar developers and their advocates must play.

Lowe says that’s why the Center is so vital. 

“What makes us unique is that our work is mainly community engagement,” she said. “Our stance is to be neutral, and to provide factual information. I think we need to tell more success stories.”

How one nonprofit is working to build support for solar — and added benefits for communities — in rural North Carolina is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Massachusetts environmental advocates hope a provision in the state’s new climate law could be a final blow to a proposed expansion of private jet facilities at a suburban airport. 

Opponents say adding 500,000 square feet of hangar space at Hanscom Field, a general aviation airport that serves private and corporate aircraft in a town 20 miles outside of Boston, will inevitably mean more flights — mostly private jet travel to luxury locations — which will increase climate pollution with minimal public benefit.

“This is an industry that is highly polluting and yet serves only a very narrow slice of the public,” said Alex Chatfield, a local social worker and an activist fighting the project. 

The expansion plans have been in the works since 2021, but progress slowed in June after state regulators rejected the planners’ first environmental impact report. Since then, state lawmakers passed a new law requiring state agencies and boards, including the state port authority, to consider the impact of greenhouse gas emissions in their decisions. 

The measure does not directly prohibit the Massachusetts Port Authority from proceeding with projects such as the Hanscom plan, but it does leave the agency vulnerable to legal action should it forge ahead without being able to show it weighed the likely greenhouse gas emissions against the benefits of the plan. 

Much-needed hangars

The expansion plan started with Massport, which oversees operations at Hanscom as well as Boston’s Logan International Airport and Worcester Regional Airport. In 2021, the agency released a request for proposals to develop “much-needed hangars” at the airport, said Massport spokesperson Jennifer Mehigan. A plan submitted by North Airfield Ventures and Runway Realty Ventures won the bid. 

The proposed facilities would be built on 47 acres of land, some of which is already owned by the developers and some of which would be leased to them by Massport. The project comprises 17 new hangars, the rehabilitation of a historic Navy hangar on the site, and fuel storage facilities. 

Planners argue the development would be environmentally beneficial, because the structures would be designed for net-zero energy use and built to LEED Gold standards, and buildings and equipment would be electrified whenever possible. They also claim the additional capacity would help cut down on emissions from so-called “ferry flights,” in which a plane hangared elsewhere flies to Hanscom to pick up passengers and then returns to its home airport at the end of the trip. 

Opponents, however, argue that more hangars will inevitably mean more flights. These flights, they say, are likely to be private jet travel to luxury locations, generating emissions for the benefit of just a privileged few. One report, by Washington, D.C.-based Institute for Policy Studies, found that 31,600 private flights departed Hanscom during an 18-month period in 2022 and 2023, and that roughly half of those were bound for high-end vacation destinations like the Bahamas, Palm Beach, and Nantucket.

“It’s very well known that private jets are the most polluting form of transportation per passenger ever devised,” Chatfield said. “It is on a scale that is really hard to imagine.”

State environmental regulators are also skeptical. The state response to the developers’ first environmental impact report, referred to the “fanciful nature of the proponents’ ‘ferry flight theory,’” pointing to a study that found only 132 ferry flights actually occurred at Hanscom rather than the 3,500 developers claimed. Regulators also suggested new hangars at Hanscom were unlikely to attract planes to relocate, and therefore would not reduce what ferry flights do occur.

The developers can resubmit their environmental impact report, addressing the state’s concerns. One of the founders of North Airfield Ventures said the company declines to comment on its plans at this time. 

Factoring in climate impacts

In the months since the state’s order was released, legislators created another obstacle for the project. 

As Massachusetts attempts to reach its goal of net-zero carbon emissions, an ongoing mundane-yet-important challenge has been the fact that some crucial state agencies and boards have lacked the authority to factor climate impacts in their decisions. These bodies were founded well before the climate crisis became such a pressing public policy question, and thus their rules never required or authorized them to consider greenhouse gas emissions or other climate impacts in their decision-making. 

In recent years, attempts have been made to integrate climate change mitigation into more statewide policies and processes. A climate law enacted in 2021 requires the administration to set greenhouse gas reduction goals to be realized by the state’s three-year energy efficiency plans, which were initially intended only to reduce the cost and quantity of electricity, gas, and oil used. The same bill instructed public utilities regulators to consider greenhouse gas impact as part of their decisions. 

“The department up to that point had just focused on reliability and affordability,” said state Sen. Michael Barrett, chair of the legislature’s committee on telecommunications, utilities, and energy, and one of the main authors of both the 2021 and 2024 climate bills. “I have wanted to reorient state agencies that don’t seem to have gotten the memo about climate change being an existential crisis.”

The latest bill included more such provisions, authorizing the Board of Building Regulations and Standards to give preference to building materials that boost emissions reductions, and requiring Massport to consider the greenhouse gas impacts of its decisions.

“I hope that Massport appreciates that what is done today on climate is inadequate, and I hope it also appreciates that the policies have changed,” said Barrett. “I don’t pretend to be able to predict particular outcomes on particular projects, but I do know that Massport needs to take this seriously.”

Plan to expand airport for private jets runs into new Massachusetts climate law is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Three Ohio companies are investing in hydrogen fuel cell passenger vehicles even as the U.S. market for electric vehicles continues to grow. Each has an innovative approach to the chicken-and-egg problem of having fuel available when and where drivers need it.

The Ohio companies’ focus on fuel cell passenger vehicles is unique nationwide, especially for a state that doesn’t yet have any public hydrogen fueling stations. California, where almost all of the country’s hydrogen fuel cell cars are registered, still has fewer than 60 public stations. 

“When we see hydrogen transportation deployment projects, it’s really more on the medium- and heavy-duty side,” said Mark Henning, a researcher at Cleveland State University’s Energy Policy Center at the Maxine Goodman Levin School of Urban Affairs.

A hydrogen car is essentially an electric vehicle with an onboard fuel cell providing electricity alongside a battery. General Motors first displayed a prototype for a hydrogen fuel cell vehicle back in the 1960s, but hydrogen cars weren’t available to U.S. consumers until leases for the 2015 Hyundai Tucson Fuel Cell began, with sales of the Toyota Mirai starting that fall. 

Hydrogen car sales have been essentially limited to California, where state policy and public funding supported the development of some public fueling stations. Since then, only about 18,000 fuel cell cars have been sold in the U.S.

Yet Ohio companies have been working on hydrogen energy for more than two decades. The state trade association, the Ohio Fuel Cell and Hydrogen Coalition, traces its history back to 2003. 

If successful, the current efforts could eventually provide another option for switching away from gasoline-powered cars. While electric vehicles are comparable in price, hydrogen cars can be refueled quickly — assuming the infrastructure is available — and offer more consistent range in cold weather. But much could hinge on how quickly hydrogen infrastructure develops, as well as how quickly and effectively plug-in electric vehicle makers deal with their own range and charging challenges.

One example of the desire for hydrogen vehicle alternatives comes from DLZ, an engineering, architectural and project management company headquartered in Columbus with offices across the United States as well as in India and Costa Rica. The company has a fleet of about 250 vehicles across the Midwest, including electric vehicles. In 2022, it added six Hyundai hydrogen fuel cell cars for use by professionals from its Columbus office.

“The hydrogen fuel cell vehicles have a lot more consistent performance in range and durability,” especially in cold weather, said Ram Rajadhyaksha, DLZ’s executive vice president. The range for the cars is sufficient for round trips the office’s professionals make to site locations around the state, he explained at the Ohio Fuel Cell & Hydrogen Coalition symposium in North Canton last month.

Hydrogen fuel cell cars aren’t sold in Ohio yet, so DLZ had its six Hyundai vehicles shipped from California to Columbus. Except for the fuel cells, dealers in Ohio can provide any necessary service the vehicles may need, Rajakhyasksha said.

The cars also need a regular source of hydrogen, so DLZ added its own. Its station in Columbus can generate about 20 kilograms of hydrogen per day, using electricity from a solar array atop a large building on company property. A net metering agreement lets DLZ sell any excess electricity from the array to the grid. 

Nonetheless, there were hurdles, including permitting, building codes, supply chain issues during the tail end of the pandemic, and even signage codes.

Made in Ohio

While California has been the country’s epicenter for fuel cell vehicles, Honda Motors is now producing the first American-made hybrid hydrogen vehicle at its Marysville plant in Ohio. Its 2025 CR-V e:FCEV model can go roughly 270 miles on a tank of hydrogen. There’s also a small electric battery which provides a driving range of about 30 miles. A 110-volt power outlet on the vehicle can run small home appliances or other equipment.

That range is about the same as Honda’s all-electric Prologue SUV, which also has a comparable list price. But the company believes there is room for both.

“It’s not one or the other,” said Dave Perzynski, assistant manager for hydrogen solutions business development at Honda, who also spoke at the Ohio Fuel Cell & Hydrogen Coalition symposium. “It’s using the right equipment at the right place at the right time.” The CR-V’s electric charging range is about right for his daily round-trip commute, he said, while the fuel cell offers flexibility for longer trips.

Honda’s goal is to achieve 100% decarbonization, Perzynski said. However, limits on local electric grids can make that difficult in some places. “If you can electrify it, if it works, then do that,” he said. “And once that stops working, then thank goodness we’ve been investing in hydrogen for the last 20 years, because there are places and times when you run out of power.”

As a practical matter, the Ohio-made cars’ initial market will be California. For other states, Honda is counting on others to build out the fueling infrastructure. 

“The only way we can do that is through a coalition,” Perzynski said. “We can’t build infrastructure alone.”

Building a network

Millennium Reign Energy in Dayton has a membership model to develop hydrogen infrastructure along with the demand for it. Its Emerald H2 network will help customers buy used fuel cell vehicles, while also providing access to hydrogen fueling stations designed and built by the company.

As the number of customers in an area grows, Millennium Reign Energy would swap out the fueling station for one with larger capacity. The smaller station would then go to another location. Access to the stations would be for members only, although members traveling outside their local area could use stations elsewhere.

“Our mission is to build the first transcontinental hydrogen highway,” said CEO Chris McWhinney as he explained the model at the fuel cell program last month. The company’s fueling stations are already operating at places outside the United States, as well as three private facilities in Ohio. The company plans to add its first Emerald H2 network stations in the Dayton area early next year.

The stations use electricity and water to make hydrogen, so using one with a nearby source of solar, wind, hydropower or geothermal energy can provide green energy, versus just moving emissions from tailpipes up to power plants, McWhinney said. That can also bring the cost for the hydrogen fuel down below that of gasoline, he suggested, as renewable electricity continues to get cheaper.

Hurdles ahead

Whether hydrogen-powered passenger vehicles are the best use for renewable energy remains questionable. A study published in Joule last August found battery-electric vehicles were roughly three times more efficient in using renewable electricity than fuel-cell vehicles.

“The battery-electric case is much more efficient than the hydrogen fuel cell vehicle,” said Greg Keoleian, co-director of the University of Michigan’s MI Hydrogen initiative, and one of the co-authors of the Joule study. Ideally, renewable energy will be used efficiently, given the limited amount on the grid now and the urgent need to decarbonize because of climate change, he said.

Battery electric cars also have a much bigger charging network, with nearly 70,000 stations nationwide, Keoleian noted. Cost is also an issue, he added, noting that hydrogen fuel in California currently costs about five times as much as gasoline would to go the same distance. 

Henning did note that one of Ohio’s public transit systems, SARTA, the Stark Area Regional Transit Authority, has had hydrogen buses as part of its fleet since 2016. Transit fleets also often need a handful of passenger vehicles, which might be able to use tbuses’ hydrogen fueling station while also qualifying for bulk discounts that may start with the acquisition of five or six vehicles, he said.

The Department of Energy’s recent push for hydrogen hubs might also play an indirect role, suggested Sergey Paltsev, deputy director of the Massachusetts Institute of Technology’s Center for Sustainability Science and Strategy. None of the hub projects so far focus on light-duty vehicles, but infrastructure developed for other purposes could make it easier to develop fueling stations. In that case, the Ohio companies could be angling for a competitive advantage. 

Yet much remains unknown about whether the incoming Trump administration will continue incentives begun in the Biden administration, Henning said. The law’s tax credit can apply to fuel cell vehicles with final assembly in North America, which might apply to Honda’s hybrid car — if the Inflation Reduction Act continues.

“I do think there is an appetite and there is a customer base for fuel cell electric vehicles, and I can imagine different use cases where that makes more sense” than an all-electric car, said Grant Goodrich, executive director of the Great Lakes Energy Institute at Case Western Reserve University. Multiple people in Northeast Ohio have expressed reluctance to buy an electric vehicle now, especially given the challenges of harsh winter weather.

Yet the infrastructure for electric vehicles is much farther ahead, and electric vehicle makers continue to work to improve performance. “Will the technology of battery and electric vehicles improve enough to stay ahead of FCEV adoption so that is able to keep that challenge at bay?” Goodrich asked.

Early last month, he would have put money on the EV makers to stay ahead. After hearing the presentations from Honda, Millenium Reign Energy and DLZ, he’s not so sure. 

“It’s not a done deal,” Goodrich said, noting that the hydrogen fueling experience also seems to be a more natural replacement for the habits customers have adopted as drivers of vehicles with internal combustion engines. “If it was to roll out faster, I think you could see some competition there.”

Editor’s note: This story was updated to clarify Greg Keoleian’s role.

Why Ohio companies are investing in hydrogen cars despite infrastructure issues is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Emissions from buildings make up about two-thirds of the greenhouse gas footprint of Indianapolis. So when the city committed to slash emissions, in its 2019 climate action plan and then as part of the Bloomberg American Cities Climate Challenge in 2020, leaders knew where they had to start.

A 2021 ordinance requires all buildings over 50,000 square feet and publicly-owned buildings over 25,000 square feet to do energy benchmarking and report results to the city, to be made publicly available by 2026. 

The deadline to comply was July 1, 2024. But at year’s end, only about 20% of the 1,500 buildings covered had complied — even though the process can be done in a matter of hours using EPA’s ENERGYSTAR Portfolio manager software. The city also hosted workshops to help walk building managers through the process.

Now the city’s challenge is to boost benchmarking compliance. The penalties for failing to comply are low: fines of $100 the first year and $250 yearly after that. Chicago’s 2013 benchmarking ordinance, by comparison, includes fines of $100 for the first day of a violation and up to $25 each day thereafter, with a maximum fine of $9,200 per year — and the city has a much higher compliance rate.

Lindsay Trameri, community engagement manager for the Indianapolis Office of Sustainability, said the office is continuing outreach, including sending postcards to all relevant building managers and owners. 

“We’re not assessing fines yet, but we’re making sure they’re aware this isn’t a city program that’s going away, it is indeed local law,” Trameri said. “And there are benefits to be gleaned from participating. It might cost hundreds of dollars not to participate, but you could save thousands if you participate and take it seriously.”

Trameri said 27 publicly-owned buildings in the consolidated city and county government must be benchmarked, and the city is planning to use about $800,000 worth of federal Department of Energy funding to hire an energy manager “who will be solely focused on looking at city-owned buildings and how to make them more energy efficient.” 

In Indiana, reducing buildings’ electricity use is particularly urgent since the state got about 45% of its power from coal in 2023. The benchmarking mandate doesn’t require buildings to take any action based on their energy results, but benchmarking often motivates building owners and municipalities to invest in savings, experts say. 

Cities participating in the Bloomberg program saw 3% to 8% energy reductions and millions in savings, with nearly 400 million square feet now covered by benchmarking policies and over 37,000 energy audits completed, according to Kelly Shultz, who leads Bloomberg Philanthropies” sustainable cities initiative. 

Success stories

Though overall compliance is low, some major public and private entities have completed benchmarking in Indianapolis, including the airport, convention center, the Indianapolis Museum of Art, Target and JC Penney. 

Phil Day, facilities director for the museum, noted that it’s crucial for museums to keep consistent levels of humidity and temperature. That means high energy use, and also vulnerability to blackouts or energy price spikes. Benchmarking has helped him develop plans for reducing natural gas and electricity use with smaller boilers and heat pumps distributed throughout the facilities, a possible geothermal chilling system, and better insulation. These innovations should save money and make the museum more resilient to energy disruptions.

“Museums aren’t typically known as an energy efficient facility, but it is always high on my priority list in everything we program or replace,” Day said.

The firm Cenergistic has done benchmarking since 2017 for Indianapolis Public Schools, and identified more than $1 million in wasteful energy costs that could be cut across 71 schools. Under Cenergistic’s contract, it is paid half of the energy savings it secures. Seventeen school buildings have obtained EPA Energy Star status based on their energy efficiency improvements, Cenergistic CEO Dennis Harris said. 

“Benchmarking provided a clear starting point by identifying high-energy-consuming facilities and systems,” Harris said. “Cenergistic energy specialists track energy consumption at all campuses with the company’s software platform, identifying waste and driving conservation. By consistently reviewing this data, Cenergistic continues to work with IPS to make data-driven decisions, set measurable goals, and continually refine its strategy for maximum impact.” 

Trameri said the schools’ success is “a great message to point to. If they can do it, we can do it. Of course, we want those millions to go back into classrooms and teachers and students versus out the door for utility costs.”

Learning by example

Trameri said in developing its benchmarking program and ordinance, Indianapolis has relied on guidance and lessons from other cities including Columbus, Ohio and Chicago, both fellow participants in the Bloomberg challenge. 

In Chicago, about 85% of the 3,700 buildings covered by the ordinance are in compliance, said Amy Jewel, vice president of programs at Elevate, the organization that oversees Chicago’s program. She said nine out of 10 buildings complied even right after the ordinance took effect, thanks to years of organizing by city leaders and NGOs like the Natural Resources Defense Council.

“A large number of building owners recognized this was coming. They engaged in the process, and saw their fingerprints within the ordinance,” said Lindy Wordlaw, director of climate and environmental justice initiatives for the city of Chicago. 

Chicago passed an additional ordinance creating an energy rating program, where buildings receive a score of 0 to 4 based on their energy benchmarking results. An 11-by-17-inch placard with the score and explanation must be publicly posted, “similar to a food safety rating for a restaurant,” Wordlaw said.

In 2021, Chicago reported that median energy use per square foot had dropped by 7% over the past three years, and greenhouse gas emissions had dropped 37% since 2016 in buildings subject to the ordinance. City public housing and buildings owned by the Archdiocese were among those to do early benchmarking and investments.

Along with Philadelphia, New York and Washington D.C., Chicago was among the nation’s first major cities to institute benchmarking. Jewel said they hope to keep sharing lessons learned.

For example, “it’s actually pretty hard to come up with the covered buildings list,” Jewel noted, since there is no central list of all buildings in a city but rather various records “all used for slightly different purposes — the property tax database, different sources tracking violations. It took a bit of time to get that list together, and it takes time to maintain it as buildings are constructed or demolished.”

In Indianapolis, Trameri said they are hopeful more buildings will get with the program as awareness grows about the requirement.

“There has always been evidence that you can’t manage what you don’t measure,” said Trameri. “It’s a market-based strategy. Truly once a facilities owner or manager is able to look at their energy usage over a month, 12 months, or multiple years and make evidence-based decisions based on that data, it will affect your bottom line, and those savings you can reinvest into whatever your organization’s mission is.”

Correction: An earlier version of this story misattributed performance information about Bloomberg Philanthropies’ sustainable cities initiative.

Indianapolis grapples with low compliance on energy benchmarking requirement for large buildings is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Amid a surge in utility shutoffs, and in the face of a groundbreaking study finding racial disparities in those outcomes, Minnesota’s largest utility is taking a closer look at the issue.

In a November agreement with consumer groups and the state’s Public Utilities Commission, Xcel Energy has outlined a series of steps to provide more information to customers and make it easier for them to restore service.

Xcel also agreed to hire an outside consultant to conduct a one-year study of disparity issues related to disconnections and outages and, separately, do its own analysis of outages. The move came in response to a University of Minnesota study released earlier this year that found that people of color were more likely than White households to have their service disconnected for falling behind on bills, even when controlling for income and home ownership status. 

The agreement falls short of a demand from the Minnesota Attorney General’s Office for Xcel to institute a temporary moratorium on shutoffs until racial disparities are addressed, based on a recommendation from Fresh Energy and a coalition formed by Cooperative Energy Futures, Environmental Law & Policy Center, Sierra Club, and Vote Solar. 

Erica McConnell, staff attorney for the Environmental Law & Policy Center, represented the clean energy organizations advocating for grid equity. She supported the agreement but believes it will do little to help reduce disparities in shutoffs. 

“These are very important improvements that don’t really address — and the commission didn’t discuss — the disparate impacts and the racial disparity (of disconnections) and how to address that specifically,” she said.

A temporary moratorium on disconnections would have allowed for time to study disparities and find ways to address them.  

“The commission didn’t talk about that,” McConnell said. “They didn’t address it at all, so that was disappointing. I understand it’s uncomfortable and it’s a tough issue, but it’s disappointing they shied away taking it head on.”

Shutoffs soaring

Beyond the challenge of disparities, Xcel’s number of service disconnections has skyrocketed. More than 45,000 Xcel customers saw their power shut off this year, a number that has grown significantly over the last two decades. 

Xcel agreed to many proposals from the Citizens Utility Board of Minnesota, the Energy CENTS Coalition, clean energy organizations and the Public Utilities Commission to create more consumer protection against shutoffs.

Xcel Energy’s involuntary disconnection notices began rising significantly in 2023 before skyrocketing in 2024, when shutoffs doubled the prior year’s total for May through July. Despite Minnesota’s cold weather protection rules that limit disconnections during the winter through April 30, shutoffs even grew during the winter months.

Clean energy and consumer organizations point to Xcel’s ability to remotely disconnect customers who have smart meters as a major reason for the shutoffs, along with inflation, escalating rate increases and challenging repayment requirements. Xcel had demanded customers pay 50% of what they owe to reconnect, which may have violated Minnesota law, according to the Citizens Utility Board. 

Xcel’s pact with the Citizens Utility Board and Energy CENTS “is going to make payment agreements more affordable and hopefully help households that are behind on their bills avoid getting shut off and get caught back up,” said Annie Levenson-Falk, executive director of the Citizens Utility Board of Minnesota.

The utility board and Energy CENTS Coalition forged the agreement with Xcel under the purview of the Public Utilities Commission, which will issue a final order later. The agreement requires the following:

• Customers will pay 10% of what they owe to have the power turned back on, instead of 50%.
• The amount due will have to be at least $180 before Xcel can send a disconnect notice.
• Xcel cannot shut off power until a customer reaches a $300 past due balance. Xcel’s data from this year showed disconnected customers were $441 in arrears on average in October and much higher in other months.
• The utility must wait at least 10 days after a shutoff notice has been sent to disconnect, up from five days.
• Xcel must post clear disconnection and payment policies on its website, along with information about customers’ right to develop an affordable repayment plan. Any changes Xcel makes to shutoff policies and repayments have to be reported to the commission, and it must collect data on repayments and customer agreements.
• A variance allowing remote disconnections without field visits from Xcel remains, but the utility must contact customers via voicemail and use at least one other form of electronic communication.

Xcel spokesperson Kevin Coss said the utility believes “this agreement is a great step toward reducing disconnections for some of our customers who continue to struggle economically.”

Options for customers

George Shardlow, Energy CENTS executive director, said he thought a clearer explanation of the disconnection process on Xcel’s website brings a transparency that had been lacking.

“I don’t think the average person even knows that they have a right to negotiate when they’re struggling to pay their bills,” he said. “It’s all sort of opaque. We’re excited to see better documentation of people’s rights on Xcel’s website.”

Minnesota law says utility customers are “entitled” to a payment plan they can afford, Shardlow said. Customers who cannot afford the 10% down payment can still negotiate for a settlement that fits their budget, he added.

Shutoffs have been growing. This year Xcel sent disconnection notices to 51,000 customers in January and 71,000 in July. But not all notices result in shutoffs. The highest month for disconnections, May, saw more than 10,000 shutoffs. By August, slightly more than 8,400 customers had been disconnected.

Coss said Xcel works with customers to avoid disconnection by starting a nine-week process of contacting them through multiple channels to “point them to available options for energy assistance — both through the federal Low Income Home Energy Assistance Program and our own affordability programs — and offer flexible payment plans tailored to their circumstances.”

Minnesota also has cold weather protections that greatly reduce utilities’ ability to disconnect customers in winter months. But people who fail to pay their bills in winter see their balances grow, leading to higher disconnections in summer when they fail to catch up.

Xcel agreed to monitor progress and collect more data on racial disparities involving customers involuntarily shut off. The utility has already hired a third party evaluator, as the agreement requires, to study its shutoff policies and hold stakeholder engagement meetings during the year-long process.

Coss said disparities result in inequities throughout society and Xcel has been doing its part to address them. The utility has worked with the study’s authors and advocacy groups to identify actions to reduce disparities, he said.   

Earlier this year, the commission also approved a proposal by Xcel for a pilot program that will provide bill credits to select census tracts with high levels of disconnections. Coss said Xcel will provide $500 bill credits to customers in low-income census areas who have a greater than $2,000 past-due balance, using money available from a quality of service program.

Minnesota Public Utilities Commissioner Joe Sullivan said he believed the agreement negotiated among the nonprofits and utility would reduce the financial strain on households facing disconnections and assist Xcel in recovering debt.

“I thought that in that docket people came together and were constructive,” he said. “I feel like I’m hopeful that the order will make some progress.”

PUC Chair Katie Sieben said the commission is “always looking at affordability, and especially as it pertains to low-income customers, I think we have a great track record on working with stakeholders and with utilities to provide robust low-income assistance to customers.”

She mentioned the commission’s role in approving an Xcel pilot to decrease payments for low-income, low-usage customers and a September decision that used a penalty for the utility’s service quality underperformance to provide bill credits to around 1,000 customers with the oldest outstanding balances in low-income census tracts.

‘Still more work to do’

The agreement does not solve the problem of low-income customers struggling to pay utility bills. Shardlow said Energy CENTS and the Citizens Utility Board lobbied the state legislature to allow households to apply for energy assistance funding the entire year instead of the current policy of having a deadline of May 31. Only 20% of eligible Minnesota households participate in the program, he said.

Levenson-Falk wants Xcel to consider eliminating the 1.5% late fee it charges customers on their balance, or consider donating the money to affordability programs.

The Citizens Utility Board also wants Xcel to develop a plan to reconnect customers quickly on days of high heat or poor air quality. Coss said Xcel will evaluate reconnecting customers disconnected during days of air quality alerts.

Levenson-Falk said the agreement at least makes progress. “I think we resolved everything that we had discussed with Xcel but that’s not to say that we think this is going to solve the problem, because, of course, there are still going to be continuing shutoffs, and those are still very concerning,” she said. “There’s still more work to do.”

This story was updated to include a statement from Minnesota Public Utilities Commission Chair Katie Sieben.

Fresh Energy staff, board members and funders do not have access to or oversight of the Energy News Network’s editorial process. More about our relationship with Fresh Energy can be found in our code of ethics.

As utility shutoffs soar in Minnesota, Xcel Energy agrees to consumer protections and racial disparities study is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Living in a net-zero home is often a luxury for those who can afford solar panels, state-of-the-art HVAC and other innovations and renovations.

But lower-income people are those who could benefit most from energy cost savings, and those who suffer most from extreme climate. Milwaukee is trying to address this disconnect by building net-zero homes for low-income buyers in partnership with Habitat for Humanity, a marquee project of the city’s 2023 Climate and Equity Plan.

In September, the U.S. Department of Energy announced a $3.4 million grant that will go toward Milwaukee’s construction of 35 homes on vacant lots in disadvantaged neighborhoods and the opening of a factory to make wall panels for net-zero manufactured homes.

City leaders have found the undertaking more challenging than expected, especially on the factory front. But they hope overcoming roadblocks will help create a new local and regional market for energy-efficient, affordable prefabricated homes, while also training a new generation of architects in the sector through partnership with the University of Wisconsin-Milwaukee School of Architecture and Urban Planning.

“It remains an ambitious project,” said Milwaukee environmental sustainability director Erick Shambarger. “We’re trying to support equity, climate, new technology, manufacturing. It takes some time, but we’re excited about it and looking forward to making it a success.”

Panelized, prefabricated homes can be built relatively cheaply, but making them highly energy efficient is a different story. A handful of small companies nationwide make the wall panels used in such construction to highly energy-efficient standards, but transporting the panels is expensive and creates greenhouse gas emissions. 

The city sought a local manufacturer, but an initial request for proposals yielded no viable candidates. Now the city and UWM professors are working with the Rocky Mountain Institute to convince a qualified company to open a site in Milwaukee to make energy-efficient panelized home components at commercial scale, for both the city and private customers.

“It’s such a great fit for Milwaukee,” said Lucas Toffoli, a principal in RMI’s carbon-free buildings program. “It’s a city that has a very strong blue-collar tradition, so the idea of bringing back some manufacturing, and leveling up the home-building capacity of the city feels very congruent with the spirit of Milwaukee.”

And panelized homes could be a cornerstone of affordable, energy-efficient housing nationwide if the sector was better organized and incentivized, RMI argues — a goal that Milwaukee could help further. 

“Local action always drives a message in a way that federal action doesn’t,” Toffoli said. “It will be even more important under the incoming presidential administration and Congress. Having this project getting started at the local level in an important Midwestern city is a way to help ensure that progress continues at some level, even if it’s less of a priority at the federal level.” 

Panel problems

Habitat for Humanity builds its own panels in its Milwaukee warehouse, and is working on an energy-efficient panelized design that it hope will yield the first net-zero affordable homes in 2025. Milwaukee has yet to select a developer for the DOE-funded program, but Milwaukee Habitat was a partner in the DOE grant and CEO Brian Sonderman said the organization is hopeful it will be chosen during an RFP process.

Single-family homes are typically “stick built” from the ground up, with 2×4 or similar boards forming a skeleton and then, one by one, walls. Panelized homes involve walls transported intact to the site. 

Milwaukee Habitat for Humanity often uses a hybrid method wherein walls are “stick built” laying on their side in the Habitat warehouse, and then brought to the site where volunteers help assemble the new house.

There are various other methods of making panels that don’t involve lumber, UWM Associate Professor Alexander Timmer explained, and making these models highly energy efficient is still an emerging and decentralized field.

“It’s the chicken-or-the-egg problem in some sense,” Timmer said, since component manufacturers don’t know if there’s a market for energy-efficient panelized homes, and developers don’t build the homes because few component suppliers exist.

Wall panels can involve two sheets of plywood with insulation in between, or a steel interior surrounded by rigid insulation, among other models.

“With 2x4s, any small crew can build a home,” said Timmer. “With panelized, you need a factory, specialized tools, specialized knowledge. The hope is we are graduating architects into the market who know these technologies and techniques, and can design them to high energy efficiency standards. The city needs architects and builders who want to do these things and feel comfortable doing them.”

Toffoli touted the benefits of net-zero homes beyond the carbon emissions and utility bill savings.

“There’s less draftiness, greater comfort throughout the whole home,” said Toffoli. “In addition to making the heater run less to warm the air, there’s a big comfort benefit and acoustic benefit,” with little noise or pollutants filtering into the well-sealed home.

“In the middle of a severe Wisconsin winter storm, [if] power goes out for everyone, you have a home that can basically ride through harsh conditions passively much better,” Toffoli added. 

Toffoli said examples in Pennsylvania and Massachusetts show panelized, highly energy-efficient homes can be built at costs not much greater than standard market panelized homes. A different design, including thinner studs and more insulation, means less heat or cold is transported from the outside in. Insulation and highly efficient windows cost more than market rate, but smaller appliances can be used because of the efficiency, helping to mitigate the cost increase. 

He said mass production of net-zero panelized homes is much more efficient and cost-effective than stick-built energy-efficient homes. 

“You don’t need to, every time, find a contractor who understands the proper sequence of control layers for a very high-performance wall,” Toffoli said. “It’s been done in part in a factory where they’re plugging and chugging on a design that’s been validated and repeated.”

The DOE grant includes $1 million for Milwaukee to incentivize construction of the panel factory, $40,000 each toward 25 homes, plus funds for administration and other costs. Shambarger said $40,000 per home will cover the construction cost difference between an affordable home that merely complies with building codes, and one that is net-zero – meeting federal standards with a highly efficient envelope, an electric heat pump and solar panels.

Shambarger noted that the city funding and business will not be enough to motivate a company to build a new factory in Milwaukee.  

“Any company is going to have to have a customer base” beyond the city orders, Shambarger said. “We’ll have to make sure other housing developers like the product that companies have, that it’s cost effective. One of the things we learned the first time around is most of the developers really didn’t understand how to do net-zero energy. We want to make sure the product we select fits within Milwaukee neighborhoods, will work in our climate, has buy-in from the community.”

Local jobs would be created by the factory, which is slated to be in Century City, the neighborhood with the most vacant manufacturing space.

“Overall with the climate and equity plan, we are trying to create good-paying jobs that people want,” Shambarger said. “That often means the trades. One of the things attractive about building housing components in a factory is it offers steady year-round employment, rather than having to go on unemployment for the winter,” as many building tradespeople do.

Creating Habitat

Sonderman said that in the past, Milwaukee Habitat has put solar on some homes, but little else specifically to lower energy costs.

“Clearly if there was a really substantial market for developers who were interested and willing to do this work, the reality is Habitat wouldn’t be the first call,” he said. “It’s something new. One of the things we’re looking forward to is sharing with our Habitat network in the state and other developers and builders, so we build some confidence this can be done efficiently and cost-effectively.”

Net-zero homes are not only a way to fight climate change, but an environmental and economic justice issue in predominantly Black neighborhoods scarred by redlining and disinvestment, where the majority of residents are renters, Sonderman added.

“Even for the individuals who don’t live in that home but live in the neighborhood, it breathes hope, it says that our neighborhood is being invested in,” Sonderman said. “That matters deeply for the residents of Lindsay Heights, Harambee, Midtown and elsewhere. To take a project like this and see it come to fruition has tremendous ripple effect in a positive way.”

Several other Habitat chapters nationwide are building net-zero homes, including in Colorado, Illinois and Oregon.

Milwaukee Habitat is planning to build 34 homes in 2025 and up to 60 homes annually by 2028. Sonderman said they will make as many as possible net-zero.

“We’re not in a capacity to be the full-scale factory [Shambarger] was envisioning,” he said. “But we believe we’ll be able to supply the walls we need to build dozens and dozens of net-zero homes in the future.”

Milwaukee plans to build net-zero modular homes for lower-income residents — but it’s not easy is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

A new contract between Kalamazoo, Michigan, and utility Consumers Energy signals a change in direction for the city’s clean energy strategy as it seeks to become carbon neutral by 2040. 

Solar was seen as a pillar of the city’s plans when it declared a climate emergency in 2019 and set a goal of zeroing out carbon emissions by 2040. After spending years exploring its options, though, the Michigan city is tempering a vision for rooftop solar in favor of large, more distant solar projects built and owned by the utility. It’s not alone either, with Grand Rapids, Milwaukee, Muskegon and other cities taking a similar approach.

“Folks want to see solar panels on parking lots and buildings, but there’s no way as a city we can accomplish our net-zero buildings just putting solar panels on a roof,” said Justin Gish, Kalamazoo’s sustainability planner. “Working with the utility seemed to make the most sense.” 

Initially there was skepticism, Gish said — “environmentalists tend to not trust utilities and large corporate entities” — but the math just didn’t work out for going it alone with rooftop solar.

The city’s largest power user, the wastewater treatment station, has a pumping house with a roof of only 225 square feet. Kalamazoo’s largest city-owned roof, at the public service station, is 26,000 square feet. Spending an estimated $750,000 to cover that with solar would only provide 14% of the power that building uses annually — a financial “non-starter,” he said.

So the city decided to partner with Consumers Energy, joining a solar subscription program wherein Kalamazoo will tell Consumers how much solar energy it wants, starting in 2028, and the utility will use funds from its subscription fee to construct new solar farms, like a 250 MW project Consumers is building in Muskegon. 

Under the 20-year contract, Kalamazoo will pay a set rate of 15.8 cents per kWh — 6.4 cents more than what it currently pays — for 43 million kWh of solar power per year. If electricity market rates rise, the city will save money, and Kalamazoo receives Renewable Energy Credits (RECs) to help meet its energy goals. 

The subscription is expected to eliminate about 80% of Kalamazoo’s emissions from electricity, Gish said. The electricity used to power streetlights and traffic signals couldn’t be covered since it is not metered. As the city acquires more electric vehicles — it currently has two — electricity demand may increase, but city leaders hope to offset any increases by improving energy efficiency of city buildings.  

Consumers Energy spokesperson Matt Johnson said the company relies “in part” on funds from customers specifically to build solar, and considers it a better deal for cities than building it themselves, “which would be more costly for them, and they have to do their own maintenance.”  

“We can do it in a more cost-effective way, we maintain it, they’re helping us fund it and do it in the right way, and those benefits get passed on to arguably everybody,” Johnson said. 

Grand Rapids, Michigan, joined the subscription program at the same time as Kalamazoo. Corporate customers including 7-Eleven, Walmart and General Motors are part of the same Consumers Energy solar subscription program, as is the state of Michigan.

Costs and benefits

“There’s a growing movement of cities trying to figure out solar — ‘Yes we want to do this, it could save us money over time, but the cost is prohibitive,’” said John Farrell, co-director of the Institute for Local Self-Reliance. 

Until the Inflation Reduction Act, cities couldn’t directly access federal tax credits. The direct-pay incentives under the IRA have simplified financing, Farrell said, but cities still face other financial and logistical barriers, such as whether they have sufficient rooftop space.  

Advocates acknowledge deals with utilities may be the most practical way for budget-strapped cities to move the needle on clean energy, but they emphasize that cities should also strive to develop their own solar, and question whether utilities should charge more for clean power that is increasingly a cheaper option than fossil fuels.

“Our position is rooftop and distributed generation is best — it’s best for the customers, in this case the cities; it’s best for the grid, because you’re putting those resources directly on the grid where it’s needed most; and it’s best for the planet because it can deploy a lot faster,” said John Delurey, Midwest deputy director of the advocacy group Vote Solar. “I believe customers in general and perhaps cities in particular should exhaust all resources and opportunities for distributed generation before they start to explore utility-scale resources. It’s the lowest hanging fruit and very likely to provide the most bang for their buck.”

Utility-scale solar is more cost-effective per kilowatt, but Delurey notes that when a public building is large enough for solar, “you are putting that generation directly on load, you’re consuming onsite. Anything that is concurrent consumption or paired with a battery, you are getting the full retail value of that energy. That is a feature you can’t really beat no matter how good the contract is with some utility-scale projects that are farther away.”

Delurey also noted that Michigan law mandates all energy be from clean sources by 2040; and 50% by 2030. That means Consumers needs to be building or buying renewable power, whether or not customers pay extra for it. 

“So there are diminishing returns [to a subscription deal] at that point,” Delurey said. “You better be getting a price benefit, because the power on their grid would be clean anyways.” 

“Some folks are asking ‘Why do anything now? Just wait until Consumers cleans up the grid,’” Gish acknowledged. “But our purchase shows we have skin in the game.” 

A complement to rooftop

In 2009, Milwaukee adopted a goal of powering 25% of city operations — excluding waterworks — with solar by 2025. The city’s Climate and Equity Plan adopted in 2023 also enshrined that goal. 

For a decade, Milwaukee has been battling We Energies over the city’s plan to install rooftop solar on City Hall and other buildings through a third-party owner, Eagle Point Solar. The city sought the arrangement — common in many states — to tap federal tax incentives that a nonprofit public entity couldn’t reap. But We Energies argued that third party ownership would mean Eagle Point would be acting as a utility and infringing on We Energies’ territory. A lawsuit over Milwaukee’s plans with Eagle Point is still pending.

In 2018, We Energies launched a pilot solar program in Milwaukee known by critics as “rent a roof,” in which the utility leased rooftop space for its own solar arrays. Advocates and Milwaukee officials opposed the program, arguing that it encouraged the utility to suppress the private market or publicly-owned solar. In 2023, the state Public Service Commission denied the utility’s request to expand the program.

Wisconsin Citizens Utility Board opposed the rent-a-roof arrangement since it passed costs they viewed as unfair on to ratepayers. But Wisconsin CUB executive director Tom Content said the city’s current partnership with We Energies is different, since it is just the city, not ratepayers, footing the cost for solar that helps the city meet its goals.

Milwaukee is paying about $84,000 extra per year for We Energies to build solar farms on a city landfill near the airport and outside the city limits in the town of Caledonia. The deal includes a requirement that We Energies hire underemployed or unemployed Milwaukee residents.

The Caledonia project is nearly complete, and will provide over 11 million kWh of energy annually, “enough to make 57 municipal police stations, fire stations, and health clinics 100% renewable electricity,” said Milwaukee Environmental Collaboration Office director Erick Shambarger. 

The landfill project is slated to break ground in 2025. The two arrays will total 11 MW and provide enough power for 83 city buildings, including City Hall – where Milwaukee had hoped to do the rooftop array with Eagle Point. 

Meanwhile Milwaukee is building its own rooftop solar on the Martin Luther King Jr. library and later other public buildings, and Shambarger said they will apply for direct pay tax credits made possible by the Inflation Reduction Act — basically eliminating the need for a third-party agreement.

“Utility-scale is the complement to rooftop,” said Shambarger. “They own it and maintain it, we get the RECs. It worked out pretty well. If you think about it from a big picture standpoint, to now have the utility offer a big customer like the city an option to source their power from renewable energy — that didn’t exist five years ago. If you were a big customer in Wisconsin five years ago, you really had no option except for buying RECs from who knows where. We worked hard with them to make sure we could see our renewable energy being built.”

We Energies already owns a smaller 2.25 MW solar farm on the same landfill, under a similar arrangement. Building solar on the landfill is less efficient than other types of land, since special mounting is needed to avoid puncturing the landfill’s clay cap, and the panels can’t turn to follow the sun. But Shambarger said the sacrifice is worth it to have solar within the city limits, on land useful for little else.

“We do think it’s important to have some of this where people can see it and understand it,” he said. “We also have the workforce requirements, it’s nice to have it close to home for our local workers.”

Madison is also pursuing a mix of city-owned distributed solar and utility-scale partnerships. 

On Earth Day 2024, Madison announced it has installed 2 MW of solar on 38 city rooftops. But a utility-scale solar partnership with utility MGE is also crucial to the goal of 100% clean energy for city operations by 2030. Through MGE’s Renewable Energy Rider program, Madison helped pay for the 8 MW Hermsdorf Solar Fields on a city landfill, with 5 MW devoted to city operations and 3 MW devoted to the school district. The 53-acre project went online in 2022.

Farrell said such “all of the above” approaches are ideal.

“The lesson we’ve seen generally is the more any entity can directly own the solar project, the more financial benefit you’ll get,” he said. “Ownership comes with privileges, and with risks. 

“Energy is in addition to a lot of other challenging issues that cities have to work on. The gold standard is solar on a couple public buildings with battery storage, so these are resiliency places if the grid goes down.”

Correction: Covering Kalamazoo’s public service station roof with solar panels would provide an estimated 14% of power used by that building. An earlier version of this story mischaracterized the number.

In Michigan and Wisconsin, cities are finding rooftops alone may not achieve solar energy goals  is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Community and environmental justice advocates say the Biden administration is failing to deliver promised transparency and public engagement around its $7 billion clean hydrogen hub initiative.

“Engagement isn’t merely leading people into a process that’s going to happen with or without them,” said Tom Torres, hydrogen program director for the Ohio River Valley Institute, a nonprofit serving one of the regions where federally funded partnerships are trying to lay the groundwork for new local hydrogen economies. “It means meaningfully involving people in the decisions about the project.”

The U.S. Department of Energy announced funding in October 2023 for seven regional clean hydrogen hubs — clusters of interconnected projects meant to kickstart production of the fuel with little or no greenhouse gas emissions. Since then, the department has held online briefings and virtual listening sessions for each hub, but advocates say they are not getting the kind of information necessary to assess who will be impacted by the projects and how.

Torres and others say they want more than just dots on a map. They want to know how hydrogen will be produced, how it will be used, and how it will get to end users. For projects that depend on carbon capture, they want to know how and where the carbon will be captured, transported and stored. And once the specifics are known, they want a chance to have meaningful input on the final projects.

Spokespeople for the Department of Energy and regional hubs said the answers to those questions are still being worked out and that more engagement is on the horizon.  Advocates are increasingly frustrated and fear that community input will come too late to affect how the hubs are developed.

“It doesn’t make sense … on one hand to say there’s not enough on paper to tell the public about, but on the other hand there is enough to allocate almost $1 billion for these companies,” Torres said.

Are events just ‘checking a box’?

When burned as a fuel source, hydrogen does not emit carbon dioxide, but its production today almost always comes from fossil fuels. Some see a potential for hydrogen to replace natural gas in certain hard-to-electrify sectors such as industry or heavy duty transportation, but the benefits for addressing climate change hinge on whether it can be produced cleanly and at scale.

The Biden administration’s hydrogen hub program, part of the 2021 Bipartisan Infrastructure Law, aims to ramp up production of hydrogen made with low-carbon energy, including renewables, nuclear power, and fossil fuels paired with carbon capture. 

“It is literally like building the natural gas infrastructure that we have all over the place again for hydrogen,” said Shawn Bennett, energy and resilience manager for Battelle, the project manager for the Appalachian Regional Hydrogen Hub, ARCH2, which includes projects for Ohio, West Virginia and Pennsylvania. A majority of its projects will use steam methane reforming to make hydrogen from natural gas, along with carbon capture and storage. Other projects in the hub plan to make hydrogen from waste gases or from electrolysis, which uses energy to split water molecules. 

In May, dozens of groups urged the Department of Energy to suspend funding discussions for the ARCH2 project until the public receives detailed information beyond general maps and short project descriptions. On July 31 the Department of Energy formally committed the first $30 million of federal funding to ARCH2, with a total of up to $925 million to be spent over the next decade or so.

Last month, the Department of Energy committed up to $1 billion for the Midwest Alliance for Clean Hydrogen, MachH2, which spans Illinois, Indiana, Michigan and Iowa and plans to produce hydrogen from a mix of nuclear power, wind energy and natural gas. The department will hold a December 9 briefing on MachH2.

In response to the Energy News Network’s questions about community groups’ complaints about a lack of outreach, a Department of Energy spokesperson provided a statement saying it “has been actively engaged with these communities in support of the economic playbook” of the Biden-Harris administration.

The ARCH2 project held a community outreach session in West Virginia in November, and additional meetings will be held in Ohio and Pennsylvania early next year, Bennett said. Some community group members protested outside at the West Virginia session but then came inside for a good discussion, he added.

Torres said there was no general presentation at the West Virginia meeting, and company representatives were present for only a handful of the hub’s projects. Even then, project information was still sparse. 

“It wasn’t an opportunity for people’s voices to be heard,” he said. “What is the value of these events other than checking a box for these companies?”

Advocacy groups focusing on the MachH2 project said months went by without getting updates or details. Then last month, they got less than 24 hours’ notice for a briefing with general descriptions about the MachH2 hub projects.

During that session, representatives for the Department of Energy said a decision on the hub’s funding commitment would come soon, “probably next week sometime,” said Susan Thomas, the legislative and policy director and communications manager for Just Transition Northwest Indiana. Minutes after the November 20 session ended, the Department of Energy announced the MachH2 funding commitment. 

“Our jaws were on the table,” Thomas said.

Details remain to be worked out

Groups have been trying to get answers from the Department of Energy for more than a year, said Chris Chyung, executive director of Indiana Conservation Voters. In his view, the agency’s approach “is just flouting the law.” According to the Department of Energy’s website, engagement with communities and labor is a key principle required in hubs’ community benefits plans, which are part of hubs’ contractual obligations for funding.

Community groups learned in the November 20 briefing that the MachH2 community engagement would not address concerns related to any pipelines associated with the hub. Instead, those would be handled by a separate office within the Department of Energy. 

But a pipeline for northwestern Indiana “is absolutely part and parcel of [a] dirty hydrogen project that is part of MachH2,” and the community should get a say on it, said Lauren Piette, an attorney with Earthjustice, which does not consider hydrogen made with natural gas to be climate-friendly, even with carbon capture.

The Department of Energy spokesperson did not respond to the Energy News Network’s question about how community benefits for hub projects can fully be assessed if they don’t include consideration of issues and input related to necessary pipelines.

Representatives of the MachH2 and ARCH2 hubs who spoke at an Ohio Fuel Cell & Hydrogen Consortium program last month said they couldn’t practically engage in community outreach until funding commitments had been negotiated with the Department of Energy. Until then, it wasn’t certain whether each hub would move forward.

Also, as a practical matter, “there was no budget for these things,” Bennett said. Details for each hub’s projects are still being worked out, and ARCH2 is still trying to add additional project partners.

Even then, details for projects won’t be finalized until review under the National Environmental Policy Act, according to Neil Banwart, who is the chief integration officer for the MachH2 hub and also the managing director for hydrogen at Energy Systems Network. 

“It’s not a certainty that all of the projects will get built in the locations that we shared on a map,” he said.

Chyung said he felt the comments about funding were “a complete dodge on behalf of these extremely wealthy national corporations that have said since 2023 they were eager to get started on community outreach.”

Advocates frustrated by lack of transparency, engagement on regional hydrogen hub projects is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Charlotte, North Carolina, may soon get access to a new tool to deploy in its push toward 100% clean power: data.

The Tar Heel state’s largest city aims to power all government operations with carbon-free electricity by the end of the decade, including the city-owned Charlotte-Douglas International Airport, one of the busiest in the world. 

But the hub is a big question mark for the city’s climate target. Officials don’t actually know how much energy it uses — or how much renewable energy they need to offset it — because the utility bills for the five-terminal airport are paid by dozens of individual customers, from Cinnabon to Jamba Juice to airline club lounges.

Now, after a decade of urging by Charlotte and others, Duke Energy has a proposal to change that: an eight-page plan for improved data access that has sign-off from the North Carolina Sustainable Energy Association; Public Staff, the state-sanctioned customer advocate; and Dominion Energy, which serves the northeast corner of the state.

Filed last month with regulators for approval, Duke’s proposed rules could have wide application, said Ethan Blumenthal, regulatory counsel for the North Carolina Sustainable Energy Association. 

“For municipalities applying for federal grants, large customers pursuing energy efficiency, and homeowners and solar companies that are trying to right-size solar installations,” Blumenthal said, “this access to data is essential.”

Avoiding a ‘laborious process’

The Charlotte airport is a prime example of one hurdle facing local communities with climate goals. Today, getting total energy usage data for government-owned buildings with multiple meters means reaching out to individual tenants to get permission to access their accounts.  

“It would be a very laborious process to do that at the airport and anywhere else we have tenants,” said Aaron Tauber, Charlotte’s sustainability analyst.

The problem extends to private building owners who aim to reduce their carbon footprints or improve efficiency but don’t have insight into their renters’ energy consumption. Honeywell, for instance, is a partner in the city’s “Power Down the Crown” initiative, whereby building managers look to reduce energy use by optimizing efficiency. 

“They don’t own all of the data,” Tauber said. “They have tenants in their properties. So, they don’t have visibility to the entire building’s energy use.” 

The new rule will allow a large user, from Honeywell to Charlotte, to access aggregated data for a large building with multiple tenants by request to Duke, so long as at least 15 individual accounts are involved, and none consumes more than 15% of the building’s energy use. 

“Being a larger city, we do have a lot of large buildings with multiple tenants,” said Tauber. “I’m just really excited for these building owners to really — for the first time — gain an understanding of how their buildings are using energy.”

That understanding, he said, is critical for commercial properties to access a new law that allows them to borrow public money for energy efficiency upgrades and pay it back on their property tax bills.  

“Being able to unlock a financing mechanism based on this data will really go a long way for the city to be able to meet our strategic energy action goal of being a low-carbon community,” said Tauber.

Not just for big buildings

The data access rule also applies to a census block, zip code, or other area with at least 15 accounts, which will help local governments meet community-wide climate goals. 

“You can use the aggregated data to make good decisions for program design, and where you might want to target,” said Ann Livingston, senior executive and director of programs with the Southeast Sustainability Directors Network. “You can assess: is this particular block or neighborhood really using a lot more energy per house per square foot than others?” 

Durham County, for instance, together with neighboring Granville and Orange counties, has a $1.5 million federal grant to help low-income homeowners cut their energy use through weatherization and other upgrades.  

“We want to focus in areas where there’s a higher energy use or higher energy burden,” said Tobin Freid, the county’s sustainability manager. “We’d like information at a more granular level than just the county.”

If the new Duke rule is approved, it will also help county officials better tailor the program to individual households and assess its impacts. The proposal would ease the approval process for allowing third-party access to data and ensure that at least two years of prior energy use is included.

“For every home that we work on, we would need historic data to see: what was your energy use before?” Freid said.

Both the aggregated data and third-party access provisions will also be critical for federal programs like Solar for All, aimed at deploying rooftop solar on low-income households. 

“Often, those federal funding opportunities require you to assess and report on energy impact,” said Livingston. “Solar for All will be a very clear example of this, where you need to report energy savings for individual participants.”

Growing interest in local impact

Apart from the sustainability goals, government officials also have a commitment to manage public dollars efficiently, Livingston noted. That’s especially pertinent for large energy users like Durham County, who may pay a higher “demand charge” for a single 30-minute spike in energy use. Large customers with net-metered solar power also pay more during times of peak demand. 

The proposed rules will help solve these challenges by allowing third parties access to machine-readable, easily analyzed data for customers of all sizes. The format would essentially meet national “Green Button” standards, one familiar to the many companies around the country dedicated to managing building energy performance.

The Green Button initiative, a project of the U.S. Department of Energy that originated in Canada, has been around for over a decade – about as long as the Sustainable Energy Association has been advocating for improved customer data access, along with counties like Durham.

But the issue seems to have gained new steam in recent months, as local governments look to take advantage of new federal grants and laws aimed at reducing climate pollution.

What’s more, Blumenthal said, Duke has pledged to implement the rules within 18 months of their approval and help expedite any data requests in the interim.

“There is a commitment to doing everything they can, essentially, to provide data for federal funding purposes up until [the proposal] is fully implemented,” Blumenthal said. “A commitment to try to bridge the gap.”

Asked what prompted the agreement with Blumenthal’s group and others after all this time, Duke spokesperson Logan Stewart said over email: 

“A lot has changed in the last decade from a technology, cybersecurity, and customer engagement perspective that made this stipulation possible. Duke Energy is always looking for ways to collaborate with stakeholders to achieve outcomes that benefit customers.”

Duke Energy data access rules poised to help North Carolina communities meet climate goals is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

A trailblazing regional greenhouse gas partnership on the East Coast is considering possible changes or expansion that would allow it to keep building on its success — and the stakes grew higher last month with the reelection of Donald Trump.

The 11-state Regional Greenhouse Gas Initiative, established in 2005, is the country’s first regional cap-and-invest system for reducing carbon emissions from power generation. Since 2021, administrators have been conducting a program review, analyzing its performance since the last review in 2017 and weighing potential adjustments to make sure it continues to deliver benefits to member states.

The role of such programs is more crucial as Trump’s pledges to roll back federal climate action leaves it up to cities, states, and the private sector to maintain the country’s momentum on clean energy over the next four years. In RGGI, as the regional initiative is known, states have a potential model for scaling their impact through collaboration. 

“RGGI has not only been an effective climate policy, it’s been an extraordinary example of how states can work together on common goals,” said Daniel Sosland, president of climate and energy nonprofit Acadia Center. “It is a major vehicle for climate policy now in the states, more than it might have seemed before the election.” 

How RGGI works

RGGI sets a cap for total power plant carbon emissions among member states. Individual generators must then buy allowances from the state, up to the total cap, for each ton of carbon dioxide they produce in a year. The cap lowers over time, forcing power plants to either reduce emissions or pay more to buy allowances from a shrinking pool.

States then reinvest the proceeds from these auctions into programs that further reduce emissions and help energy customers, including energy efficiency initiatives, direct bill assistance, and renewable energy projects. Since 2008, RGGI has generated $8.3 billion for participating states, and carbon dioxide emissions from power generation in the nine states that have consistently participated fell by about half between 2008 and 2021, a considerably faster rate than the rest of the country. 

“It has really thrived and been really effective across multiple administrations,” said Jackson Morris, state power sector director with the Natural Resources Defense Council. “RGGI is a winning model. It’s not theoretical — we’ve got numbers.”

Currently, Connecticut, Delaware, Maine, Maryland, Massachusetts, New Hampshire, New Jersey, New York, Pennsylvania, Rhode Island, and Vermont are part of the program. Virginia joined RGGI in 2021, but in 2023 Gov. Glenn Youngkin repealed the state’s participation, a move immediately challenged in court; a judge ruled last month that the governor lacked the authority to withdraw the state from initiative, though a spokesman for the governor has declared the state’s intention to appeal. 

There is widespread agreement that RGGI will endure despite likely federal hostility to climate measures. There was no attempt to take direct action against it during Trump’s first term, nor has there been any concerted industry opposition, said Conservation Law Foundation president Bradley Campbell, who was involved in the founding of RGGI when he was commissioner of the New Jersey Department of Environmental Protection.

Supporters also note that the program has historically had broad bipartisan support: Participating states have been led through the years by both Republican and Democratic governors and legislatures. 

Politics has had some influence over the years, though only at the margins. New Jersey, a founding member of RGGI, left in 2011 when Chris Christie was governor, but returned in 2020 following an executive order from his successor. Pennsylvania joined in 2022 through an executive order from the governor, but its participation is now being challenged in court. 

Still, RGGI’s foundations are solid and will remain so, experts said. 

“The basic infrastructure has weathered the political winds over the decades,” Campbell said.

Looking forward

Nonetheless, RGGI will need to make some carefully thought-out program design decisions during its current review to make an impact in the face of falling federal support for decarbonization. 

One question under consideration is whether to maintain the existing trajectory for the overall emissions cap for the program — a reduction of 30% between 2020 and 2030, then holding steady thereafter — or to continue lowering the limit after 2030. 

The RGGI states are also contemplating a possible change to the compliance schedule that would require power generators to acquire allowances worth 100% of their carbon emissions each year, and certify compliance annually. The current system calls for certification every three years, and only mandates allowances equivalent to half of carbon emissions for the first two years of each period.

The program is looking for ways to appeal to potential new participant states that have less aggressive decarbonization goals than current member states without watering down the program’s overall impact on decarbonization, said Acadia Center policy analyst Paola Tamayo. Acadia suggested possible program mechanisms such as giving proportionately more allowances to states with more stringent emissions targets to incentivize tighter limits.

“At this point it is critical for states to maintain a high level of ambition when it comes to programs like RGGI,” Tamayo said. “There are different mechanisms that they can implement to accommodate other states.”

The program review is expected to yield a model rule some time over the winter, though updates may be made into the spring as the RGGI states receive and consider feedback on how to accommodate potential new participants.  

States will also need to maintain and strengthen their own climate policies to magnify the impact of RGGI, Campbell said. He pointed to Massachusetts, where Gov. Maura Healey needs to show “bolder leadership,” he said, and Maine and Vermont, where the Conservation Law Foundation has filed lawsuits in an attempt to compel the states to meet their own carbon reduction deadlines. 

“It’s especially important that the states that have strong emissions reduction mandates speed up the implementation of their climate laws,” he said. “State leadership on these issues is going to be more important than ever.”

As climate focus shifts to states, East Coast partnership offers model for multi-state collaboration is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

A top executive with Minnesota’s largest utility says data center growth will not prevent it from meeting the state’s 100% clean electricity law, but it may extend the life of natural gas power plants into the next decade.

“As we take all of that coal off the system — even if you didn’t add data centers into the mix — I think we may have been looking to extend some gas (contracts) on our system to get us through a portion of the 2030s,” said Ryan Long, president of Xcel Energy’s division serving Minnesota and the Dakotas. “Adding data centers could increase the likelihood of that, to be perfectly honest.”

Long made the comments at a Minnesota Public Utilities Commission conference this fall exploring the potential impact of data centers on the state’s 2040 clean electricity mandate.

The expansion of power-hungry data centers, driven by artificial intelligence, has caused anxiety across the country among utility planners and regulators. The trend is moving the goalposts for states’ clean electricity targets and raising questions about whether clean energy capacity can keep up with demand as society also tries to electrify transportation and building heat.

Minnesota PUC commissioner Joe Sullivan organized last month’s conference in response to multiple new data centers projects, including a $700 million facility by Facebook’s parent company Meta that’s under construction in suburban Rosemount. Microsoft and Amazon have each acquired property near a retiring Xcel coal plant in central Minnesota. 

“We need to ensure that our system is able to serve these companies if they come,” Sullivan said, “and that it can serve them with clean resources consistent with state law.” 

Alongside concerns about whether clean energy can keep up with new electricity demand, there’s also an emerging view that data centers — if properly regulated — could become grid assets that help accelerate the transition to carbon-free power. Several stakeholders at the Oct. 31 event shared that view, including Xcel’s regional president.

A 100-megawatt data center could generate as much as $64 million in annual revenue for Xcel, enough to help temper rate increases or cover the cost of other projects on the system, Long said. He said the company wants to attract 1.3 gigawatts worth of data centers to its territory by 2032, and it thinks it can absorb all of that demand without harming progress toward its 2040 clean energy requirement.

Long said data center expansion will not change the company’s plans to close all of its remaining coal-fired power plants by 2040, but it may cause them to try to keep gas plans operating longer. Ultimately, meeting the needs of data centers will require more renewable generation, battery storage, and grid-enhancing technology, but rising costs and supply chain issues have slowed deployment of those solutions.

Other utilities echoed that optimism. Julie Pierce, Minnesota Power’s vice president for strategy and planning said the company has experience serving large customers such as mines in northeastern Minnesota and would be ready to serve data centers. Great River Energy’s resource planning director Zachary Ruzycki said the generation and transmission cooperative “has a lot of arrows in its quiver” to accommodate data centers.

Ruzycki noted, too, that much of the interest it has received from data center developers is because of the state’s commitment to clean energy. Many large data center operators have made corporate commitments to power them on 100% carbon-free electricity, whether from renewables or nuclear power.

Pete Wyckoff, deputy commissioner for energy at the Minnesota Department of Commerce, expressed doubts about the ability to meet unchecked demand from data centers. Even with the state’s recent permitting reforms, utilities are unlikely to be able to deliver “power of any sort — much less clean power — in the size and timeframes that data centers are likely to request.”

He sees hydrogen, long-duration batteries, carbon capture, and advanced nuclear among the solutions that will eventually be needed, but in the short-term the grid could serve more data centers with investments in transmission upgrades, virtual power plants, and other demand response programs.

“These solutions can be deployed faster and cheaper than building all new transmission and large clean energy facilities, though we’ll need those, too,” Wyckoff said.

Aaron Tinjum, director of energy policy and regulatory affairs for the Data Center Coalition, said data centers provide the computing power for things like smart meters, demand response, and other grid technologies. The national trade group represents the country’s largest technology and data center companies.

“We can’t simply view data centers as a significant consumer of energy if they’re all helping us become more efficient, and helping us save on our utility bills,” Tinjum said. 

He also pointed to data centers’ role in driving clean energy development. A recent report from S&P Global Commodity Insights found that data centers account for half of all U.S. corporate clean energy procurement. 

The true impact of data centers on emissions and the grid is complicated, though. Meta, which participated in the recent Minnesota conference, says it matches all of its annual electricity use with renewable energy, but environmental groups say there is evidence that its data centers are increasing fossil fuel use and emissions in the local markets where they are built.

Amelia Vohs, climate program director with the Minnesota Center for Environmental Advocacy, raised concerns at the conference about whether data center growth will make it harder to electrify transportation and heating. She pointed to neighboring Wisconsin, where utilities are proposing to build new gas plants to power data centers.

“This commission and the stakeholders here today have all done a ton of work and made great progress in decarbonizing the electric sector in our state,” Vohs said. “I worry about possibly rolling that back if we all of a sudden have a large load that needs to be served with fossil fuels, or [require] a fossil fuel backup.” 

The Minnesota Attorney General’s Office argued that state regulators need to scrutinize data center deals to make sure developers are paying the total cost of their impact on the system, including additional regulatory, operational and maintenance work that might be required on the grid.

In an interview, Sullivan said he was impressed by tech companies’ interest in having data centers in Minnesota because of the 2040 net zero goal, not despite it. They want to buy electricity from Minnesota utilities rather than build their own power systems or locate in neighboring states, he added, and the October meeting left him confident that “we can deal with this.”

Xcel Energy says data center growth won’t get in the way of 2040 clean energy target in Minnesota is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

A solar-powered microgrid project backed with funding from the Biden administration aims to reduce energy burdens and provide backup power to a tiny northern Minnesota tribal community.

The Pine Point Resilience Hub would serve an elementary school and community center in Pine Point, an Anishinaabe village of about 330 people on the White Earth Reservation.

In June, the project was selected to receive $1.75 million from the U.S. Department of Energy’s Energy Storage for Social Equity (ES4SE) Program, which helps underserved and frontline communities leverage energy storage to make electricity more affordable and reliable. It’s part of a slew of Biden administration funding related to grid resilience and energy equity that has spurred several tribal microgrid projects across the country.

The developers, locally owned 8th Fire Solar and San Francisco-based 10Power, hope to finish the project next year, and have also secured funding from Minnesota’s Solar for Schools program and foundation grants but said they still need to raise about $1 million. They’re also counting on receiving about $1.5 million in federal tax credits, which face an uncertain future with the incoming Trump administration. 

“The idea of the microgrid is to help with infrastructure,” said Gwe Gasco, a member of the White Earth Nation and the program coordinator with 8th Fire Solar, a thermal solar company based on the reservation.

Tribal communities were largely bypassed during the massive, federally funded push under the Rural Electrification Act of 1936 to bring electricity to remote rural areas of the country. As a result, grid infrastructure on many reservations remains insufficient to this day, with an estimated 1 in 7 Native American households on reservations lacking electricity connections, and many more contending with unreliable service.

On top of higher-than-average electric reliability issues, tribal communities also generally pay higher rates for electricity and face higher energy burdens due to poverty and substandard housing.

On the White Earth Reservation, these challenges are most pronounced in Pine Point, where one-third of residents live in poverty. Gasco said the area is among the first to suffer from outages, with eleven occurring over the last five years, according to the Itasca-Mantrap Electric Cooperative that serves the area.

The Pine Point Resilience Hub project will build on an existing 21-kilowatt solar array, adding another 500 kilowatts of solar capacity along with a 2.76 megawatt-hour battery storage system, enough to provide about 12 hours worth of backup power for residents to be able to charge cell phones, power medical equipment, or stay warm in the event of a power outage.

Gasco said the microgrid could be especially important in the winter, given the area’s “brutally cold” weather and reliance on electric heat. They also hope it will reduce utility costs, though they are still negotiating with the local electric co-op on rates for power the system sends and receives from the utility’s grid. Itasca-Mantrap President and CEO Christine Fox said it doesn’t set net metering rates, which are determined by its electricity supplier.

The project developers hope to qualify for additional federal tax credits by using equipment largely produced in the U.S., including Minnesota-built Heliene solar panels, inverters made in Massachusetts, and Ohio-produced solar racks.

The developers have partnered with the Pine Point School District, which plans to incorporate the microgrid into an Ojibwe-language curriculum on renewable energy. A monitoring interface will allow students to see real-time data in the classroom.

“It’s powerful to me that this (project) is at a school where we’re hoping to inspire the next generation of kids,” said Sandra Kwak, CEO and founder of 10Power, a for-profit company that specializes in developing renewable energy projects in tribal communities.

Corey Orehek, senior business developer for Ziegler Energy Solutions, which has been hired to do the installation, said they plan to work with a local community college to train students for solar jobs. 

“One of the things that we want to drive in this is workforce development,” Orehek said. “We want to leave something that’s not only a project that’ll last 30 years but provide the training and experience for community members to either start their own energy companies or become contractors in the clean energy workforce.”

The resilience hub is the second such project announced by a Minnesota tribe in just recent months. The Red Lake Nation received $3.15 million from the U.S. Department of Energy’s Local Government Energy Program in late September for a behind-the-meter microgrid project at a secondary school.

The Shakopee Mdewakanton Sioux Community is also working with Minnesota Valley Electric Cooperative to build a $9 million microgrid with U.S. Department of Energy funding. The electric cooperative will install a 4 megawatt-hour energy storage system and add a 1 megawatt solar system at the reservation in suburban Minneapolis.

It’s unclear whether federal funding for such projects will continue in President-elect Trump’s second term, but for now tribal energy advocates see microgrids as a good solution to both lower energy burdens and improve reliability.   

“This is a great opportunity to create a success story in terms of leveraging cutting-edge technology, being able to help frontline communities, and for tribes and co-ops to work together,” Kwak said.

Minnesota tribe’s solar-powered resilience hub would provide cost savings, backup power to local community is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Mark Fleming has a prediction for those terrified about the impact of a second Trump administration on the clean energy transition: “It’s going to work out better than folks think.”

Fleming is head of Conservatives for Clean Energy, a Raleigh-based nonprofit that brings together lobbyists, consultants, and politicians on the right who support clean energy. The group formed a decade ago, not long before Trump’s first term began, and is now active in six Southeast states. On Tuesday, together with the Chambers for Innovation and Clean Energy, it held its biennial luncheon in downtown Raleigh. 

Coming just two weeks after an election most advocates see as a major setback for federal clean energy policy, the Raleigh event was not unlike past affairs, with congenial vibes, a half dozen awards to politicians and businesses, and presentation from leading Republican consultants assessing the political salience of clean energy.

“It was an election about the economy and immigration,” explained Paul Shumaker, one such pollster and a fixture at these gatherings. “Clean energy is never going to be the issue.”

Trump and his hostile, mostly fact-free rants on the campaign trail about wind energy and the climate crisis got little mention during the formal presentations. Side conversations showed conservatives seemed relatively unconcerned about the future president’s tirades and threats.

“Governing is different than campaigning,” Fleming said. 

He and others believe much of Trump’s rhetoric was tossed as red meat to his base of supporters and won’t get meaningful follow-through. On technologies such as offshore wind — which the incoming president frequently lambasts — perhaps the administration and even the man himself can be convinced of its economic benefits, attendees suggested. 

Virginia Gov. Glenn Youngkin, a Republican who supports offshore wind in the commonwealth, “will be at the top of the list of conservative policy makers in terms of encouraging the Trump administration to look at the positives on offshore wind,” Fleming said. “It makes long term economic sense, but there’s going to be some education there.”

Indeed, to help his re-election chances, Trump did flip his stance on offshore drilling four years ago — at least for the Southern Atlantic — after input from Republicans in Southeast states who oppose the practice.

Despite Trump’s vague promise to curtail the Inflation Reduction Act, Fleming believes congressional Republicans will preserve most of Biden’s signature climate law because of its benefits in rural areas.

Nine new projects announced in North Carolina the year after the measure’s passage, from lithium processing to vehicle-charging equipment plants, will spur tens of thousands of jobs and add $10 billion to the state’s GDP, the clean economy group E2 found.

Such data should be fodder for members of Congress like Sen. Thom Tillis, North Carolina’s senior U.S. senator and a Republican, to fight to keep most of the Inflation Reduction Act’s provisions.

“He has been such a thoughtful leader on energy issues,” Fleming said of Tillis. “He’s going to be a key decision maker in the U.S. Senate on these clean energy issues moving forward.” 

‘We won’t agree on everything’ 

Jason Saine, a Lincoln County Republican who served more than a dozen years in the North Carolina House and now works as a lobbyist, was among the luncheon’s awardees. He says Trump’s rhetoric is just part of politics. 

“Good science and good facts will rule the day, but in the meantime, we’ll suffer through a lot of rhetoric,” he said.

Like some of his conservative colleagues who focus on federal policy, Fleming hopes the closely divided Congress will have new reason to enact reforms to the permitting process that will speed approval of clean energy as well as fossil fuel projects.

And though he’s confident that much of the Inflation Reduction Act will survive, Fleming believes Congress will trim it — a “scalpel rather than a sledgehammer” approach. 

Saine agrees. “It can always be recreated in a different format and voted on again,” he said. “What’s dead today is never dead tomorrow.”

One item in the climate law that’s ripe for repeal is the $7,500 tax credit for electric vehicles, Fleming said. That incentive is spurring plenty of economic development in rural areas in the form of EV and battery factories, but it’s perceived as benefiting only urban folk. 

“The administration will want wins,” Fleming insisted. “We won’t agree on everything. But I think we’ll have opportunities to work together to move the economy forward and move the clean energy cause forward in D.C.”

No matter what, most of the luncheon attendees remained focused on incremental reforms in North Carolina — where the power dynamics are largely unchanged after Nov. 5. Trump won the state, but Democrat Josh Stein trounced a scandal-plagued Republican to win the governor’s race. The GOP continues to control a heavily gerrymandered legislature and is just one vote shy of a veto-proof majority in the House. 

Still, as “Trump II” approaches, Fleming acknowledged Conservatives for Clean Energy has an important role to play.

“It’s going to be better than folks think,” he repeated. “But the onus will be on all of us to make it happen. Now, groups like ours are more needed than ever. That thought leadership on these issues will be on the right. It’s not going to be from our friends on the left.”

In North Carolina, conservative clean energy supporters don’t think Trump will follow through on threats is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

Dearborn, Michigan, was at the heart of auto industry innovation during the days of the Model T Ford. 

Now clean energy and environmental justice advocates are proposing that the city play a lead role in greening the auto industry, through a transformation of the Dearborn Works steel mill to “green steel” — a steelmaking process powered by hydrogen and renewable energy with drastically lower emissions than a traditional blast furnace. 

The blast furnace at Dearborn Works is due for relining in 2027, at an estimated cost of $470 million. Advocates argue that instead of prolonging the blast furnace’s life, its owner, Cleveland Cliffs, should invest another $2 billion dollars and convert the mill to Direct Reduced Iron (DRI) technology powered by green hydrogen (hydrogen produced with renewable energy).

An October report by Dr. Elizabeth Boatman of the firm 5 Lakes Energy examines the economics and logistics of such a conversion, and argues that demand for cleaner steel is likely to grow as auto companies and other global industries seek to lower their greenhouse gas footprints. Starting in 2026, steel importers to the European Union will need to make payments to offset emissions associated with steel production.

Worldwide, the auto industry is the second largest consumer of steel after construction, and “being able to pass on the price of a ‘green steel premium’ to its end consumers, the automotive industry is uniquely positioned to create demand for green steel without having to rely on public subsidies,” the European Union think tank CEPS said in a recent publication.

“This is a great chance for the state to step in now and ensure this conversion happens, instead of waiting another 20 years,” said Boatman. “All the economic indicators suggest clean steel is the steel product of the future, and the best way to future-proof jobs especially in the steel sector and especially for unions.” 

Cutting pollution, creating jobs 

Cleveland Cliffs is planning to convert its Middletown, Ohio, steel mill to DRI, tapping a $500 million federal grant for industrial decarbonization under the Bipartisan Infrastructure Law and Inflation Reduction Act. 

A DRI furnace does not need to use coke or heat iron ore to 3,000 degrees Fahrenheit to produce pure “pig iron”; the same result is achieved with a different chemical process at much lower temperatures. DRI furnaces can be powered by natural gas or clean hydrogen. Initially, Cleveland Cliffs says, its Middletown mill will run on natural gas, releasing about half the carbon emissions of its current blast furnace. Eventually, the company announced, it could switch to hydrogen. 

Along with slashing greenhouse gas emissions, a similar green steel conversion at Dearborn Works would greatly reduce the local air pollution burden facing local residents in the heavily industrial area, which is also home to a Marathon oil refinery, a major rail yard and other polluters.    

But it wouldn’t be cheap. Boatman’s report estimated the cost of converting a blast furnace to a DRI furnace and associated electric arc furnaces at $1.57 billion, plus $2.6 billion to build a green hydrogen plant. Utility DTE Energy would need to work with grid operator MISO to add about 2 GW of solar and 2 GW of wind power, plus battery storage, to the grid to power the green hydrogen production. 

The conversion would mean closure of the EES Coke plant, which turns coal into coke for the steel mill, on heavily polluted Zug Island in the River Rouge just outside Detroit, five miles from Dearborn. In 2022, the EPA sued the coke plant, a subsidiary of DTE Energy, over Clean Air Act violations. 

A recent study by the nonprofit Industrious Labs found that the EES Coke plant could be responsible for up to 57 premature deaths and more than 15,000 asthma attacks. The report also found that more than half the people living within a three-mile radius of both the steel mill and coke plant are low-income, and three-quarters of those living around the coke plant are people of color, as are half those living around the steel mill. 

“The total health costs are quite significant,” said Nick Leonard, executive director of the Great Lakes Environmental Law Center, which is representing local residents as intervenors in the EPA lawsuit against the coke plant. “We allow companies to externalize those costs and not account for them. If they were required by some sort of change in policy or regulation to be responsible for those costs, it would certainly make the case they could make this expensive switch” to green steel. 

The law center also represented residents in legal proceedings around Dearborn Works’ Clean Air Act violations, including a 2015 consent decree and a 2023 mandate to install a new electrostatic precipitator at a cost of $100 million. 

Leonard said local residents “know Cleveland Cliffs poses a risk to their health, and they want solutions. They know there’s a problem, they are frustrated by the lack of will or attention from state and local government.”

Cleveland Cliffs did not respond to a request for comment. 

Why Michigan? 

The country’s active steel mills are concentrated in Pennsylvania, Indiana, Ohio and Michigan. Advocates and residents are asking Nippon Steel to consider a green steel conversion at the Gary Works mill in Northwest Indiana, if the global corporation succeeds in acquiring Gary Works owner U.S. Steel. Advocates have also proposed green steel conversions for Pennsylvania mills. 

There are factors that make a green steel conversion both more promising and more challenging at Dearborn Works, compared to other locations, Boatman explained. 

Dearborn Works has only one blast furnace in operation, meaning a potentially smaller investment than at mills with more furnaces. Michigan has also set aggressive renewable energy goals, which could be furthered by the ambitious renewable energy buildout that would be required to produce enough green hydrogen for the steel mill.

“That’s why we’re asking the state of Michigan and the governor to get all the interested parties to the table to actually talk about this, hopefully commit to it, and do the detailed planning that needs to be done to figure out how much wind, how much solar, how much battery storage does there need to be to get this off the ground,” said Boatman. 

Michigan has legal limits on behind-the-meter generation that could make it more difficult to build renewables specifically to power green hydrogen production for a steel mill. Utilities would instead need to produce or procure the renewable energy, and sell it to the steel mill, Boatman explained.

A green steel conversion at Dearborn Works could create a total of about 500 new jobs, Boatman estimates, considering that about 500 jobs would be lost at the closing coke plant but 410 jobs would be created at the hydrogen plant, 550 in new renewables and 170 at the mill itself. The DRI conversion at the Middletown steel mill is expected to create 170 new permanent jobs and 1,200 construction jobs, according to Cleveland Cliffs. 

A 2023 analysis by the Ohio River Valley Institute found that at the Mon Valley Works steel mill in Pennsylvania, a DRI conversion would likely preserve more iron- and steel-making jobs than “business as usual,” with 87% of the current jobs expected to exist in 2031, compared to 69% without a change — as U.S. steel production continues to shrink and automate. 

“We are seeing a general trend for both iron and [secondary] steel production to move toward the South, to states that aren’t friendly to unions and can produce products at cheaper prices by bypassing unions,” said Boatman. “Michigan obviously has a proud history of being a strong union state, it matters to keep those good union jobs there.” 

Labor unions have largely been silent on the concept of green steel conversion. The United Auto Workers union — which represents Dearborn Works employees — and the United Steelworkers did not respond to requests for comment. 

Hydrogen wild cards 

The U.S. Department of Energy plans to spend $8 billion on hydrogen hubs, and a potentially lucrative tax credit known as 45V is being finalized for clean hydrogen. Experts and advocates agree that energy-intensive, hard-to-decarbonize industries like steel are where hydrogen could have the most impact. But large-scale production of pure hydrogen for industrial use is still in nascent stages, and little infrastructure has been built or tested for transporting and storing hydrogen. 

That is among the reasons, Boatman said, that there’s been reluctance among residents and union leaders to embrace the concept of green steel. Boatman’s report emphasizes that community benefits agreements and community engagement processes are crucial to make sure residents are informed about, benefit from, and have a meaningful voice in any green steel plans. 

“Union workers and fence-line community members all want better air quality, lower emissions, who wouldn’t want to go to work knowing you’re safer being there?” she said. “There’s a lot of interest in cleaning up the air. It’s more a question over how that happens. When hydrogen becomes part of the equation, there’s always some concern.” 

She noted that hydrogen could potentially be stored in salt caverns in the Detroit area, though extensive study on the feasibility and environmental impacts would be needed. In Mississippi, a startup company Hy Stor Energy is planning to store green hydrogen in salt caverns, ready to generate electricity during times of high demand. 

Tax incentives for clean hydrogen could provide major incentives for steel mills. But clean hydrogen proposed projects have been in flux nationwide as the rules for qualifying for 45V tax credits are being hashed out in a lengthy, controversial process; and the change in presidential administration adds even more uncertainty. 

“These industries have to be incentivized,” said Roxana Bekemohammadi, founder and executive director of the U.S. Hydrogen Alliance, which advocates for pro-hydrogen policies on the state level. “Europe is creating a mandate — that’s one incentive. We’d love to support any incentives that would allow hydrogen to be leveraged in the steel industry. With state legislation we certainly can incentivize it. It’s a question of how competitive we want to be.”

Advocates make economic case for green steel production at Dearborn, Michigan plant is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

A Massachusetts university is developing technology that aims to use lasers to drastically cut emissions and energy use from Maine’s paper and pulp industry. 

Worcester Polytechnic Institute recently received a $2.75 million U.S. Department of Energy grant to help ready the industrial drying technology for commercial use.

“We are all excited about this — this is potentially a groundbreaking technology,” said Jamal Yagoobi, founding director of the institute’s Center for Advanced Research in Drying.

In Maine, the paper and pulp business generates about 1 million metric tons of carbon dioxide emissions each year, roughly half of the state’s industrial emissions. Much of these emissions come from the process of drying mashed, pressed, and rolled wood pulp to yield paper products. The emissions come mainly from three major operations across the state; three additional facilities contribute smaller amounts.

These plants’ emissions will need to be addressed if Maine is to reach its goal of going carbon neutral by 2045. Furthermore, each of these plants is located in an area with an above-average population of low-income residents, according to data assembled by Industrious Labs, an environmental organization focused on the impact of industry. And two are located in areas with a higher-than-average risk of cancer from air toxins, suggesting a correlation between their operations and the incidence of cancer in the area. 

At the same, the paper and pulp industry remains economically important to Maine, said Matt Cannon, state conservation and energy director for the Maine chapter of the Sierra Club. 

“It’s got real union jobs — the paper industry is still very important to our community,” he said. 

Worcester Polytechnic’s drying research center has been working on ways to dry paper, pulp, and other materials using the concentrated energy found in lasers. The lasers Yagoobi’s team is using are not the lasers of the public imagination, like a red beam zapping at alien enemies. Though the lasers are quite strong — they can melt metal, Yagoobi says — they are dispersed over a larger area, spreading out the energy to evenly and gently dry the target material. 

Testing on food products has shown that the technology can work. Now, researchers need to learn more about how the laser energy affects different materials to make sure the product quality is not compromised during the drying process. 

“For paper, it’s important to make sure the tensile strength is not degrading,” Yagoobi said. “For food products, you want to make sure the color and sensory qualities do not degrade.”

Therefore, before the system is ready for a commercial pilot, the team has to gather a lot more data about how much laser energy is incident on different parts of the surface and how deeply the energy penetrates different materials. Once gathered, this data will be used to determine what system sizes and operating conditions are best for different materials, and to design laser modules for each intended use. 

Once these details are worked out, the laser technology can be installed in new commercial-scale drying equipment or existing systems. “This particular technology will be easy to retrofit,” Yagoobi said. 

Industrial sources were responsible for about 1.3 billion metric tons of carbon dioxide emissions in the United States in 2023, about 28% of the country’s overall emissions, according to the U.S. Energy Information Administration. Heating processes, often powered by natural gas or other fossil fuels, are responsible for about half of those emissions, said Evan Gillespie, one of the co-founders of Industrious Labs. Many industrial drying processes require high temperatures that have traditionally been hard to reach without fossil fuels, giving the sector a reputation as hard to decarbonize, Gillespie said.

“The key challenge here is: How do you remove natural gas as a heating source inside industrial facilities?” said Richard Hart, industry director at the American Council for an Energy-Efficient Economy. “The scale of what is happening in industry is enormous, and the potential for change is very powerful.”

To make the new technology effective, industry leaders and policymakers will need to commit to reinvesting in old facilities, Gillespie noted. And doing so will be well worth it by strengthening an economically important industry, keeping jobs in place, and creating important environmental benefits, he added.

“There’s often this old story of tensions between climate and jobs,” Gillespie said. “But what we’re trying to do is modernize these facilities and stabilize them so they’ll be around for decades to come.”

Paper and pulp mills produce half of Maine’s industrial CO2 emissions. Could lasers help slash their climate impact?    is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

As a state committee studies ways to wean Rhode Island off of natural gas, several of its members want the group’s final report to dismiss one potential pathway as wholly unrealistic.

Switching to renewable natural gas or other alternative fuels appears to be neither a feasible nor a financially viable solution at this time, say multiple stakeholders who have commented on a draft outline of a report a consulting group prepared for Rhode Island regulators.

RNG is derived from biomass or other renewable resources. It is a biogas, captured from the decomposition of organic matter, such as animal manure or food waste.

Many gas utilities around the country are pushing for RNG as part of the solution to lowering greenhouse gas emissions. But Michael Walsh, a partner at Groundwork Data, a clean energy consultancy that worked with the Conservation Law Foundation and the Sierra Club in the committee process, told the Energy News Network that “we don’t see a lot of viability with the RNG pathway,” both because of limited availability and because it is much more expensive then fossil fuel gas to produce.

While RNG is interchangeable with conventional natural gas, “realism about the availability and cost of alternative fuels for the gas system is necessary” for the planning process, wrote Nicholas Vaz, Rhode Island special assistant attorney general, in his comments on the draft. 

Vaz cited a 2019 study prepared for the American Gas Foundation that looked at RNG production potential by 2040, based on the availability of source materials and utilization. Based on those findings, Vaz concluded that the amount of RNG available by 2050 would only allow for about 17% of Rhode Island households to remain connected to the gas system.

Currently, more than half of Rhode Island homes receive natural gas service.

The state Public Utilities Commission established the stakeholder committee as part of its “Future of Gas” docket, an investigation of the future of the regulated gas distribution business in Rhode Island. That docket was opened in 2022 in response to the passage of the state’s Act on Climate, which mandates a 45% reduction in greenhouse gas emissions below 1990 levels by 2030, 80% by 2040, and net-zero by 2050.

The natural gas system operated by Rhode Island Energy accounts for almost 40% of statewide emissions. So the PUC, which regulates the utility, is in the tricky position of having to craft a plan for getting commercial and residential customers off natural gas, finding a way to pay for it, and ensuring that consumers aren’t harmed in the process. Regulators will use the committee’s report to help inform the strategy it lays out.

The neighboring state of Massachusetts is a little farther along in that process; its state Department of Public Utilities issued an order last December outlining a strategy for getting the state off natural gas.

While utilities there initially pushed for a plan that was heavily reliant on RNG, regulators ultimately rejected that approach, citing concerns about availability, cost and whether such alternative fuels will actually lead to a reduction in emissions.

To some extent, Massachusetts’ work to date helped inform the committee process in Rhode Island, Walsh said.

“We had a lot of Massachusetts folks in the room to share lessons learned,” he said. “We at least got through some of the questions faster.”

Ben Butterworth, director of climate, energy and equity analysis for the nonprofit Acadia Center, told ENN his organization would like to see Rhode Island prioritize much of what is in the Massachusetts strategy: a focus on electrification and energy efficiency, disincentivizing further expansion of the gas system, and pilot programs focused on the strategic decommissioning of the gas system.

The PUC must also consider how to fund the transition, Butterworth noted. Vermont and Massachusetts are pursuing a clean heat standard as a funding mechanism for climate goals, while New York is pursuing a cap-and-invest approach. 

“Finding that mechanism is critical, and the report should include at least those options,” Butterworth said.

At the same time, the report should include a discussion of possible mechanisms to protect low-income ratepayers from “the inevitable initially increased costs of electrification,” urged Jennifer Wood, executive director of the Rhode Island Center for Justice, in her comments on the draft.

These might include capping the amount a household pays for electricity as a percentage of their income; rate reforms; and assistance programs to defray the costs of installing electric heat pumps.

“Low-income utility customers living in rented homes that are least well equipped for energy efficiency are already most harmed by the social effects of climate change,” Wood wrote. “The only way to ensure that they will not be doubly harmed by unsustainably higher utility bills during the transition…is to decouple income-eligible consumers’ energy costs from the near-term impacts of necessary, but initially more costly, electrification.”

The committee is expected to issue a final report with its findings and recommendations to the PUC by the end of the year.

As Rhode Island considers future of gas, advocates call for ‘realism’ on cost, availability of RNG is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

A successful regional collaboration to secure federal Inflation Reduction Act money in northeast Ohio has inspired a new, ongoing effort to help cities, counties, utilities and community groups coordinate on clean energy.

Three Cleveland-area foundations last month announced the launch of Power Up Local, which aims to play both a matchmaker and wedding planner role on large-scale, regional clean energy developments. The initiative plans to help connect potential partners, maximize projects’ community benefits, and facilitate joint funding opportunities such as federal grants, tax incentives, or green bank loans.

“This is really looking for the larger, more ambitious stakeholder projects that have direct stakeholder benefits,” said Daniel Gray, Power Up Local’s executive director. A big emphasis will be on assembling groups who “might not have worked with each other originally or understood where there’s an overlap” between clean energy and other goals.

The initiative could offer a new path for local leaders to advance in a place where state government remains hostile to clean energy. The continued availability of federal funding is in question following former President Donald Trump’s reelection, but Gray and others said they are confident some form of federal support for clean energy will remain during his second term.

The idea for Power Up Local grew out of collaboration among Cuyahoga County, the cities of Cleveland and Painesville, and other organizations on a $129 million grant application under the federal Climate Pollution Reduction Grant program. The application was among those awarded funding in July. It includes money for closing a coal plant and building multiple solar arrays, including on four closed landfills.

Beyond reducing pollution, the project will help lower electricity costs and generate revenue. Some of that will in turn aid in conservation efforts for the West Creek Conservancy, including lakeside access for residents in Lake County. Gray did some work on the project as director of local strategies for the Citizens Utility Board of Ohio, and local philanthropic support also helped in assembling the grant application.

The Cleveland Foundation, George Gund Foundation and the Fund for Our Economic Future are providing initial funding for Power Up Local. Initially, the program’s three full-time employees are being housed under Fund for Our Economic Future, with a goal of spinning it out as an independent nonprofit by 2027. 

The George Gund Foundation also provides funding to the Energy News Network. Like other donors, it has no oversight or input into the editorial process and may not influence stories.

Gray said Power Up Local will help stakeholders think bigger and more broadly about projects. For example, a project to redevelop a former industrial site may be able to help bring in other properties from a land bank or other group, potentially expanding into an economic redevelopment district that might support a microgrid, he suggested.

“We can add efficiency to projects, both financially and timewise,” Gray said.

Power Up Local will be a resource for organizations that want to add clean energy to a project but may not have the time or bandwidth to figure out how to do it. “They don’t necessarily know how to engage the marketplace,” Gray said.

And when it comes to funding, competitive grants will just be part of the story. A range of other credits or incentives can also help bring more clean energy. That raised a question, said Stephen Love, program director for environmental initiatives at the Cleveland Foundation: “What would it look like at scale beyond just the competitive grants to really unlock the whole scale of federal resources?”

While Power Up Local will work on clean energy projects, those projects must still be “net-neutral or revenue-positive” in order to promote economic development, Gray said. “We’re looking to develop as much community benefit as possible.”

Those benefits can come from lower electricity rates for people with high energy burdens, health benefits from lower pollution, job opportunities, conservation, access to parks, redevelopment of properties to attract businesses, and so on.

“This is about economic development. This is about creating economic opportunity in our communities,” said Love. As he sees it, clean energy can help drive that development.

Uncertainties ahead

No one knows what Trump’s presidential victory will mean for federal clean energy funding, but advocates are confident some funding will still be available.

“There are still grants to go after, and will likely still be grants to go after in the future,” Gray said. A repeal of the Inflation Reduction Act and Bipartisan Infrastructure Law would take time, and much of the grant funding has flowed to districts that supported Trump in 2020.

Even if agencies under Trump stopped carrying out the law, “I don’t think the bulk of the IRA direct credits are going to go away,” Gray said. He noted that Rep. Dave Joyce (R-Bainbridge Township) is among 18 members of Congress who wrote to House Speaker Mike Johnson this summer to support continuation of the energy tax credits.

Atlas Public Policy’s Climate Portal Program estimates those tax credits could exceed a quarter of a trillion dollars, with nearly another $250 billion of potential credits under the 2021 Bipartisan Infrastructure Law. Those credits can serve as refunds for nonprofits and local governments, which is how sewage treatment authorities in Columbus and Cincinnati plan to offset big chunks of the costs for biogas plants at two of their wastewater treatment facilities.

Financing opportunities will also be available from green banks, Gray said. Commercial banks also are looking to expand their portfolios for financing clean energy projects as part of corporate sustainability goals, he noted.

Power A Clean Future Ohio has already been working for several years to help its 50 local government members find ways to cut greenhouse gas emissions, based on their individual interests and priorities. Executive Director Joe Flarida said Power Up Local’s work will be a welcome complement to its ongoing work. 

“It just underscores the huge needs we have in the state of Ohio to invest locally and ensure that our local leaders and local governments have all the resources they need to do this work efficiently,” he said.

In Flarida’s view, an anti-climate approach by the incoming Trump administration “is also an anti-jobs approach.” And even if the federal government no longer treats climate change as a key priority, “that doesn’t change the reality that this is an issue we have to address head on,” he said.

Gray encourages local governments and other organizations with ideas for projects to reach out in the coming weeks and months.

“Now is the time to start thinking about what might be possible,” he said.

Ohio program wants to play matchmaker and wedding planner for clean energy collaborations is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.

The U.S. Environmental Protection Agency plans to finalize more than $200 million in grant funding in the coming weeks to accelerate the clean energy transition at three Great Lakes shipping ports.

The Cleveland-Cuyahoga County Port Authority, Detroit/Wayne County Port Authority, and the Illinois International Port District were each selected for grants last month under the Biden administration’s Clean Ports Program.

The U.S. EPA said it intends to finalize grant agreements by December or January. That action will obligate the federal government to pay roughly $3 billion in grants under the program, even if President-elect Donald Trump or the next Congress tries to repeal or block further action under the Inflation Reduction Act.

The $94 million grant announced for the Cleveland port is the largest it has ever received and will help it build on work that’s already underway to electrify and decarbonize its infrastructure. 

“It puts us at the forefront of decarbonization,” said William Friedman, president and chief executive officer of Cleveland’s port authority. “Now we’ll be able to start figuring out what’s the phase-in and then how do we move forward with the next round.”

The Detroit/Wayne County Port Authority will get approximately $25 million for solar panels, charging infrastructure and electric cargo handling equipment, and another $95 million will go to the Illinois EPA for solar, battery storage and hydrogen-related investments at the Illinois International Port District serving greater Chicago.

The largest share of grants will go to ports along the East and West coasts. “But the program is also intended to set the foundation for transitioning the entire port industry to zero emissions,” said Jennifer Macedonia, a deputy assistant administrator for U.S. EPA. “And there are important communities around many of our inland ports as well.”

The shipping industry accounts for roughly 3% of global greenhouse gas emissions, according to the U.S. Department of Energy. While the bulk of that is from ships themselves, port operations typically rely on diesel power for most of their energy. And ships often burn fuel to power equipment even while they’re in port.

The EPA’s review process included ensuring that selected projects can achieve or exceed goals for reducing greenhouse gas emissions, as well as other pollution that can affect nearby communities, said U.S. EPA Administrator Michael Regan. Those criteria air pollutants are ozone, particulate matter, carbon monoxide, lead, sulfur dioxide and nitrogen dioxide.

The work is especially important for Ohio, which has lagged other Midwest states and regions in deploying strategies to reduce greenhouse gases, said Valerie Katz, deputy director for Cuyahoga Green Energy. “Our regional decarbonization efforts will reduce environmental exposure to toxic air pollutants for downstream Ohio communities.”

Funding for the Port of Cleveland will encompass work for electric cargo-handling equipment and vessels that serve the port, along with solar generation and battery storage, charging infrastructure and shore power for vessels. Project partners include Logistec USA, the commercial operator for day-to-day operations, as well as the Great Lakes Towing Company, which will build two electric tug boats.

Decarbonization is a “competitive advantage that will attract more shipping volume to our port,” said Baiju Shah, president and CEO of the Greater Cleveland Partnership. “Companies are striving to reduce their environmental footprints through their operations and value chains,” including Scope 3 greenhouse gas emissions. “In addition, electrifying the port operations supports our region’s clean air efforts.”

That’s especially important given the port’s location near the downtown lakefront and riverfront areas, Shah said. Lake Erie and the Cuyahoga River are the focus for several waterfront development projects aimed at drawing more business and visitors to Cleveland.  

Funding for the Port of Detroit will go toward electric cargo-handling equipment, some vessels and railcar movers, along with charging infrastructure and solar generation. Part of the money also will be used to develop a roadmap for adding EV and hydrogen fueling infrastructure. The Detroit/Wayne County Port Authority is part of the Midwest Alliance for Clean Hydrogen, or MachH2, which was selected last year for $1 billion in Department of Energy funding for a hydrogen hub.

Funding for the Illinois International Port District will cover a variety of projects for its three ports, including hydrogen fueling infrastructure, solar energy and battery storage, and hydrogen and electric cargo handling equipment. Hydrogen and electric locomotives also are on EPA’s program selections list. The Illinois EPA is the lead partner for the grant work.

Like its counterpart in Cleveland, the Detroit/Wayne County Port Authority had already begun working on plans to move to cleaner energy sources for Scope 1 and Scope 2 emissions. But zero-emissions equipment to move cargo is new in the U.S. shipping industry and is still generally more expensive than fossil-fueled counterparts.

“What’s great about the EPA grant is that it helps these businesses make the decision to choose this cleaner technology,” said Mark Schrupp, executive director for the Detroit port authority. Over time, costs for such equipment should come down, but the grants will help launch market growth.

Various projects among the 55 selected for grants last month have planning components and provisions for community engagement or workforce development. Planning work on emissions inventories can position other ports to move ahead with clean energy in the future, Macedonia said.

The U.S. EPA plans to move ahead swiftly to finalize grant agreements, which will have the effect of protecting the funds from a possible clawback under Trump or the next Congress.

“We will be awarding the grants in December of 2024 and January of 2025… so that money will be obligated on or before the end of this administration,” Regan said. Depending on the projects, implementation will occur over the next three to four years.

In Cleveland, that means a big chunk of work under the new grant will be taking place even as renovation of the Port of Cleveland’s Warehouse A and electrical work take place under its current projects.

“We’ll have to throw a lot here at the engineers and construction project management people to figure this out,” Friedman said. Yet the timing means it will be that much sooner for the port to move to zero emissions for its own operations.

Great Lakes ports will get a share of U.S. EPA funding to move shipping off fossil fuels is an article from Energy News Network, a nonprofit news service covering the clean energy transition. If you would like to support us please make a donation.