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December 24, 2024

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New Mexico Contemplates Organized Market Choice

When it comes to choosing one of the two competing Western day-ahead market offerings, who else is participating in the market is a key consideration, a representative of a New Mexico utility said last week.

The New Mexico Public Regulation Commission (PRC) held a workshop on Sept. 21 to discuss the pros and cons of utility participation in a regional day-ahead market or RTO. The discussion came as CAISO prepares to roll out its extended day-ahead market, in competition with SPP and its Markets+ offering.

Kelsey Martinez with the Public Service Company of New Mexico (PNM) said during the workshop that both market operators are “proven,” and PNM believes the two offerings would provide similar benefits.

“Less and less of the decision feels about the market operator and the market design,” said Martinez, who is PNM’s RTO and markets manager. “And more and more of it feels really about who’s in the market with you. So which resources are in the market, which transmission is in the market, what loads are in the market.”

In written comments to the commission, PNM was even more specific, saying “existing market transmission connectivity represents the largest deciding factor in choosing a day-ahead market.”

PNM said it currently has the most market transmission connectivity with Arizona Public Service. PNM expects to select a day-ahead market in 2024.

PNM also worked with consultant Energy and Environmental Economics (E3) to look at the impact of market seams between New Mexico and Arizona. The utility defined seams as areas where entities that share transmission connectivity are in different market footprints.

“For PNM … [the study] showed a large reduction in benefits when seams exist between Arizona and New Mexico,” the utility said in its comments.

PNM noted that it won’t know what transmission connections will be in each footprint until other utilities reveal their day-ahead market choices.

The E3 analysis was a follow-up to a report the consultant prepared for the Western Markets Exploratory Group, looking at the impact of different market footprints on WMEG member benefits.

Moving Renewables to Market

In August, the PRC opened a docket to establish “guiding principles” for participation in a regional day-ahead market or RTO by two investor-owned utilities in the state, PNM and El Paso Electric. (See NM Commission to Set Standards for RTO, Day-ahead Participation.)

PNM has been participating in CAISO’s Western Energy Imbalance Market (WEIM) since 2021 and El Paso Electric joined the WEIM this year.

Last week’s workshop was scheduled as part of PRC’s guiding principle development. In addition, PNM, El Paso Electric and other stakeholders filed lengthy written comments answering questions posed in the commission’s initial order opening the docket.

Some stakeholders used the workshop as an opportunity to make a pitch for a Western RTO.

“Moving forward in the stepladder of market opportunities before us is good, but stopping short of a full RTO leaves real opportunity on the table,” said Rikki Seguin, executive director of the Interwest Energy Alliance.

Interwest is an advocacy group that represents utility-scale renewable energy developers in six Western states. For the renewable industry, “getting to the benefits of centralized transmission planning and cost allocation is key,” Seguin said.

To meet state policy goals, the West will need to add 9 GW of renewable energy each year starting in 2026, Seguin said, citing data from Energy Strategies’ Western Flexibility Assessment.

New Mexico is well-positioned to help satisfy that demand, she said, with its “world class” solar and wind resources.

But “absent the transmission planning … it’s going to be really hard to move those renewables to market,” Seguin said.

Bifurcation Challenges

Public interest group Western Resource Advocates (WRA) also weighed in on the regional market issue in written comments and with a presentation during the PRC workshop.

WRA said a single, large-footprint market would provide the most economic, environmental and reliability benefits to New Mexico. In terms of challenges arising from regional markets, WRA said one of the largest would be a bifurcation of day-ahead energy markets and their impact on efficient clean energy dispatch and economic gains from the WEIM.

In addition, WRA is concerned about New Mexico utilities’ decision-making process for joining a market.

“The choice to join a regional market … should not be based on grounds of expediency to satisfy an adjoining utility that it relies on for transmission access and dispatch,” WRA said in written comments.

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MISO Somewhat Open to COD Allowances in Interconnection Queue Rules

MISO has signaled it is receptive — but only to an extent— to stakeholder ideas on loosening its commercial operation date deadlines in its generation interconnection queue.

MISO will collect stakeholder suggestions through Oct. 17 on how it might stretch deadlines around commercial operation date rules in its interconnection queue. The RTO is experiencing a growing number of generation projects that are approved to connect to the system but aren’t finished.

However, MISO said the potential commercial operation dates generation developers are using in negotiations for upcoming generator interconnect agreements (GIAs) so far don’t exceed the existing extensions MISO’s tariff allows.

“It appears at least on the surface that commercial operation date extensions are adequate,” MISO’s Brady Mann said at a Sept. 26 Interconnection Process Working Group teleconference.

Mann pointed out that MISO allows a three-year deferral when transmission owners cannot bring equipment necessary to connect new generation into service on time.

MISO policy requires GIAs struck among interconnection customers, transmission owners and MISO to contain a commercial operation date that’s within three years of the date originally requested in their queue applications. The grid operator additionally allows up to a three-year extension of the commercial operation date in the initial GIA. When developers can’t meet either extension, MISO can remove the project from its queue or developers can seek a waiver of the queue tariff deadlines with FERC.

Mann added that MISO is open to hearing potential remedies from stakeholders.

“It is a new world we’re living in, so having that collaboration and conversation will be helpful,” Mann said. “Our intent here is to understand the issues you’re facing and additional remedies that may be required.”

EDP Renewables last month requested that MISO consider extending its grace period or letting developers amend commercial operation dates to be more realistic in GIAs. The developer said study delays and supply chain setbacks mean interconnection customers can’t realistically meet the commercial operation dates set forth in the first drafts of their GIAs. (See MISO to Assess Extending Queue’s COD Grace Period.)

Multiple renewable energy developers told MISO that behind-schedule commercial operation dates will be common.

“We’re in a different world than in 2018. There are supply chain and delivery issues on both the interconnection customer and transmission side. … The problem is not likely to go away, in our view, and will extend into several future queue cycles,” EDP Renewables’ David Mindham said. “We believe it’s better to deal with this problem holistically than file a bunch of one-off waivers at FERC.”

Mann said MISO expects both interconnection customers and transmission owners to simultaneously gather supplies, conduct engineering analysis and construct facilities after a GIA is negotiated. He said one shouldn’t be waiting on the other to move ahead.

Growing Share of Approved And Unbuilt Generation

In a separate presentation, Mann said volumes of executed generator interconnection agreements are on the rise, with the 35 GW in GIAs expected to be executed by year’s end more than doubling 2022’s 16 GW.

MISO acknowledged the lion’s share of gigawatts from recently executed GIAs isn’t yet in commercial operation. Mann said MISO predicts a “large increase” in commercial operations in 2028, when developers exhaust their three-year grace periods.

MISO has said it has about 49 GW worth of generation projects that are approved to connect to the system under completed GIAs but remain unbuilt, which raises its near-term reliability risks. (See MISO: Reliability Risk Upped by 49 GW in Approved but Unbuilt Generation.)

By year’s end, MISO expects that value to grow to 66 GW in executed GIAs for generation projects that have yet to reach commercial operation.

Meanwhile, MISO’s interconnection generation queue studies continue to slip on their intended timelines. Most interconnection queue cycles for MISO’s four planning regions are delayed.

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DOE Looks to Build Clean Energy Park at Hanford Site

The U.S. Department of Energy wants to convert 30 square miles of the state of Washington’s heavily contaminated Hanford Site into a clean technology park.

But the agency doesn’t yet know what type of clean tech it wants there.

Led by Deputy Energy Secretary David Turk, DOE officials talked about the concept Friday with about 75 people, including developers, in Richland.

The Hanford Site consists of 586 square miles of land set aside for nuclear research and development, of which the central portion and much of the Columbia River shoreline are highly contaminated. Southeastern Hanford borders Richland with a 30-square-mile portion that is mostly uncontaminated.

That 30 square miles includes the fenced-off Columbia Generating Station nuclear plan and a long-defunct research reactor. A handful of small, mildly contaminated waste burial sites are also in the area, which DOE says would be easy to clean up. The area is adjacent to the Pacific Northwest Laboratory’s complex in northern Richland.

DOE wants to combine its cleanup and energy missions by turning this area into a clean tech park, Turk said. However, it does not plan to pin down what it wants to put in that park for a while.

The agency is seeking public comments on how it should proceed by Oct. 12. It then expects to issue a request for proposals in late November. Decisions to narrow down those proposals should occur by early 2024.

“We’re not going into this with, ‘It has to be this technology, it has to be that technology.’ … We’re soliciting creative options,” Turk said. He declined to say if solar farms would be considered for the site.

Brian Harkins, DOE Hanford Site assistant manager for mission support, said wind farms would face hurdles in the area because of their vibrations. Just west of the 30 square miles is a Nobel-prize-winning observatory that captures gravitational waves from black holes and colliding stars. Its instruments are ultra-sensitive to outside vibrations.

The site could conceivably hold several projects simultaneously. The requirement is that any specific project must generate at least 200 MW of electricity. “We’re thinking big, really big,” said Ingrid Kolb, director of DOE’s Office of Management.

The area has been already heavily surveyed on environmental and cultural matters. DOE officials estimated that the appropriate environmental impact studies would take two to four years to complete. One advantage is that the studies would tackle the entire 30 square miles at once, instead of being divided into separate studies for individual projects, DOE officials said.

In a separate development, southeast Washington economic development organization Tri-City Development Council earlier this month said it planned to set up a nonprofit subsidiary to help develop clean energy businesses in the region. The group’s leader told NetZero Insider that it has not yet set a timetable for getting the venture up and running or identifying goals. (See Southeast Wash. Looks to Become Clean Tech Hub.)

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Wash. Judge Rejects Cap-and-trade Lawsuit

A Washington judge on Friday rejected a lawsuit that sought to suspend the state’s cap-and-trade program.

Thurston County Superior Court Judge Mary Sue Wilson ruled that the 2022 transportation bill that included a clause giving Washington’s Department of Ecology rulemaking authority to implement a 2021 cap-and-invest law did not violate the state’s constitution by having more than one subject in it.

The conservative Citizen Action Defense Fund sued the state in January, alleging that the Legislature invalidated its 2022 transportation bill by cramming multiple subjects into it.

The lawsuit had two intentions, said Jackson Maynard, executive director for the Citizen Action Defense Fund. One was to hold the line on the state constitutional rule that limits a bill to one subject. The second was to at least temporarily halt the state’s new cap-and trade program by eliminating Ecology’s rulemaking authority.

The program went into effect Jan. 1 and has so far this year raised $1.462 billion in three quarterly auctions and one special auction. (See Wash. Allowance Prices Surge Again in 3rd Cap-and-trade Auction.)

The money is earmarked for many programs that combat climate change, which has been linked to health, agriculture, fish and wildfire issues. A large portion of cap-and-trade revenue is used to address transportation concerns.

Plaintiff’s attorney Callie Castillo argued Friday that the Legislature overreached by loading too many subjects into the transportation bill.

“We don’t know if this is a transportation bill or a climate action bill. Those two don’t go together. … [The bill] is simply a tax increase,” Castillo said.

Assistant Attorney General Alicia Young argued that the disputed bill provided resources to tackle transportation programs with several sub-sections to address a bigger issue.

“This is an omnibus bill to address a broad issue in multiple ways. … This is a resources bill,” Young said.

Judge Wilson agreed with Young. “In this legislation, subjects come together or hang together on one topic,” Wilson said.

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State Ratepayer Advocates Discuss Role in Energy Transition

BURLINGTON, Vt. — ISO-NE, states and stakeholders must work together to prevent transmission costs from skyrocketing amid the energy transition, consumer advocates told the ISO-NE Consumer Liaison Group (CLG) last week.

Consumer advocates from all six New England states convened at the CLG fall meeting Thursday to discuss their role in the transition off fossil fuels.

The advocates stressed the importance of keeping energy affordable for consumers, while highlighting the dual climate and cost benefits of limiting the peak demand on the grid as electrification of transportation and heating increases.

“We’re trying to broaden the definition of what a consumer interest is,” said Bill Dornbos, legal director for Connecticut’s Office of Consumer Counsel, making the case that consumer needs include both low rates and a healthy climate and environment.

Dornbos added that it is time to “rebalance the power dynamic between ratepayers and utilities” to spur innovation and adapt to the climate crisis.

Andrew Landry, Maine’s deputy public advocate, agreed on the importance of keeping electric rates low in the clean energy transition.

“I believe, and our office believes, that we can achieve our climate policy goals in a way that is affordable,” Landry said.

Jacob Powser of the CLG Coordinating Committee | Rebecca Beaulieu

ISO-NE has projected a 2050 winter peak of up to 57 GW due to the electrification of heating and transportation as part of its 2050 Transmission Study. (See ISO-NE Planners Outline Potential Solutions for 2050 Tx Overloads.) Landry said more planning and focus is needed to limit the growth of the peak, including increased investment in demand response programs, energy efficiency and storage.

“I think we have underinvested in efficiency and demand response,” Landry said, noting that ISO-NE indicated in the initial transmission study findings that a 10% reduction in the 2050 winter peak would be associated with a one-half to one-third reduction in transmission costs. (See ISO-NE Projects Decrease in Gas, Increase in Coal and Oil for 2032.) Landry added the region should “do everything we can to lower that peak.”

Landry said ISO-NE has a key role in keeping transmission costs low as demand from electrification increases.

“I think market rules can be designed to support demand response and support energy storage,” Landry said, adding that “we also need to think about demand response and storage in the transmission planning process,” along with non-transmission alternatives.

Don Kreis, New Hampshire’s consumer advocate, agreed on the need to keep peak loads low and prevent runaway transmission costs.

“I am absolutely rabid about energy efficiency,” Kreis said, adding that there is an overlap in climate and ratepayer interests. Kreis also called for more scrutiny on asset condition projects, which represent the largest source of new transmission investments in the region. Asset condition projects are transmission upgrades for infrastructure that is old, obsolete or in need of wide-scale repair.

This month, Kreis co-signed a letter with representatives from Connecticut, Maine, Massachusetts and Rhode Island calling for a pause on all nonemergency asset condition projects not yet under construction until the asset condition approval process is reformed. The current process requires relatively minimal scrutiny for the multimillion-dollar projects, the costs for which are spread among ratepayers across New England. (See States Press New England TOs on Asset Condition Projects.)

The consumer advocates wrote there is about $5 billion in proposed, planned or under-construction asset condition projects and that this cost has increased by approximately 50% in the past six months.

“All stakeholders … need the opportunity to assess the reasonableness of each [transmission owner’s] planned spending,” the consumer advocates wrote. “Ultimately, the NETOs must be held accountable for the prudency of this spending.”

Community Members Call for Clean Energy, Transparency

Several local climate and environmental justice advocates who spoke at the meeting called on ISO-NE to take bolder steps to spur the transition away from fossil fuels.

Julie Macuga, a researcher for Global Energy Monitor, said it’s difficult for states to implement decarbonization policies when ISO-NE policies like the Minimum Offer Price Rule and forward capacity auctions ensure ratepayer dollars go directly to fossil fuels.

“ISO New England has the power to support actual grid reliability in the face of climate change,” Macuga said, adding that “you can end coal, gas, biomass and more.”

Jacob Powsner, a member of the CLG Coordinating Committee, climate activist and maple farmer, told RTO Insider he would like to see more transparency and democratic engagement from ISO-NE, as well as a larger voice for ratepayers at NEPOOL.

“If a member of the public wants to join [NEPOOL], it costs $500,” said Powsner, who added that even as an active member of the CLG Coordinating Committee, he still personally would have to bear the costs of NEPOOL membership.

“That would just come out of the farm budget,” Powsner said.

Energy transition

Burlington activists Leif Taranta and Julie Macuga | Rebecca Beaulieu

Leif Taranta, a Burlington-based community organizer, emphasized the impacts of climate-fueled flooding that hit Vermont this summer, displacing hundreds of residents.

“What is reliable energy when business as usual means that folks don’t even have a light switch?” Taranta asked.

Taranta called for increased focus on community resilience solutions and said there is “widespread desire” for programs including community solar, net metering and demand response.

“We can change our ways to take care of each other, and that should be the first priority,” Taranta said.

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Massachusetts Announces Permitting And Siting Reform Commission

To increase the pace of development for clean energy resources, Massachusetts Gov. Maura Healey (D) signed an executive order Tuesday creating a state Commission on Clean Energy Infrastructure Siting and Permitting.

The goal of the commission, the administration said in a press release, is to identify and reduce barriers for clean energy infrastructure and cut permitting timelines. The commission will work with state agencies within the Executive Office of Energy and Environmental Affairs (EEA) and make recommendations to government officials and legislators.

“This commission represents our administration’s efforts to bring people together and build consensus to tackle one of the most complex issues of our time,” Healey said, adding that “the clean energy transition can’t wait.”

The announced commission members, who were sworn in on Tuesday, represent a variety of interests, including labor, environmental justice and climate groups, electric utilities and the clean energy industry.

“With these members leading this effort, we are confident that the recommendations will be smart, balanced and ready for action,” said EEA Secretary Rebecca Tepper.

The commission also will make recommendations about how best to engage with communities in expedited permitting processes and ensure the benefits of the energy transition extend to all state residents.

“We’re going to need a lot of new infrastructure, and we’re going to need it fast,” said Lt. Gov. Kim Driscoll. “With these stakeholders at the table, we’re going to build serious consensus on how to tackle this challenge in a way that ensures environmental justice communities don’t bear a disproportionate burden, greenspace and other development priorities are protected, and we can all share in the benefits of clean energy.”

The executive order also tasked the commission with convening a “Siting Practitioner Advisory Group” to advise the commission on technical issues. That group will be chaired by Mary Beth Gentleman, a former assistant secretary for policy at the EEA and partner at Foaley Hoag.

The co-chairs of the legislature’s Joint Committee on Telecommunications, Utilities and Energy (TUE), Rep. Jeff Roy (D) and Sen. Mike Barrett (D), both have listed permitting and siting reform as top priorities of the current legislative session and are on the commission. (See Checking in on Clean Energy at The Mass. Legislature.)

Rep. Roy introduced a bill (H.3215) this session that would create an electric infrastructure permitting office to issue consolidated permits covering all necessary state and local approvals for clean energy infrastructure, which the office would need to issue within seven months of an application.

“What we’re trying to do,” Roy told NetZero Insider this year, “is move the community input back to the beginning of the process, give folks an idea of what they’re trying to do and how it’s going to help them and then streamline the permitting process so it runs parallel.”

The TUE committee played a large role in the omnibus climate bills passed in the legislature’s two prior sessions, and the committee’s leaders have said they intend to construct another climate bill in the current session, which ends Nov. 15.

Healey’s executive order also creates an Interagency Siting and Permitting Task Force to inform the commission, with experts from the EEA, Economic Development, Housing and Livable Communities, and Transportation Executive Offices.

A final report from the commission is due at the end of March 2024.

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DOE, FERC Outline Plans for Possible Government Shutdown

The split control of Congress means another possible shutdown of the federal government looms this weekend with a funding deadline of Sept. 30, the end of the fiscal year.

While several days remain before the deadline that could be extended by just a short-term deal, the Department of Energy and FERC already have laid out plans for what would be the first shutdown of the government since 2018. (See FERC to Furlough Most Employees in Govt. Shutdown.)

FERC would run with a skeleton crew of 60 as 1,506 out of 1,566 employees would not work after the agency runs out of funding. The commission said it would be able to keep going for some time using money it has on hand, but once exhausted it would limit activities to the bare minimum for as long as the government is unfunded.

DOE normally has 13,850 full-time employees and some 4,139 of those are financed by a resource other than the annual appropriations Congress is fighting over, while 1,404 employees are “necessary to protect life and property.”

Both agencies said they would be able to wind down standard operations within a half day of finding out the government is not funded.

FERC would keep up its safety reviews of dams and natural gas infrastructure, as well as continuing to monitor the bulk power system for reliability and policing energy markets against manipulation.

As presidential appointees, the commissioners themselves would continue working and issuing any orders that have to come out. For court cases, FERC would ask for stays. If courts deny stays, then staff will have to meet any deadlines in their cases.

DOE headquarters would keep a small staff to help coordinate its actions that must continue, which include maintaining and safeguarding the country’s nuclear arsenal and providing electricity from federal power administrations.

Bonneville Power Administration is self-funded and will continue to operate normally (its employees are covered in the category where their salaries are funded outside of the normal appropriations process). The other power marketing administrations (Southeastern Power Administration, Southwestern Power Administration and Western Area Power Administration) will perform functions related to the safety of human life and the protection of property by engaging in controlling and directing power to utilities, transmission of power and repair of the power transmission system.

“After the exhaustion of available balances, those activities not related to the preservation of life and property, unnecessary to the discharge of the President’s constitutional power, not funded by other than annual appropriations or not otherwise expressly authorized by law will cease,” DOE’s plan said.

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GE Sues Wind Turbine Blade Recycling Company

General Electric is suing a contractor it says failed to recycle GE customers’ old wind turbine blades.

GE alleges it paid Global Fiberglass Solutions of Texas LLC $16.9 million to provide an environmentally sound end-of-life disposal for about 5,000 blades, but GFS instead stockpiled them with other companies’ used blades.

This was “fraud and deception,” GE states in a Sept. 20 filing in federal court in New York City. (Case 1:23-cv-08346)

It also tarnished GE’s reputation when the situation was publicized, the lawsuit states.

The Texas Commission on Environmental Quality measured two GFS stockpiles in Sweetwater, Texas, at a combined 450,000 cubic yards during a 2021-2022 investigation of unauthorized storage of industrial solid waste.

Iowa regulators conducted a similar investigation of three stockpiles in that state in 2020.

Global Fiberglass Solutions is based in Washington state. Its LinkedIn page indicates it also has operations in Sweetwater and in Newton, Iowa. The most recent post on its Facebook page is more than three years old. A top-of-the-page banner indicates its website is under construction.

A person who answered the company’s phone number Tuesday said no one was available to speak to NetZero Insider about the lawsuit.

Allegations

GE’s lawsuit makes the following statements and allegations:

    • GFS hosted GE on-site in Texas to demonstrate the process by which it reduced the massive blades to pellets that could be reused in a variety of products.
    • GE contracted with GFS in 2017 and 2018 to remove roughly 5,000 blades from GE customer sites in Iowa and Texas and recycle them.
    • GFS billed GE for its services within 48 hours of completion of removal from each site.
    • GE paid a premium — $3,525 or $3,600 per blade — to what it thought was an environmentally conscious industry leader.
    • GFS repeatedly assured GE that it was actively recycling them.
    • GE heard reports that GFS instead was stockpiling the blades; it visited Sweetwater in late 2018 and saw the GFS facility did not appear to be in full operation.
    • GE on Dec. 18, 2018, demanded GFS rectify this breach of agreement within 10 days.
    • GFS “all but shut down” its operations; GE cannot be certain that any of the roughly 5,000 blades have been recycled.
    • The Iowa Department of Justice in September 2022 threatened civil action against GFS and GE under the state’s solid waste law; three months later, GE agreed to pay another company $5.5 million to recycle the blades stockpiled in Iowa to avoid litigation and prevent further harm to its reputation.

In its lawsuit, GE is seeking return of the money it paid GFS, plus interest; court costs and legal fees; and declaratory relief on indemnification for the third-party expenses it has incurred.

Background

Onshore wind power is one of the largest businesses of General Electric Renewable Energy. One of its lines is repowering or servicing existing wind farms, which can entail replacing turbine blades. As part of its sustainability pledge, GE actively seeks alternatives to landfilling these extremely large and heavy objects.

Aerial images of the main Sweetwater stockpile are striking — thousands of blade sections and nacelle components gleaming in the sunlight, arranged in piles with aisles between them.

Texas Monthly published a report in August 2023 on local frustration with the situation. Neighbors worry the site is a breeding ground for rattlesnakes and mosquitoes; community leaders fear the company will never remove the blades.

The report quotes the managing director of GFS saying the company is ramping up to shred the blades into pieces the size of coarse sand and has found a buyer for the material. He said the heaps of blades would be gone from Sweetwater by late spring 2024.

He declined to discuss the situation in Iowa.

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As EV Penetration Rises, Utilities Turn to Smart Charging Strategies

A pilot program using smart EV charge management to smooth distribution loads and improve demand response has been so successful a utility is adopting the program permanently before completing the pilot. The interim results of the U.S. Department of Energy-funded pilot were shared at a workshop at RE+ in Las Vegas earlier this month.

“Baltimore Gas and Electric found the initial residential pilot results are impactful and have included a permanent smart charge management program in their multi-year plan,” said Joshua Cadoret, senior project manager at Exelon, which received an award from DOE for a Smart Charge Management (SCM) pilot program with three of its utilities: Baltimore Gas and Electric, Delmarva Power and Light and Potomac Electric Power.

The pilot study, which is ongoing, includes about 3,000 residential EV customers with more than 3,600 vehicles as well as 850 public chargers throughout their territories as of Sept. 7. Commercial EV fleet owners also were targeted, but only one has been recruited successfully to date.

The SCM pilot recruited Tesla owners to enable their cars’ charging to be throttled to reduce peak demand and encourage off-peak charging. WeaveGrid software shares the utilities’ signals with the vehicles. The EV owners received a $10/month electric bill credit, equal to 10% of an average monthly bill, and were able to override the demand response request up to four times each month. The public charging pilot program offered customers two options: the default opt-in where charging is throttled at certain times and charged at a discounted cost/kWh or opt-out to get the full capacity of the charger at the standard rates.

Managed charging aims to solves two problems utilities face: their distribution systems’ ability to cope with an increasing number of EVs and the utilities’ need to respond to renewables, said Shane O’Quinn, senior director of business development at WeaveGrid, a company whose software optimizes EV-grid integration for utilities. “Whenever you have a large number of EVs coming online where 80% of the charging is happening at the residential level, and the residential distribution network is designed to support really relatively modest loads at the household, we’re ultimately going to get to a point to where we have distribution system challenges.”

EV charging incentives can be designed with the goal of spreading the load into times that lower the need for grid upgrades, O’Quinn said: “One of the first things you have to consider is how are people actually going about charging their EVs today and where do you ultimately want them to be in terms of how they charge in the future?”

The default for most EV drivers is to plug in their car when they arrive home from work, which usually coincides with peak demand as most housholds turn on HVAC and use appliances at the same time. This is shown in the first scenario in Weavegrid’s  graph, which shows eight cars on a single distribution feeder plugging in when they return from work, although one works late shifts so that car draws on the grid later than the others.

“Many utilities take the next step and think about how they might be able to implement time-of-use rates which can shape behavior so that people are starting to charge after the on-peak times are over,” O’Quinn said. That can help the drivers manage the cost of electricity but may not be optimal for the utility.

The initial stage of the residential pilot tested the ability to use SCM to move charging to off-peak times and resulted in 96% of the more than 40,000 charging sessions being done off-peak. While the drivers may plug in when they get home, the SCM works with vehicle telematics so charging begins when off-peak rates start, the second scenario in the graph.

“There’s another technique that can more actively push the charging into periods that are beneficial for you as a utility. For instance, we can utilize an approach where we’re smoothing out the charge levels on various distribution system assets, making sure that you’re not overloading transformers, for instance,” O’Quinn said, “or you might be able to push the charging into a period where you can soak up renewables on the grid.” The third scenario in the graph shows SCM being used to even out load on distribution grid assets.

Helping utilities use managed charging to absorb renewables on the grid is driven by economic realities, said Russell Vare, who heads automotive OEM partnerships for Kaluza, a vehicle-to-grid software provider. Using data from the UK as an example, he showed how the move from 17% to 35% renewables resulted in a substantial increase in price volatility.

The UK market shows that increased renewables penetration leads to greater wholesale power price volatility. | Kaluza

While regulated markets may not have that degree of price volatility, this data shows the need for utilities to use EVs to absorb peak renewables supply.

The pilot also looked at potential cybersecurity risks and vulnerabilities of EV chargers and vehicle telematics software, according to the Phase 1 Review distributed by the Smart Electric Power Alliance (SEPA).

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Northeast Stakeholders Discuss The Future of Alternative Fuels

New England regulators, policymakers and industry representatives convened in downtown Boston last week to discuss the potential of alternative fuels in the region’s push for decarbonization.

The conference was organized by the Northeast Energy and Commerce Association and featured talks and panels about the future of the natural gas network, along with the potential of fuels like hydrogen, renewable natural gas (RNG), biodiesel and renewable diesel in the energy transition.

The uncertain future of the region’s gas network loomed large over the course of the conference. Massachusetts, New York and Rhode Island all have ongoing state investigations into the future of their natural gas systems, with options ranging from widescale decommissioning to doubling down on the infrastructure.

“It’s so important to consider all options — that includes using the pipes which are in the ground, and potentially expanding pipes — to be able to meet the energy needs of the future,” said Max Bergeron of Enbridge.

From left: Jose Costa, Northeast Gas Association; Donny McCallum, Smartpipe Technologies; Max Bergeron, Enbridge. | © RTO Insider LLC

The company recently announced an open season for a project that would increase its pipeline capacity of natural gas to the northeast. (See Enbridge Announces Project to Increase Northeast Pipeline Capacity.)

“We anticipate we will see a growth in demand for gas utilities of about 6½% over the next five years,” Bergeron said. “We also have to keep in mind that the power grid is very much reliant here in New England on natural gas-fired generation, so we see a strong need for incremental pipeline capacity to alleviate some of those bottlenecks.”

Carleton Simpson, a commissioner on the New Hampshire Public Utilities Commission, said fuel availability “appears to represent a significant challenge moving forward” and added that a “NERC-style entity” may be needed to ensure the reliability of the gas network.

Jessica Waldorf, chief of staff and director of policy implementation at the New York Department of Public Service, said the state faces a tough task of maintaining the functionality of the gas network while keeping up with decarbonization.

“There’s certainly a lot of pressure for us to move quickly away from use of natural gas,” Waldorf said, while noting the state’s gas utilities simultaneously connect “tens of thousands of new customers to the natural gas system.”

Waldorf said if utilities continue to add customers at current levels, the state will be required to ensure the system can “safely and reliably meet the demand of those customers.” She added this will result in “really hard infrastructure decisions.”

“It also is increasingly challenging because we’re balancing those decisions against the requirements of the Climate Act, in addition to all of our other statutory responsibilities,” Waldorf said. “And that means additional review processes and additional analysis is needed to really justify the need for these projects on the basis of reliability.”

Jamie Van Nostrand, chair of the Massachusetts Department of Public Utilities (DPU), echoed the concerns about gas availability while questioning whether utilities should continue their pace of new gas hookups.

“To some extent, it seems to be business as usual in the natural gas industry with respect to new residential hookups and continuing levels of load growth,” Van Nostrand said. “Is that consistent with the statutory emissions limits that we need to achieve?”

Van Nostrand called the dynamic “a disconnect,” adding, “things seem to be that bad that [the gas utilities] are worried about the need to keep the Everett Marine Terminal open to address reliability concerns, but it doesn’t seem to have any impact on policies with respect to accommodating new connections.”

The DPU chair also called for a greater focus on reducing the energy burden on residents as the state transitions away from fossil fuels.

“We want to start a proceeding to focus on the energy burden, to figure out if there are rate designs … that would allow us to move rapidly forward on a clean energy agenda, while still recognizing that people have a hard time paying their bills,” Van Nostrand said. “That’s a very high priority for this commission.”

Hydrogen And RNG

State policy concerning the future of the gas networks frequently has pitted climate organizations against the gas industry, with climate groups pushing to rapidly decommission gas networks and the industry advocating for a continued reliance on the gas system and the blending of alternative fuels like RNG and hydrogen.

Bergeron said RNG and hydrogen could be blended into the gas network to lower its carbon intensity, while acknowledging fossil fuels like natural gas will have an “ongoing role.”

“We see RNG as an opportunity to leverage our existing network,” Bergeron said.

Jose Costa of the Northeast Gas Association echoed Bergeron’s support for fuel blending and added that legislative and regulatory help is needed to bring RNG into the region’s gas network.

“Electrification of everything is not the sole answer,” Costa said. “The natural gas distribution network, it’s going to be there, it’s going be needed, and I’m not sure if fully renewable energy will be the energy source of the future — it’s going to be a mixture.”

alternative fuels

Massachusetts Rep. Jeff Roy, co-chair of the Joint Committee on Telecommunications, Utilities, and Energy. | © RTO Insider LLC

Massachusetts Rep. Jeff Roy, (D) co-chair of the Legislature’s Joint Committee on Telecommunications, Utilities and Energy, told the conference Massachusetts “must use all the tools at its disposal to remain both a national leader in climate mitigation efforts and a prosperous, affordable home to residents.”

Roy highlighted a bill he introduced this legislative session (H.2938) that would promote the use of alternative fuels including RNG and hydrogen in the state’s gas network, calling the bill “a starting point for our conversation on the role of fuels in the Commonwealth’s future.”

Lobbyists for gas industry groups including Enbridge, National Grid and the Propane Gas Association of New England have supported Roy’s bill, arguing it would make efficient use of the existing gas network.

Meanwhile, members of climate organizations including the Green Energy Consumers Alliance, Mothers Out Front and Gas Transition Allies have opposed the bill, arguing that using the fuels in the gas network simply would perpetuate fossil fuel reliance and would lead to high costs to ratepayers due to the mounting expenses of maintaining the state’s aging gas network, combined with the high costs of hydrogen and RNG.

“The Commonwealth’s clean energy and climate plans indicate that the best pathway to clean heat is through electrification, not renewable natural gas and hydrogen, which this bill subsidizes,” Carrie Katan of the Green Energy Consumers Alliance told a legislative committee in June, adding the fuels are better suited for hard-to-decarbonize sectors like air travel.

Katan said biofuels like RNG are “fundamentally inefficient fuel sources” constrained by the feedstocks used to produce them, adding “no amount of state subsidies will overcome these problems for RNG, just as no amount of federal support could make ethanol the future of transportation.”

The environmental groups also argued that blending in alternative fuels would perpetuate the health effects and safety issues from the natural gas network. A 2022 study from Boston College’s Global Observatory on Planetary Health found that air pollution contributed to nearly 3,000 excess deaths in Massachusetts in 2019, largely attributed to burning fossil fuels.

Boston College biology professor Philip Landrigan, a co-author of the study, told NetZero Insider that blending hydrogen or RNG into the natural gas supply would have little effect on the local air pollution associated with the gas system, including the release of air pollutants like NOx gases, benzene, and other toxic chemicals.

Landrigan added that while the local air pollution impacts of natural gas are not as bad as coal or oil, natural gas is “every bit as powerful a greenhouse gas.” The professor added that he considers the effort to mix hydrogen into the gas network to be “a desperate attempt by the fossil fuel industry” to maintain a market for gas and protect their investments in gas infrastructure.