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November 14, 2024

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ERCOT Voltage Drop Leads to EEA Level 2

DFW AIRPORT, Texas — A frequency drop Wednesday evening leading to a dip in operating reserves forced ERCOT to enter emergency operations for the first time since the disastrous February 2021 winter storm.

The EEA 2 was issued to maintain critical system frequency because of low power reserves. Grid frequency is the balancing of the flow of electricity between 60.1 Hz and 59.9 Hz and must be maintained at that level on the entire ERCOT grid. Thursday night, the frequency dipped to 59.77 Hz.

The grid operator issued a Level 2 energy emergency alert at 7:26 p.m. CT when operating reserves dropped below the 2,300-MW threshold as solar energy ramped down during near-record peak demand. It said frequency dipped to 59.77 Hz, below the 60.1-59.9 Hz critical system range; the EEA allowed ERCOT to use additional reserve resources.

“To protect the stability of the electric system, ERCOT has access to additional reserve sources only available during emergency conditions,” CEO Pablo Vegas said in a press release.

In its first public acknowledgement of the event, ERCOT said in a Thursday evening email to the media that the event was triggered by a transmission limitation that restricted the flow of generation out of South Texas to the rest of the grid.

ERCOT exited the Level 2 EEA  about an hour and 15 minutes later, dropping down to Level 1. Operations returned to normal about 10 minutes after that.

Wholesale prices spiked at $5,070/kWh during the alert after having ranged from $20 to $60/kWh earlier in the day.

Speaking at SPP’s Resource Adequacy Summit at Dallas/Fort Worth International Airport, Texas Public Utility Commissioner Will McAdams said the commission is compiling a report and it plans to publish Sept. 13. The report will be discussed during the PUC’s open meeting Sept. 14.

“Full debrief, for the public,” McAdams said.

The event occurred during the normal evening period, when the sun sets and, along with it, solar production drops. ERCOT staff have met demand during that time period until Wednesday, when the drop was too precipitous. Solar energy regularly has been providing more than 12 GW this summer, with a peak of 13.73 GW in August.

“A key part of the story is that it’s hotter at 8 p.m. than it used to be,” tweeted Michael Webber, a professor at the University of Texas at Austin leading clean energy technology research. “After more than two months of high temperatures, the streets, sidewalks building materials and soil all become hotter and therefore keep the temps higher for longer after sundown.”

Energy storage contributed a record 2.17 GW of energy during the EEA, according to Grid Status. Generation outages were within ERCOT’s normal expectations of 5 to 6 GW.

Dan Woodfin, ERCOT | © RTO Insider LLC

“We need more dispatchable capacity to cover those time frames where our tightest timeframe isn’t even in the peak demand time of the day anymore,” Dan Woodfin, ERCOT’s vice president of system operations, said during a panel discussion at the Resource Adequacy Summit. “We’ve got roughly 13 GW of solar online every day. It’s when the sun goes down and so every day, it becomes an issue of whether the load is going to go down enough, and the wind comes up enough to make up for the solar going down. And it goes down really fast.”

Demand peaked at 82.7 GW on Wednesday, enough to set a new high for September. However, that was far below ERCOT’s still-unofficial peak demand record of 85.44 GW, recorded Aug. 10.

ERCOT issued a conservation appeal at 4:54 p.m. Wednesday for the hours between 6 and 9 p.m. The Texas grid already was operating under a weather watch through Friday, with the state’s largest cities expecting triple-digit temperatures into the weekend.

It made another call for voluntary conservation, its 11th of the summer, for Thursday evening.

ERCOT has called for reductions by large electric customers and has worked with neighboring RTOs to deploy switchable resources. On Thursday, it also requested U.S. Department of Energy authorization to allow its generating units to operate up to their maximum output levels, if needed. The DOE approved the request that day.

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Clean Energy Groups Protest NYISO DER Proposal

Renewable energy advocates filed a protest with FERC Thursday arguing that NYISO’s proposal to facilitate participation of distributed energy resource aggregations in its market would discriminate against smaller aggregations (ER23-2040).

The protest by Advanced Energy United (AEU) and the Advanced Energy Management Alliance (AEMA) comes after NYISO’s response to a FERC deficiency notice asking the ISO to clarify several aspects of its proposals to comply with Order 2222, which requires RTOs and ISOs to design rules giving aggregations market access. The complaints align closely with previous protests by the two groups.

In the protest, the groups argued NYISO failed to justify its 10-kW minimum requirement for DER aggregation participation. They also contended the ISO’s plan to restrict single resource type aggregations from using metering service entities is illogical and its requirement that demand response resources submit cost-basis data is impossible to fulfill because that data doesn’t exist.

AEU and AEMA focused particularly on the 10-kW rule, maintaining the requirement doesn’t “withstand scrutiny” and basing the DER aggregation minimum participation model on historical emergency demand response and special case resource programs is inappropriate because the “resource types and sizes are different.”

The two organizations also questioned NYISO’s administrative reasons for limiting DER participation, arguing that if the ISO thought it would be burdensome to register all types of DERs then it should either hire more staff or ask FERC for a limited waiver to give it more time to review smaller DER aggregations.

AEU and AEMA also criticized NYISO’s failure to propose an end date for its 10-kW requirement, which they said violates the objectives of Order 2222.

The groups asked the commission to reject NYISO’s proposals, saying the ISO’s response to FERC’s deficiency notice fails to adequately explain or justify the shortcomings the commission identified.

In addressing FERC’s letter last month, the ISO stuck to its previous arguments, claiming it did not have the bandwidth to allow all resources to immediately participate and saying any further delays would hinder implementation of its DER aggregation plans and potentially disrupt its demand response programs. (See FERC Seeks More Info on NYISO DER Aggregation Proposal.)

NYISO’s response did confirm it expects to complete its DER aggregation software development by Sept. 1 and aims to implement its participation model shortly after.

FERC must respond to NYISO’s deficiency letter within 60 days.

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NEPOOL Participants Committee Briefs: Sept. 7, 2023

COO Report

ISO-NE’s energy market value was about $300 million in August, down from $580 million in July and $1.1 billion in August of 2022, COO Vamsi Chadalavada told the NEPOOL Participants Committee on Thursday.

Chadalavada noted that natural gas prices were 83% lower than the August 2022 average. Net commitment period compensation payments were about $800,000 lower than the previous month and $4.4 million lower than August 2022.

The peak load for the month occurred Aug. 21, which triggered an abnormal conditions alert. Overall, monthly temperatures were lower than historical August averages.

Chadalavada’s report noted that annual 2023 emissions are down from 2022 levels through early August, with the biggest reductions coming from decreased oil combustion.

Budget Clarifications

Prior to the meeting, ISO-NE published a set of responses to questions from the states regarding the organization’s draft 2024 budget. The RTO has proposed a 21.5% budget increase for the coming year. (See ISO-NE Proposes 21.5% Budget Increase for 2024.)

“The budget reflects increases necessary to successfully transition to the clean energy future, as well as catch up on inflation costs that were higher than previously budgeted,” ISO-NE wrote. “While the inflationary pressures will subside, there will still be a need to increase resources in the foreseeable future. At this point, we are still assessing what may be needed for a post-transition paradigm.”

ISO-NE told states that managing the grid amid the energy transition will require increased resources and personnel.

“The number of assets in New England will grow to hundreds of thousands/1 million-plus in number,” ISO-NE wrote, adding that the complexity of its system will increase as it manages more behind-the-meter resources and non-dispatchable weather-dependent resources, as well as shifting load patterns.

“This complexity will increase the workload in ways that are straightforward (e.g., higher volume of asset registrations and transmission interconnections to study and manage) and less straightforward (e.g., changes to adapt the markets and operating procedures, including forecasting, to the aforementioned growth in complexity),” the RTO said.

ISO-NE also elaborated on the portion of the budget increase allocated to existing employee salaries, noting that an ongoing analysis led by an independent consulting firm has indicated that the RTO’s base salaries are below market. The organization said that the unfinished aspects of this analysis will inform future budget decisions and “affect both the 2024 and 2025 salary budgets.”

The PC will vote on the budget at the Oct. 5 meeting, which will be followed by a vote by the ISO-NE Board of Directors. The RTO said it hopes to file the budget with FERC in mid-October.

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Fishermen Quit RI Coastal Board in Anger

The panel of fishers advising Rhode Island’s coastal regulator has abruptly quit, accusing the agency of bias toward the offshore wind development they fear will harm the seafood industry.

All nine members of the Rhode Island Fisherman’s Advisory Board signed a letter of resignation to the Rhode Island Coastal Resources Management Council (CRMC) on Aug. 31.

They said they no longer would participate in the state’s Ocean Special Area Management Plan because its review of utility-scale wind power proposals had become “political theater,” a mockery of what the Ocean SAMP was designed to accomplish.

“It has become abundantly clear that the Rhode Island CRMC has made deference to offshore wind developers its top priority regardless of the requirements of the Ocean SAMP, the cost to the environment or the impacts to Rhode Island’s fishing industry,” they wrote.

The fishers said the CRMC ridiculed their expertise as anecdotal while placating developers and downplaying the impact of their projects.

The fishers cited potential damage to cod spawning grounds and population-level impacts to Atlantic cod because of these projects, as well as significant long-term impacts on the state’s fishing industry, in violation of the Ocean SAMPs enforceable policy.

“We will not allow our names to be connected in any way to Council approvals now amounting to wholesale ocean destruction,” they wrote. “Rhode Island is supposed to be the Ocean State, not the Windmill State.”

The letter is one of many attacks by the fishing industry on the offshore wind industry as it develops along the Northeast coast.

The industry is worried about the effect of wind power construction and operation on marine ecosystems and the effect on fishing fleets. There has been limited reassurance offered in return.

The U.S. Bureau of Ocean Energy Management has noted in environmental impact statements that there likely are to be project-specific effects on local commercial and sport fishing industries. BOEM also expects a cumulative impact from all the projects being planned in relatively compact zones on the Outer Continental Shelf from Cape Cod to Cape May.

Other reports have flagged the lack of scientific knowledge about the exact effects large wind farms will have on the ocean — because these are the first to be built in this part of the world, and because the turbines installed here likely are to be larger than those in use elsewhere.

Finally, National Marine Fisheries Service scientists have warned the ability to assess wind farms’ impact on fisheries will be compromised because research work in the vicinity must be curtailed for safety reasons.

State and federal policymakers are rushing to encourage offshore wind development as a climate-protective measure, simultaneously attempting to build a supply chain, infrastructure and body of scientific knowledge.

Rhode Island and its fishing industry are at the heart of all this — nine federal wind energy lease areas are designated in a trapezoidal area of the Atlantic south of the state. Construction is underway on two wind farms there and a third has been greenlighted.

Rhode Island leaders hope to make the state an onshore hub for offshore wind construction and maintenance and hope to import hundreds of megawatts from the ocean for in-state use.

The state already is home to Block Island Wind. With a nameplate capacity of only 30 MW, it is not considered utility-scale, but it holds the distinction of being the nation’s first offshore wind farm.

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NYISO to Ask FERC for Order 2023 Compliance Extension

RENSSELAER, N.Y. — NYISO on Wednesday said it plans to file a motion with FERC for an extension on the compliance deadline for Order 2023, according to a presentation given to stakeholders.

Thinh Nguyen, NYISO senior manager of interconnection projects, told the Transmission Planning Advisory Subcommittee (TPAS) and Electric System Planning Working Group (ESPWG) meeting that the ISO has 90 days to make its request to the commission, following the order’s publication in the Federal Register that day.

Nguyen added that NYISO plans to hold meetings focused on the interconnection queue and Order 2023 compliance that will be held after regular TPAS sessions and be potentially named the Interconnection Issues Task Force.

NYISO’s presentation also noted how, though it and several other RTOs have already asked FERC for a rehearing on Order 2023, the ISO might still comply with the order, as it is unclear if the commission will grant a rehearing (RM22-14). (See FERC Order 2023 Gets Rehearing Requests from Around the Industry.)

The ISO has been actively working to streamline its congested interconnection queue, and while it believes Order 2023 could improve efficiencies, it also cautioned stakeholders that it believes some of FERC’s directives may be legally inconsistent or counterproductive to the order’s goals.

Stakeholders probed NYISO staff for detailed information about the transition process and its potential implications.

Doreen Saia, an attorney with Greenberg Traurig, asked whether much of the transition was still to be determined or if the ISO could share some specifics.

Nguyen acknowledged that many of the specific details are to be determined but added that “for us to make a meaningful transition, we may need to sit down and figure out what this new process will look like and come up with a transition rule that will complement our own study process.”

Mark Reeder, representing the Alliance for Clean Energy New York, asked about the frequency of the newly proposed task force’s meetings and the expected outcomes.

“It’s too early to decide whether these will be biweekly or monthly meetings, but we want to make sure that when we host these meetings that we are coming to stakeholders with meaningful information rather than just general updates,” Nguyen said.

NYISO promised to return to stakeholders with more details on how it proposes to comply with Order 2023 and how proposed revisions might impact current interconnection processes.

Comprehensive Reliability Plan

NYISO also presented an updated draft of the Comprehensive Reliability Plan, with additional sections for dispatchable emission-free resources (DEFRs) and other developing technologies, as well as the short-term reliability needs recently identified in New York City.

The newly added “Beyond the CRP — Road to 2040” section, featuring DEFRs, was included in response to stakeholder requests. (See “Comprehensive Reliability Plan,” NYISO Proposes 48 Market Projects for 2024.) The CRP, which is the last part of the reliability planning process, is conducted every two years and evaluates the future risks to reliability and the viability of proposed solutions identified in earlier Reliability Needs Assessments.

FERC Order 2023

Historical generating capacity fuel mix in New York (2000-2023) | | NYISO

Mark Younger, president of Hudson Energy Economics, and Kevin Lang, partner at Couch White, questioned NYISO’s reliance on NERC data for reliability assessments, rather than using New York-specific data. Younger said New York City certainly has a reliability need in the short term but argued that using state data might lead to a more accurate accounting of potential shortfalls.

ISO staff said they are discussing the subject internally, though they emphasized that confidentiality concerns are a main reason New York data is not used.

NYISO aims to release its final CRP draft by late September and will seek committee approval in October.

Class Year & Expedited Deliverability Study Update

NYISO reported that 84 projects are officially part of Class Year 2023 and released a list of the 16 projects that have executed their expedited deliverability study (EDS) agreements.

The CY study assesses the feasibility of new projects looking to enter NYISO’s grid, while the EDS process is a more fast-tracked grid feasibility assessment for prioritized energy projects.

NYISO Manager of Facility Studies Wenjin Yan said the ISO must first finalize the EDS base case and estimated the study would finish next January.

Reeder suggested the ISO should consider tariff changes to allow for later entry into the EDS and consider starting another study after the current one is completed in early 2024 to enable projects to move ahead more quickly.

Yan said NYISO anticipates presenting CY23 for committee approval in July and August 2024.

NYC PPTN

NYISO gave a quick update on the New York City public policy transmission needs assessment, stating that the ISO is finalizing the baseline case and will share the data with developers upon completion.

The ISO reminded stakeholders, however, that the information would only be given to developers who have completed the requisite Critical Energy Infrastructure Information Non-Disclosure Agreement. According to both staff and stakeholders present, there is no set deadline for completing a CEII agreement.

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NJ BPU President Fiordaliso Dies

Joseph L. Fiordaliso, who led the New Jersey Board of Public Utilities as it embraced an aggressive and sweeping clean energy agenda marked by a major investment in offshore wind, has died, Gov. Phil Murphy (D) said Thursday.

Fiordaliso, 78, a BPU commissioner since 2005 and a former deputy chief of staff to former Gov. Richard Codey, spoke frequently about the need to adopt aggressive policies to combat climate change, saying he did not want future generations to look back at the agency’s efforts and question why it didn’t do more.

“Climate is changing,” he said at the board’s most recent meeting, on Aug. 16, shortly before it voted to enact a permanent community solar program after two well-received pilot programs. “And we all better be adults about the fact that we have to do something about it, not hide our heads in the sand. Because it’s not going to get any better; it’s only going to get worse.”

Fiordaliso’s death leaves the agency leaderless as it confronts increasing challenges to the state’s clean energy investment and especially the OSW program, which is facing community and special interest opposition and several lawsuits, as well as developer concerns about increasing costs that have raised questions about project viability.

The passing of the president removes a key font of experience on the board. Three of the four remaining BPU commissioners — Democrats Christine Guhl-Sadovy and Zenon Christodoulou, and Republican Marian Abdou — joined the board in the past year. The fourth, Republican Mary-Anna Holden, was appointed in 2012.

Under New Jersey law, the governor picks the BPU president and the senate can either confirm or reject the candidate.

Murphy, in a statement announcing Fiordaliso’s death, called Fiordaliso a “consummate public servant, a trusted colleague and a good friend.” The governor’s office did not say how or when Fiordaliso died, but the Associated Press said he died Wednesday.

“As president of the BPU since the beginning of my administration, Joe skillfully led our work to responsibly transition to a clean energy economy while always putting the needs of consumers first,” Murphy said. “Every time you saw Joe he was wearing his signature offshore wind pin or handing one out to anyone and everyone he met.”

To Fiordaliso, the pin — fashioned in the shape of a wind turbine — demonstrated support for the OSW program. But it drew criticism from opponents who saw in it a sign that he was too closely aligned with the OSW sector. The pin even drew the attention of a Republican lawmaker who quizzed Fiordaliso about it at a recent budget hearing.

Fiordaliso, however, said his interest was in doing what was best for the state and for ratepayers. In fact, at the board’s June meeting, he lashed out at the state’s two offshore wind developers who he said had created “delay after delay after delay … almost since Day 1.

“So I’m issuing a recommendation to those developers: Put your nose to the grindstone, and let’s get this going again,” he warned them. “Because my patience is short, and your delays are intolerable. And if you can’t do that, we have to have a very intense discussion.” (See NJ BPU Pulls Offshore Tx Project Mod from Agenda After Complaint.)

Top Priority

Murphy, who appointed Fiordaliso as BPU president on Jan. 15, 2018, has set a target for the state to develop 11 GW of OSW capacity by 2040. The BPU has approved three projects, totaling 3.758 GW, in two solicitations and is expected to announce the winners of a third round early in 2024, which could add 4 GW. In addition, the state has moved aggressively to jump-start a logistics sector to support the OSW projects, along with those of other states, which include the development of the New Jersey Wind Port to handle material and equipment for use in the projects. (See NJ Opens Third OSW Solicitation Seeking 4 GW+.)

Doug O’Malley, executive director of Environment New Jersey, an environmental group, said that Fiordaliso’s lengthy tenure as a BPU commissioner meant he was present in, and accrued a great depth knowledge of, the early years of the solar sector in the early 2000s. The BPU’s support helped put the state in the forefront of solar capacity development.

Fiordaliso also saw the inactivity on OSW during the tenure of Republican Gov. Chris Christie, from 2010 to 2018, and the BPU’s aggressive embrace of OSW when Murphy appointed Fiordaliso as the agency’s president will be a key plank of his legacy, O’Malley said.

“Wind was arguably the top priority for President Fiordaliso,” he said. “He cared deeply about offshore wind as kind of a new technology that you can harness.”

“Obviously, offshore wind has had choppy waters this year,” he said. “But we would not be in the position we are in without President Fiordaliso’s leadership.”

Other parts of the BPU’s aggressive agenda under Fiordaliso also have ruffled feathers. The agency is facing criticism from Republicans and business groups over the expense of the clean energy programs, including the lack of clarity on how much it will cost ratepayers. The programs include extensive subsidies for the purchase of electric vehicles (EVs) and trucks and the development of charging sites, proposals for subsidies of energy storage systems and plans to promote the use of electric heat and water systems in buildings and reduce the use of fossil fuels.

The New Jersey Business and Industry Association (NJBIA), which frequently disagreed with the BPU over cost concerns and the focus on electricity instead of other alternative energy forms, said in a statement prompted by his death that Fiordaliso was “truly and passionately committed to his job and its many missions.”

“Even when we didn’t agree on policy issues, President Fiordaliso always had an open door, took part in many NJBIA events and had receptive ears to our concerns,” said the statement from CEO Michele Siekerka.

Anjuli Ramos-Busot, director of the Sierra Club of New Jersey, released a statement that called Fiordaliso a “fighter for renewables and a proud supporter of offshore wind.

“He understood the severity of climate change and had a vision for the BPU to combat it,” she said.

Tough Upbringing

Fiordaliso grew up in a cold-water apartment in Newark, and he never forgot his roots as he was putting together policy, O’Malley said. That was particularly evident in Fiordaliso’s support for the state community solar program, which provides discounted clean energy to low- and moderate-income ratepayers, O’Malley said. (See NJ Opens Community Solar and Nuclear Support Programs.)

“He was a big supporter of making clean energy, especially solar, more accessible for more people,” O’Malley said. “He wanted to make sure the clean energy could reach every New Jersey resident.”

Fiordaliso graduated with a degree in business education from Montclair State University and was a teacher from 1967 to 1986, according to the university’s website. He was director of government relations for the Saint Barnabas Health Care System and served three terms as mayor of Livingston, N.J.

He was a member of the National Association of Regulatory Utility Commissioners’ Committee on Critical Infrastructure and Committee on Energy Resources and the Environment and also sat on the Executive Committee for the Regional Greenhouse Gas Initiative (RGGI) and RGGI’s Strategic Communications Team, according to the BPU website.

He also was board member of the Organization of PJM States Inc. and of the advisory council to the board of directors of the Electric Power Research Institute. In May 2023, FERC appointed Fiordaliso to the Joint Federal-State Task Force on Electric Transmission.

At the BPU’s meeting last month, Fiordaliso introduced several interns and spoke about the role of the board.

“We are doing work that’s going to help, hopefully save future generations,” he said. “It’s not many times in one’s career, and I’ve been working a long time, that you can actually say that I’m doing something that is going to affect future generations in a positive way.”

He noted that he had spent all but five years of his working life in the public sector.

“It is one of the most gratifying experiences I think a human being can have,” he said. “You may not make a million dollars but the satisfaction that you get from doing what you do is certainly worth a million dollars.”

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Report Touts Value of Demand Response, Flags Challenges Facing It

A new report dives into the role demand response (DR) and distributed energy resources (DER) play in the reliability of the rapidly evolving North American power grid.

“Unlocking the Full Potential of DERs: Overcoming Capacity Pricing and Other Barriers to Ensure Grid Reliability” is a collaboration by energy consultant Wood Mackenzie and DER developer CPower.

The report notes what the North American Electric Reliability Corporation and others have warned about: Large swaths of the United States face a growing risk of outages in peak demand periods or during emergencies as the nation moves from a centralized, predictable power flow to a distributed, dynamic grid.

The report continues:

While DR is not a baseload resource, it has proved highly reliable under severe conditions as traditional dispatchable power is supplanted by intermittent renewables.

DR, as the largest class of DER, is an increasingly important part of the resource stack in energy markets — the diverse sizes, locations and types of DR assets adds resilience and flexibility.

DR needs strong, consistent capacity price signals to promote enrollment and retention. These signals include ensuring that wholesale energy prices do not erode capacity prices; maintaining capacity pricing stability and predictability for customers who want to participate in DR programs, especially commercial/industrial customers; and addressing the common misconception that DR has zero costs and can stay in a capacity market as the price rides down to zero.

DR carries no capital costs but there are administrative and opportunity costs — so it is easy, even advantageous, for customers to stop participating when prices fall.

Adequate capacity pricing and capacity accreditation for DR are important.

The right price signals, such as a price floor, would reassure participants about the viability of the DR market.

CPower is developing what it calls the “Customer-Powered Grid” through DER monetization and virtual power plants — it has 6.3 GW of capacity at 20,000 sites across the U.S. It is owned by LS Power.

Wood Mackenzie provides global research, analysis and consulting in energy, renewables and natural resources.

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Environmental Orgs Request Rehearing on ISO-NE Reliability Program

The Sierra Club, the Union of Concerned Scientists and the Conservation Law Foundation jointly filed for rehearing Tuesday over FERC’s approval of changes to ISO-NE’s Inventoried Energy Program (IEP) (ER23-1588), arguing that ISO-NE failed to adequately justify the program and that it likely would increase costs for consumers.

The groups wrote that FERC’s approval of the program “errs in failing to examine whether tripling the costs of the [IEP] is just and reasonable in light of the lack of evidence that IEP payments would incent oil and gas generators to procure more fuel than they would otherwise.”

The nonprofits added that the commission’s decision also “errs in failing to consider new information about winter energy adequacy that is relevant to the need for the IEP, and thus to whether consumers would receive benefits proportionate to the enormous additional cost proposed.”

ISO-NE’s IEP is intended to compensate generators for keeping stored fuel onsite to ensure the region’s winter grid reliability, while the disputed changes to the program include the introduction of indexed rates meant to reflect changes in natural gas prices.

In ISO-NE’s original filing of the IEP changes, the RTO argued the changes “are designed to align key parameters of the IEP rates, terms and conditions with current market conditions and to make other improvements necessary to attract sufficient investment in incremental inventoried energy to support winter reliability.”

FERC unanimously approved ISO-NE’s proposed changes in an August ruling. (See FERC Approves Updates to ISO-NE Inventoried Energy Program.) In the order, FERC dismissed a range of complaints from the organizations and state consumer advocates related to the cost and justification of the program.

“The purpose of the Inventoried Energy Program is to incentivize resources to maintain inventoried energy to support winter reliability, and ISO-NE’s proposed revisions are designed to improve the program’s ability to achieve this goal,” FERC wrote.

In the rehearing request, the environmental organizations called FERC’s ruling “arbitrary and capricious.”

The groups wrote that FERC did not adequately consider the effect of changes to the region’s winter risk profile since the creation of the IEP, or whether the program actually would spur changes in behavior of generators. (See Study: Limited Exposure to Supply Shortfall for ISO-NE During Extreme Weather.)

“Most of the generators who receive a payment under the IEP, they’re already obligated to perform as capacity resources,” Casey Roberts, senior attorney with the Sierra Club Environmental Law Program, told RTO Insider. “In order to do that, they have to have fuel, otherwise they can’t run.”

Roberts argued FERC’s lack of scrutiny of the program’s justification and benefits sets a bad precedent for the approval of reliability programs.

“This really goes down to FERC’s core responsibility of protecting consumers from paying excessive rates,” Roberts said.

If FERC stands by its ruling, the environmental organizations could appeal FERC’s decision in court.

In June 2022, the U.S. Court of Appeals ruled the IEP could not compensate coal, hydro, biomass and nuclear generators because the incentive would not change their inventory operations. However, the court left the rest of the IEP in place, ruling that oil, natural gas and refuse generators are eligible for payments. (See Court Strikes a Blow to ISO-NE Winter Plan.)

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NRDC Lays out Responsible Tx Expansion Recommendations

The U.S. must double the number of transmission projects permitted and built each year to meet its clean energy potential, the Natural Resources Defense Council said Wednesday in a report recommending ways to speed permitting rules to allow enough construction to meet midcentury climate goals.

“We also must double the rate at which we expand the transmission system and simultaneously shift to building large interstate transmission lines instead of the small local lines that are mostly added today,” said NRDC Senior Advocate Nathanael Greene, the report’s lead author.

The Inflation Reduction Act is a huge opportunity for the country to roll out renewable energy and make significant progress on cutting greenhouse gas emissions, while the heat and natural disasters this summer show that climate change is happening and must be addressed, Greene said in an interview.

“Those two things I think allowed people to put building things higher on their priority list,” he added.

Issues around permitting have been a major focus for those working on federal energy policy all year, but so far, Congress has passed only a small package that largely ignored transmission. (See Lawmakers, White House Promise More Work on Permitting After Debt Deal.)

It is unclear whether lawmakers will be able to come up with another legislative package, but given the limited time due to the need to fund government operations and election season kicking into gear, NRDC wanted to express views on the subject to help inform any potential legislation, Greene said.

“This is an important conversation for Congress to be having because if a window opens, that’s not going to be open for long, and people need to know what’s important, what to do, what not to do,” he said. “Because it’ll have to happen quickly when it happens.”

A deal could be attached to some kind of must-pass bill this year, which would leave little time for members to examine the legislation, he added.

The report identifies four major barriers to getting needed transmission built, the first being the need to obtain federal authority to site, permit and allocate costs for large interstate lines while increasing community engagement.

FERC and the Department of Energy should work quickly to implement their strengthened authority to designate new “national interest transmission corridors,” the report said. (See States, RTOs Caution DOE on Transmission Corridors.)

NRDC is critical of FERC’s “rubber stamping” of natural gas pipelines, so it wants the agency to do more robust environmental reviews and provide stronger landowner protections when it comes to expanding the electric grid under its limited siting authority. While NRDC has litigated some of FERC’s implementation of the Natural Gas Act, that same kind of “bright line” siting authority would help expand the grid, Greene said.

“As long as it’s a political question about whether they’ll use that authority, it’s always going to be harder for them to do that permitting,” he added.

Ultimately, Congress should pass a law giving DOE authority to plan and FERC the ability to site large, interstate transmission lines, the report said.

Given that many of the projects NRDC wants to see built will cross state lines, having federal agencies planning and siting them makes sense, Greene said.

Another major recommendation is for FERC to “consider all the benefits of transmission” and then allocate them based on who benefits. The commission can implement rules to broadly allocate costs of new transmission to states, but if it fails to do so, then Congress should pass legislation requiring that, the NRDC said.

A pending notice of proposed rulemaking would update FERC’s planning and cost allocation rules. And while Chairman Willie Phillips has called that a priority, it has yet to pass.

Dealing with NIMBY

The report’s second recommendation is meant to deal with the opposition transmission projects often encounter because people do not want major infrastructure built near their homes, but that can be minimized by making community engagement a pre-requisite to siting rather than an afterthought.

“We know all the pieces of doing permitting better,” Greene said. “We just need to integrate and hold people accountable.”

The report suggests ensuring that communities gain benefits from hosting clean energy infrastructure. Specific benefits would vary by project, but they include jobs, environmental protections, financial contributions and energy benefits.

“Some developers already routinely negotiate community benefit packages for their projects,” the report said. “States should incentivize or require this as a best practice.”

The Inflation Reduction Act also earmarked money to help beef up permitting regulators in the states so they can adequately review the expanded pace of transmission development, Greene said.

The report’s third recommendation is to improve federal coordination, accountability and staffing of clean energy permitting and environmental reviews. That can be done without undermining the purpose behind the National Environmental Policy Act, the report said.

“Environmental reviews can be made much more efficient through increased agency resources, greater use of programmatic reviews, and permitting solutions that are tailored specifically to clean energy projects,” the report said.

The final recommendation is to embrace “smart from the start” planning to ensure that clean energy projects deliver conservation benefits and mitigate the impacts. That involves early and robust stakeholder engagement, planning at a landscape level, conservation of lands with important natural resources and cultural values, and moving projects to “low-conflict areas.”

“‘Smart from the start’ is designed to make permitting more efficient and to protect high-value lands by strategically focusing on regional or landscape-level efforts to mitigate the impact of renewable energy resources,” the report said. “These larger mitigation efforts often produce greater conservation outcomes than disparate project-level mitigation.”

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Report: Many US Utilities not Delivering on Energy Efficiency

Eversource Massachusetts scored 85 out of 100 points, taking the No. 1 spot on the American Council for an Energy Efficient Economy’s (ACEEE) 2023 Utility Energy Efficiency Scorecard, while Florida Power & Light and Ohio Edison held down the bottom of the list with 3 and 2.5 points respectively.

Published every three years, the recently released scorecard reflects the uneven, inconsistent role that energy efficiency plays in U.S. utilities’ efforts to decarbonize their power supplies, help customers cut their monthly energy bills and make their systems more resilient. The 53 utilities ranked on the scorecard, some of the nation’s largest, serve about 79 million residential customers, or 60% of U.S. households, in 31 states, the report says.

With their “enormous customer bases and the ability to scale solutions … the utility sector is perhaps the best positioned of any sector to deliver energy savings to Americans,” said Mike Specian, ACEEE’s research manager and lead author of the report. But, the scorecard shows, many are not doing so.

At the top of the list, 16 utilities managed to earn more than 50 points, and at the bottom, 16 earned less than 25.

Based on 2021 data, the scorecard shows investments in and energy savings from utility efficiency programs trending downward, Specian said. Total energy savings across all 53 utilities were 18.7 TWh in 2021, a 5.4% decrease since ACEEE’s last utility scorecard in 2020, which was based on 2018 data.

Utility spending on efficiency totaled $7.6 billion in 2021, a 4.9% drop from 2018, which, ACEEE said, contributed to a 19% drop in peak demand reduction. On average, U.S. utilities are spending 2.23% of their revenue on efficiency programs.

The figures for individual utilities underline the negative impact of these trends. Entergy Louisiana (No. 43, with 17 points) spent 0.21% of its revenue on energy efficiency, less than one-tenth of the national average. As a result, the utility’s energy efficiency programs shaved a meager 0.1% off its energy sales.

The caveat on such figures, and the rankings in general, is that they are based on data from 2021 and therefore may not reflect any changes in efficiency programs utilities might have made since then. In particular, as load management technology ― like smart thermostats ― evolve, lines between efficiency and demand response are starting to blur.

David Jacot, director of efficiency services at the Los Angeles Department of Water and Power (LADWP), said the public power utility recently consolidated its efficiency, DR and distributed energy services as part of its aggressive efficiency goals, a development not reflected in the scorecard.

But, Specian cautioned, most utilities are not connecting their energy efficiency programs to their decarbonization or emission-reduction goals. “In fact, 28 of our 53 evaluated utilities have established some form of carbon-reduction goals, [but] those targets have yet to work their way into efficiency programs,” he said.

Only the two Massachusetts utilities, Eversource Energy and National Grid, have “explicitly incorporated [greenhouse gas] reduction goals into their energy efficiency programs,” he said.

If and to what extent the billions in funding for energy efficiency in the Inflation Reduction Act will affect utility programs remains uncertain, in large part because, like other IRA programs, the incentives and rebates for efficiency have been slow to roll out.

The IRA’s $8.5 billion for rebates and tax credits for energy-efficient home upgrades will be administered by the states, and the U.S. Department of Energy only recently opened the application process for states to submit plans on how they will ensure the money is used to cut consumer energy bills and emissions. (See DOE Opens Applications for $8.5 in IRA Home Efficiency Funds.)

Utilities could have a central role in these programs for raising customer awareness of the IRA rebates and incentives. Many utilities already offer rebates on efficient appliances and promote their expertise as “trusted advisers” for customers considering home upgrades.

State Regulation

Downward trends notwithstanding, during a recent webinar on the scorecard, Specian focused on the report’s more encouraging findings, such as the correlation between state energy efficiency mandates and utility performance, and increasing investments in efficiency programs for low-income customers.

Utilities at the top of the list, as well as those that shot up in the rankings, often are in states that have set targets for utility efficiency programs.

Michigan, for example, passed its first energy efficiency law in 2008, requiring utilities to meet specific savings goals, and then upped the targets in 2016. Home-state utilities DTE Energy and Consumers Energy have exceeded those mandates every year, putting them in the scorecard’s Nos. 5 and 6 spots, respectively.

Dominion Energy was the scorecard’s most-improved utility, jumping from No. 50 in 2020 to No. 27 this year. Specian attributed its better performance, in large part, to efficiency goals set in Virginia’s Clean Economy Act, passed in 2020.

At the same time, rankings for Ohio utilities nosedived this year after the state legislature passed a law in 2019 ending its energy efficiency standards. Duke Ohio and AEP Ohio fell from No. 18 and No. 21, respectively, to tie for No. 49 this year. Ohio Edison tumbled from No. 34 to the very bottom of the list.

State mandates also can act as a brake on utility innovation. Public Service Electric and Gas rose from No. 42 in the 2020 rankings to No. 25 this year, largely because of New Jersey’s efficiency targets. But Susanna Chiu, PSE&G director of energy services, said regulations set by the Board of Public Utilities create a three-year cycle for planning new utility efficiency programs.

The current cycle, which runs through June 30, 2024, did not include decarbonization or more innovative DR programs. Those will have to wait for the next three-year planning cycle, which will run from mid-2024 to mid-2027, Chiu said. PSE&G is envisioning a one-stop-shop approach in which customers can choose efficiency services that are customized for their homes and their own efficiency and decarbonization goals, she said.

Low-income Programs

Total utility spending on efficiency may have dropped, but the money spent on programs for low-income customers has grown to more than 12% of overall efficiency spending — a 17% increase since the 2020 report — resulting in an 9.5% increase in savings per residential customer, Specian said.

Digging in deeper, ACEEE added new categories on equity to this year’s scorecard, which revealed some of the gaps that still exist in efficiency programs for low-income customers. Baltimore Gas and Electric dropped from No. 5 in 2020 to No. 12 this year, after losing points on some of the new equity categories.

In a separate, written analysis of the utility’s score, Specian praised BGE for its innovative program offerings, including “12 valuable efficiency programs not commonly available across the rest of the country.” Yet the utility lost points for “a lack of efficiency workforce initiatives, low levels of community engagement during program development and a failure to direct customers at risk of utility shutoff toward efficiency programs that could lower their bills,” he said.

Speaking during the webinar, Sanya Carley, professor of energy policy and city planning at the University of Pennsylvania, said efficiency programs can be a critical tool in helping low-income customers avoid disconnection.

A 2020 report from ACEEE found that low-income households have a heavier “energy burden,” spending 8.1% of their disposable income on energy versus the 2.3% for more well-off households.

Only 13 utilities on the scorecard direct customers at risk of disconnection to efficiency programs, Carley said, and existing efficiency programs may not address the needs of such “energy insecure” households. Living in an energy-inefficient home ― with gaps in walls, or windows that don’t close ― is one of the factors that may signal risk of disconnection, she said.

Carley has collaborated with researchers at the University of Indiana to launch an online Utility Disconnection Dashboard, tracking disconnections across the country.

“Some of the same utilities that have the highest rates of disconnection are the ones not directing their customers toward energy efficiency,” she said. “Does this mean that energy efficiency programs are too late to help or too little? The data don’t reveal answers to these questions, but we should of course ask them.”

Efficiency After LEDs

While it was not part of individual rankings, ACEEE did ask utilities what they see as major barriers to energy efficiency.

Responses ranged from the predictable ― inflation, supply chain delays and lack of skilled workers ― to the more existential, such as the rising cost of efficient technologies once programs address “low-hanging fruit,” such as switching out older light bulbs for LEDs.

“Utilities that have been successfully implementing energy efficiency for years reported experiencing market saturation for some efficiency measures and decreasing amounts of remaining savings,” the report says. “Others claimed that there was no technology that could easily fill the gap left by lighting.”

Lakin Garth, director for emerging technologies at the Smart Electric Power Alliance (SEPA), agrees some utilities eventually may face a declining stock of buildings to retrofit.

“You’ve got a certain number of buildings out there, and you’re acquiring all the most cost-effective energy efficiency over a three-, four- or five-year period. … Those same opportunities might not be there in six or seven or eight years,” Garth said. “But that doesn’t mean that the investment itself should decline.”

According to the National Association of Home Builders (NAHB), close to half of all homes in the U.S. were built before 1970 — before the first energy efficiency codes were passed later in the decade. California’s first energy efficiency code was adopted in 1976 and is updated every three years.

Given the large opportunity the NAHB figures represent, Vincent Barnes, senior vice president of policy and research at the Alliance to Save Energy, says the key obstacles to utility energy efficiency programs are utility regulation and business models.

“We don’t treat energy efficiency at par with other energy resources that utilities can respect as an asset,” Barnes said. “It really is about looking at energy efficiency as an energy resource and therefore identifying energy efficiency investments as capital investments — like transmission, like distribution — and the reason we have to do that is because the way the structure is currently set up, the only assets are supply-side assets.”

Energy efficiency programs address customers’ consumption behind the meter, he said. “It’s not until we’re able to identify those investments that are behind the meter, and energy efficiency also, as capital assets, [that we will] be able to actually achieve that greater investment number that we might be looking for.”

One encouraging development, Barnes noted, is that PSE&G has gained approval from the BPU to treat at least some of its energy efficiency investments as “regulatory assets” that can be included in the utility’s rate base.

Chiu confirmed that such efficiency investments do “earn a return … which makes those investments an alternative to pipes and wires.”

LADWP’s ‘Headroom’

In the No. 10 spot, LADWP is the highest scoring of the three public power utilities on the ACEEE scorecard. The other two are Long Island Power Authority (No. 16) and the Salt River Project (No. 23).

As an unregulated utility, LADWP has been able to approach efficiency from a totally different angle, Jacot said. “We really got in earnest behind energy efficiency around 2010 and made it a part of what we call our supply portfolio,” he said. “In other words, we treat energy efficiency as a generation resource … the cheapest marginal generation resource.”

Between 2010 and 2020, the utility cut its retail kilowatt-hours by 15% and is on track for another 15% cut by 2030, Jacot said, and those savings have created “headroom” for LADWP to absorb new load without building new generation.

Vehicle electrification is a case in point. As the utility’s customers plug in their Teslas and Ford F-150 Lightnings, “we’ve created the headroom through energy efficiency; that capacity is already there,” he said.

LADWP will have to build out its system eventually to meet the demands of widespread electrification and more frequent and intense heat waves, but the utility’s aggressive efficiency programs have bought it some time, he said.

Jacot stressed the ability of public power utilities like LADWP to innovate and try out new programs quickly, without going through the drawn-out regulatory approval process investor-owned utilities typically face. With the integration of LADWP’s efficiency and DR programs, Jacot is overseeing and exploring new possibilities for both programs.

“I can coordinate not only overall energy use reduction but smart energy management and load-shifting capabilities,” for example, using smart thermostats and heat pump water heaters, he said.

Heat pumps can be set at a variable speed to reduce overall consumption, and then set to run at specific times of the day for DR, he said.

Like PSE&G, LADWP’s goal is to have a one-stop-shop for customers to take advantage of both efficiency and DR programs, he said.

Next-gen Efficiency

Today’s energy efficiency programs trace their roots to the 1973 oil crisis, when the Middle Eastern countries in the Organization of Petroleum Exporting Countries slapped an embargo on exports to the U.S. to protest American support for Israel.

Efficiency then meant closing schools and businesses, rationing gasoline and reducing speed limits on the nation’s highways to 55 mph.

The challenges today are technologically more complex but could be equally essential to President Joe Biden’s goals of decarbonizing the grid by 2035 and building out a net-zero economy by 2050.

At LADWP, Jacot sees the value of efficiency evolving in different directions as solar and storage come on the grid.

“We’re in a transitionary period where energy efficiency at some points of the day actually doesn’t do you much good,” he said. Specifically, during mid-day peaks in solar production, “energy efficiency isn’t really helping. … So, the quantification of the benefits of energy efficiency on the demand side, the kilowatt side, is very much in transition.”

However, Jacot said, as more storage is deployed to sop up excess solar production, and electrification drives more demand for power, LADWP will “want all the energy efficiency we can get because it increases the amount of available storage and lowers the amount of storage you need to get through the night.”

SEPA’s Garth also sees efficiency as essential for maintaining reliability and affordability as the grid is decarbonized and transportation and buildings are electrified.

“If we’re electrifying or planning to electrify all these uses, then these utilities should be thinking about how to do that in the most efficient way possible,” he said. “Probably the next generation of efficiency programs is how do we electrify responsibly and efficiently and how do we identify the parts of the market that have been overlooked in the past?”

But producing the clean power needed for electrification will require significant capital investments, which utilities could seek to recover through higher rates, he said. “So, it only seems logical that in a decarbonized world … the investments made in energy efficiency are commensurate with the investments that are made to clean up generation or to reduce carbon emissions.”