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November 15, 2024

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NJ Senate Committee Backs Clean Energy Bills

The New Jersey Senate Environment and Energy Committee last week backed bills that would increase the state’s planned community solar program by 50% and create a series of pilot electric vehicle charging depots that would be served by distributed energy resources.

In its Feb. 16 meeting, the committee also endorsed a bill to create a new position, the clean energy advocate, who would coordinate, and solicit cooperation, from stakeholders to assist the “implementation of interagency clean energy projects.”

“This is not an effort to increase the size of government,” said Sen. Bob Smith (D), who sponsored the bill and serves as chair of the committee. “It’s to try and get government to work better, faster and more efficiently.”

S3556 would create a full-time position whose incumbent would serve “at the pleasure” of the president of the New Jersey Board of Public Utilities. The advocate would ensure that approved programs move forward and the necessary rules and regulations are in place.

In arguing for the need for the position, Smith cited a law that Gov. Phil Murphy (D) signed in July 2021 that requires the state within 180 days to create the rules of a pilot program that would enable the construction, installation and operation of dual-use solar projects. That task has not yet been completed nearly 600 days later, Smith said. (See NJ’s $2M Agrivoltaics Study Advances.)

The goal is for the clean energy advocate to “make sure everybody is coordinating their effort, so that all of the departments are on the same page” and that “timely and successful interagency implementation actually occurs,” Smith said.

The committee passed the bill with a 3-1 vote. Sen. Edward Durr (R) expressed concern that the bill would needlessly increase the size of government.

Expanding Community Solar

The three bills advanced two days after Murphy injected urgency into the state’s clean energy initiatives by accelerating the state’s target for achieving 100% renewable electricity in the state from 2050 to 2035 and outlining several other measures.

Those include setting up a process toward the adoption of California’s Advanced Clean Cars II rules, which would require all new passenger vehicles sold in the state to be zero-emission vehicles by 2035. The governor also signed an executive order requiring the installation of electric heating and cooling equipment in 400,000 homes and 20,000 commercial properties by 2030. (See NJ Governor Sets Out Accelerated Emissions Targets.)

The committee backed the expansion of the state Community Solar Energy Program with a 3-1 vote after a much larger proposed expansion faced opposition in November from the BPU, which argued that it could not handle such a sudden increase. After two pilot solicitations, the board is currently drafting a permanent 150-MW/year community solar program, significantly smaller than the 500 MW of available capacity annually proposed in past legislation. (See NJ BPU Opposes Community Solar Program Expansion.)

The amended legislation, S3123, would create a program offering capacity of 225 MW in the period before June 1, 2024, and another 225 MW after. In the years after 2025, the available capacity would be 150 MW.

BPU and other state officials consider the program, which drew 650 applications and awarded 240 MW of capacity in the two pilot solicitations, a great success. It enables energy users who either cannot or do not want to have solar on their roofs to sign up for renewable energy.

Still, the New Jersey Division of Rate Counsel in a Feb. 15 letter urged the committee not to back the amended legislation, saying it would create “undesirable results” for ratepayers, such as increased costs. It would “crowd out less expensive grid supply projects” and undermine BPU efforts to create competition in the community solar solicitation process, the division wrote.

“Limiting the amount of solar that can compete to drive prices downward ultimately hurts ratepayers by resulting in higher, administratively set prices,” it said.

He added that creating the capacity by legislation would “set a precedent” that could open the way for future legislation to set capacity levels, rather than the BPU setting levels through “expert assessment of the market.”

The bill, however, drew support from the Solar Energy Industries Association, a few solar industry players, and environmental groups Environment New Jersey and New Jersey League of Conservation Voters.

Allison McLeod, policy director for the league, said the community solar program provides a way for people who “don’t have access to their own roofs,” such as those in multiunit dwellings, to benefit from solar.

“So far a lot of the solar program has been for those who own their own homes [and] have their own roof access,” she said. “So as we expand into our clean energy future, we want to make sure it’s accessible to all, including moderate- and low-income folks.”

Nurturing Off-grid Charging

The committee unanimously passed S3224, a bill that would require the New Jersey Economic Development Authority, which provides financing for much of New Jersey’s clean energy projects, to work with the BPU and Department of Environmental Protection to develop a request for proposals to attract developers interested in creating the EV charging depot.

The bill also secured unanimous approval from the 12-member Assembly Transportation and Independent Authorities Committee the same day.

The “demonstration program” proposal would create charging depots in six locations, with one in the service territory of each of the state’s utilities.

“Each electric vehicle charging depot shall be serviced by one or more distributed energy resource charging centers,” according to the bill. The depots, it added, should “at minimum be capable of supporting very high, coincident peak vehicle electric loads,” and should also be connected to a utility or to PJM.

Still, Sen. Smith said, the focus of the program is “not a grid issue.”

“The station will be providing its own power for the charging,” he said.

Each proposal must compile and report the “cost-saving, time-saving and resilience metrics” that stem from the project drawing energy from a DER, rather than from the public utility grid, the bill says.

The bill drew support from the business community, including from the Chamber of Commerce Southern New Jersey, the state Chamber of Commerce, the New Jersey Business and Industry Association, and Environment New Jersey.

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NERC Report Highlights ‘Transformational’ 2022

Last year represented a “transformational” one for NERC, as the ERO faced wide-ranging challenges such as cyber and physical security, extreme weather, and a changing resource mix that “it is abundantly clear” will only become more pressing in 2023, CEO Jim Robb said in the organization’s annual report released Tuesday.

“As I begin my fifth year as CEO, I can’t help but reflect on the extraordinary transformation of the resource base that is occurring, the challenges associated with extreme weather systems and the transformation of the ERO Enterprise toward operating as one synchronous machine,” Robb said in the report. “I’m pleased with how far we have come in a relatively short time with the complex and rapidly evolving risk and threat environment across North America.”

The report highlighted NERC’s major achievements last year, organized by the five key focus areas from the ERO Enterprise Long-term Strategy published in 2019, and the objectives associated with each area.

In the first section, “Expanding risk-based focus in standards, compliance monitoring, and enforcement,” NERC highlighted its shift “to a holistic, risk-based approach to compliance” that allows the ERO Enterprise to “apply resources to the most significant reliability risks and better respond to emerging risks.” NERC’s efforts in this area included its work on reliability standards related to physical and cybersecurity such as CIP-014-3 (Physical security), approved by FERC in June, and the cyber supply chain standards that became effective in October. (See FERC OKs Updated Supply Chain Standards.)

NERC also touted the completion last year of its new extreme cold weather standards, calling winter weather “one of the most critical and high-priority challenges currently facing [the electric] industry.” FERC approved the standards last week, while pushing the ERO to continue its development work. NERC’s report was written before the commission granted its approval but acknowledged that “work is presently underway to address” issues identified after the February 2021 winter storm. (See FERC Orders New Reliability Standards in Response to Uri.)

Security Collaboration Opportunities

Security was also addressed in a section of the report discussing the Electricity Information Sharing and Analysis Center (E-ISAC), which “worked to stay ahead of these challenges” by improving its own products and services, and by pursuing partnerships with other critical infrastructure sectors and the government.

Cross-border cybersecurity threats were a constant theme in 2022, thrown into sharp relief by Russia’s invasion of Ukraine that began last February. Even before the invasion, the Department of Homeland Security’s Cybersecurity and Infrastructure Security Agency launched its “Shields Up” campaign to remind infrastructure operators to improve cyber defenses and be vigilant against potential intrusions. (See Utilities Warned of Cyberattacks amid Russia Tensions.)

The E-ISAC played its part in the collective security posture by activating, with its sister organizations from other sectors, the Tri-Sector All-Hazards Playbook. NERC said the E-ISAC is now updating the playbook “based on lessons learned from this year’s coordination.” The organization is also developing the Energy Threat Analysis Center alongside the Department of Energy to coordinate security activity among utilities and government agencies.

NERC addressed further collaboration activities in its section on “strengthening engagement across the reliability and security ecosystem in North America,” highlighting its communication with state, provincial and federal authorities across the U.S. and Canada. The report also mentioned collaboration efforts with electric industry stakeholders in Europe, Africa and South America.

Identifying Improvement Areas

Another focus area concerned “steps to mitigate known and emerging risks to reliability and security” and is related to the ongoing transition of the North American electric grid to carbon-free resources. NERC’s discussion of these items in the annual report mainly dealt with its reliability assessments — including its seasonal and long-term assessments — and the annual State of Reliability Report.

NERC also highlighted its inverter-based resource and distributed energy resource strategy documents, published in September and November, respectively, to outline work needed to address the promises and pitfalls of the new generation fleet, along with its reports on disturbances involving wind and solar generators that “illustrate the need for immediate industry action” to address their performance issues.

Finally, the ERO discussed its efforts to capture opportunities for “effectiveness, efficiency and continuous improvement.” In this section NERC primarily highlighted the introduction of the Align software tool and ERO Enterprise Secure Evidence Locker, which began in 2021 and continued throughout 2022.

In addition, the organization mentioned its initiatives to improve workplace culture and give staff more flexibility in arranging their work schedule. These efforts include NERC’s new office space in D.C., dubbed the “Collaboration Hub,” that reduced working space needs “while still providing a space for the ERO Enterprise and stakeholders to connect and collaborate.”

“Fulfilling NERC’s statutory mandates and tackling the new challenges before us requires a step change in how we fulfill our mission,” Board of Trustees Chair Ken DeFontes said. “This step change requires all of us to look differently at NERC’s priorities and the resources required to accomplish these shared goals … through a new lens — one focused on agility, adaptation and aggregated approaches. Managing the pace of change is a challenge for reliability, and we need to ensure that our own efforts adapt to this pace when appropriate.”

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PSEG CEO Says Need for ‘Predictability’ Drives OSW Sale

Public Service Enterprise Group CEO Ralph Larossa said Tuesday that the utility is “not going to be” in the offshore wind business but sees potential in keeping its three nuclear plants alive now that they are eligible for federal tax credits under the Inflation Reduction Act (IRA).

Larossa made his comments during the company’s year-end earnings call, the first since the utility announced it would sell its 25% stake in Ocean Wind 1, New Jersey’s first offshore wind project, which will be fully owned by Danish developer Ørsted. Larossa said the sale, which is expected to close in the first half of the year, would bring in about $200 million, the same that the company paid for it.

“Just unequivocally, we’re not going to be in the offshore generation business,” Larossa said in response to a question from an investment analyst. “We’ll just be keeping an eye on the market and see what makes sense.”

The utility also has decided not to pursue an ownership interest in Ørsted’s second New Jersey project, Ocean Wind 2, and won’t exercise its option to purchase 50% of Ørsted’s two Skipjack generating projects in Maryland, the utility said in a release. The utility also is mulling whether or notto sell its 50% interest in Garden State Offshore Energy, which holds rights to an offshore wind lease area south of New Jersey.

“This decision to exit offshore generation was consistent with our goal to increase the predictability of our business,” Larossa said. However, the utility will provide onshore construction management and substation and cabling work for the project and will “continue pursuing regulated transmission projects offshore,” he said.

PSEG last year partnered with Ørsted to submit several proposals for a New Jersey Board of Public Utilities solicitation seeking ways to upgrade the state’s transmission system to handle offshore wind, but none were picked. (See PSEG Sees Potential $3B OSW Transmission Spending.)

Game Changer

Larossa said he considered the passage of the IRA a “game changer” that should provide the “stability required for long-term financial viability” for the nation’s nuclear generators. The utility owns the Hope Creek nuclear station and co-owns the Salem reactors with Exelon.

The BPU in 2019 and 2021 awarded PSEG a total $600 million a year for three years under the state’s Zero Emissions Certificate (ZEC) program, which provides subsidies to nuclear plants that demonstrate they are at risk of closure. (See NJ Nukes Awarded $300 Million in ZECs.)

The IRA awards a tax credit of 0.3 cents/kWh of power produced to qualified nuclear power generators, a subsidy that can be five times larger if the facility pays prevailing wages.

“As a result of the nuclear production tax credits extending through at least 2032, we are now able to consider small but important value added investments,” Larossa said. These include “the potential for capacity upgrades to Salem, a fuel cycle extension to Hope Creek and the license extension of our New Jersey units.”

“Critical to these decisions will be our determination of how predictable and visible nuclear revenues could be beyond our current three-year ZEC window,” he said.

In addition, he said the utility sees potential from IRA subsidies that could prompt consumers to transition to electric vehicles, which will “expand our opportunities to invest in last-mile reliability and make-ready infrastructure,” he said.

Larossa also said PSEG’s focus on clean energy, with the company last year completing the sale of the last of its fossil-fueled generating plants, aligns with that of New Jersey Gov. Phil Murphy and the state legislature.

Murphy last week announced an acceleration of the state’s clean energy goals, moving the target date by which the state should reach 100% clean electricity from 2050 to 2035. He also said the state would soon begin the process of adopting a version of California’s Advanced Clean Cars II rules, which would ban the sale of new gasoline-powered cars by 2035. (See NJ Governor Sets Out Accelerated Emissions Targets.)

Murphy also signed an executive order that would require the installation of electric heating and cooling equipment in 400,000 homes and 20,000 commercial properties by 2030, a sign of his determination to move the state away from gas-fired heating and hot water units.

“There’s a lot of good news in that announcement last week for a company like ours,” Larossa said, noting that the utility has placed a high priority on upgrading the “last mile” connections with customers that will become even more crucial with the increase of EV chargers.

“I think this just kind of reinforces the need for it from a customer standpoint or from a reliability standpoint,” he said.

Larossa added that the company’s gas business has not suffered fallout from Russia’s invasion of Ukraine. “We are not as dependent on Russian fuel supply at all for our fuel supply,” he said.

He also said he was not worried about the impact of New Jersey shifting away from gas and electrifying.

“It’s a mixed bag for us,” he said. “We have some gas-only territory, some electric-only territory. But the bulk of our customers are combined. So you know, I don’t want to say it’s a win-win. But it is a win-win for us to a great extent.”

Q4 Results

PSEG’s full-year and fourth-quarter results improved on 2021.

The company reported 2022 net income of $1,031 million ($2.06/share), compared with $648 million ($1.29/share) for 2021. Net income for the fourth quarter was $788 million ($1.58/share), compared to $445 million ($0.88/share) a year earlier.

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EEI Welcomes ‘Clean Slate’ on Permitting

Edison Electric Institute officials said Tuesday they are pursuing a “clean slate” on siting and permitting legislation in Congress and optimistic that they can help craft a bipartisan package after the failure of Sen. Joe Manchin’s (D-W.Va.) proposal last year.

“We’re interested now in what has been described by members of Congress as a clean slate, simply because that [Manchin] proposal didn’t get a lot of support,” Brian Wolff, EEI’s executive vice president for public policy and external affairs, said during the organization’s annual Wall Street briefing. “And we are engaging with Chairman Manchin, but we’re also engaging with House Republicans; we’re really going at this in a different way, so it’s a different process.”

EEI Wall Street Briefing (Edison EIectric Institute) Content.jpgAppearing at the Edison EIectric Institute’s annual Wall Street briefing were (from left) EEI President Tom Kuhn; Brian Wolff, executive vice president, public policy and external affairs; Emily Sanford Fisher, general counsel; Phil Moeller, executive vice president, business operations and regulatory affairs; and Richard McMahon, senior vice president, energy supply and finance & chief ESG officer. | Edison EIectric Institute

Wolff said EEI, which represents investor-owned electric utilities, expects to work on the legislation for most of the year, with General Counsel Emily Sanford Fisher seeking to win consensus on a set of “guiding principles.”

The Manchin proposal “at the end of the year was just kind of pushed … very quickly through the process, [so] we really didn’t get a lot of opportunity to make sure that they understood our constructive points,” Wolff said. (See Manchin Permitting Bill Falls Short in Senate.)

Fisher said EEI seeks “basic good governance” changes to provide “certainty that the permits that are issued and the environmental reviews that are completed are durable and can survive legal review.”

EEI President Tom Kuhn said the Republicans who control the House of Representatives and the Democrats controlling the Senate could find their way to a deal.

“The Republicans may want more pipelines approved in a shorter period of time. The Democrats want to make sure that the renewable energy out there can come on at a decent pace and the transmission can be built. So those dynamics are helpful,” Kuhn said.

“We still have the help of environmental groups and industry groups … so we are hopeful. It is complicated, but it is something that we’re all behind, and we’re going to continue to push in a major way,” he added. “I think that [it will lead] to the realization that we’re just wasting a lot of money [and] a lot of time at a period of urgency for us to move forward.”

Philip Moeller, executive vice president of business operations and regulatory affairs, also spoke of “urgency.”

“And not only for the clean energy transition, but resource adequacy issues, congestion issues; as we electrify more, we need more transmission, and we need it sooner rather than later,” he said. “So what accelerates that, and what hinders it and adds to more delays, that’s kind of the lens that I think we look through. …

Transforming the Energy Mix (Edison EIectric Institute) Content.jpgThe U.S. electric power industry has reduced its reliance on coal and increased its use of natural gas and renewables since 2012, according to data from the Energy Information Administration. | Edison EIectric Institute

 

“So if there’s legislative language that just kind of confuses things or leads to more litigation, you know, that’s not good. Similarly, if there’s a FERC proposal that sets in another layer, like an independent transmission monitor, is that helping to speed things along? That’s the lens that we have to look through.” (See States Urge More Transparency on Tx Planning, Independent Monitors.)

Moeller also urged policymakers not to “slow up the queue reform that’s already going on in some of the RTOs. They’re on it. Don’t mess it up. That’s kind of been our philosophy.”

Fisher said EEI is seeking regulatory relief in addition to permitting legislation. “There are also things that we can do, both at FERC and [the Department of Energy] and at [the Interior Department] to help accelerate those processes now,” she said. “And so we’re sort of dual tracking a legislative and regulatory effort.”

Moeller, a FERC commissioner from 2006 to 2015, said he was optimistic that stakeholders can overcome the cost allocation challenges that have made interregional transmission difficult.

“It’ll be trickier, but doable, when we talk about projects between regions,” he said, citing SPP and MISO’s Joint Targeted Interconnection Queue projects. (See MISO, SPP Update Stakeholders on Joint Tx Planning.)

“Those are solvable problems with the right people at the table with the right attitude,” Moeller said “If you look kind of what’s going on in SPP and MISO, [the] right attitude, right commitment can make things happen.”

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NextEra, SREA Protest Canceled MISO Project at FERC

NextEra Energy Transmission and the Southern Renewable Energy Association (SREA) have asked FERC to intervene in a last-ditch effort to save the only competitive transmission project ever approved for MISO South.

The two lodged separate protests after MISO filed at the commission in January to terminate its executed selected developer agreement with NextEra Energy Transmission (NEET) Midwest (NYSE:NEE) to construct the $115 million, 500-kV Hartburg-Sabine Junction project in East Texas (ER23-865).

The grid operator determined there wasn’t a need for the project last year, saying its benefits evaporated because of recent Entergy (NYSE:ETR) generation additions in the region. (See MISO Cancels Hartburg-Sabine Competitive Project.)

When Texas passed a right-of-first-refusal (ROFR) law for incumbent developers in 2019, a struggle percolated over whether NEET Midwest, MISO’s originally selected developer for the project, or Entergy Texas would build the line.

NEET told FERC in its filing that it is “optimistic” it can resume the project’s development following the 5th U.S. Circuit Court of Appeals ruling last year that the law discriminates against nonincumbents in the portions of Texas belonging to interstate transmission systems. Texas has since appealed the ruling to the Supreme Court. (See Texas Petitions SCOTUS to Review ROFR Ruling.)

The transmission developer told FERC that MISO’s cancellation of the project was premature. It said the grid operator “failed to appropriately weigh the full array of potential consequences of termination, like evaluating the true cost of canceling the [project] where it may more efficiently address identified system needs as compared to other projects proposed for inclusion” in MISO’s annual Transmission Expansion Plan (MTEP).

NEET pointed to the $1.1 billion, 150-mile, 500-kV line and substation project that Entergy Texas proposed for reliability purposes in MTEP 23. It implied that MISO is better suited to system planning than Entergy, which has sparked debate among stakeholders over whether the utility is attempting to dodge more efficient and regionally allocated transmission projects. (See Initial MTEP 23 Ignites Familiar Arguments over MISO South’s Reliability Spending.)

“Termination of the project at this time would leave real benefits on the table for customers in the MISO South region and potentially incentivize incumbent utilities in RTO/ISO regions to use litigation and other delay tactics as a method to undermine competitive transmission development in favor of potentially more expensive and less efficient solutions that are less likely to offer the same level of cost-containment mechanisms typically offered by developers through the competitive planning processes implemented by RTOs/ISOs,” NEET argued.

MISO approved Hartburg-Sabine as a market efficiency project under MTEP 17. The project was expected to alleviate congestion, ease import limitations and allow access to lower-cost generation for customers in the chronically congested West of the Atchafalaya Basin and western load pockets in Entergy’s MISO South footprint.

SREA accused Entergy of using “an anticompetitive strategy of capturing, delaying and/or canceling transmission projects with local generation assets at significant cost to local ratepayers, while at the same time not resolving underlying load pocket problems.”

The industry association maintained there still might be a need for Hartburg-Sabine because MISO performed only a “limited” benefits screen in its latest analysis of the line. It added that since 2017, the grid operator hasn’t performed a congestion analysis for MISO South, so the region could be in considerable need of prudent planning.

SREA lamented that Hartburg-Sabine has gone the way of the Waterford-Churchill economic project in Entergy Louisiana territory. The utility and MISO agreed to build the 230-kV project in 2016. Four years later, Entergy canceled the project after it built the nearby 950-MW St. Charles combined cycle gas turbine.

The association said Entergy is trying to resuscitate the Waterford-Churchill project in MTEP 23, rebranding it as a baseline reliability project rather than a competitively bid market efficiency project. Baseline reliability projects in the MISO footprint are proposed by transmission owners, not cost shared, and billed only to the local transmission zone in which they’re located.

“The cancellation of Hartburg-to-Sabine at this particular moment without a deeper analysis of the project could simply extend an ongoing trend in inefficient planning,” SREA told FERC.

Entergy filed in support of MISO’s decision to terminate, saying that Hartburg-Sabine “will not provide any meaningful adjusted production cost benefits, that terminating the project will not adversely affect reliability and that continuing to include the project in transmission models could distort transmission planning processes and potentially harm stakeholders.”

The utility also disputed that its proposed reliability project in MTEP 23 shares characteristics with Hartburg-Sabine. In an emailed statement to RTO Insider, Entergy spokesman Neal Kirby said the company will address the allegation in an upcoming FERC filing.

Kirby said the two projects are “completely different in location, scope and scale, and address different needs.”

“The MTEP 23 project travels from near the Texas border deep into the western region and allows increased imports of power to mitigate against risks during high load conditions or if generators in the western region are unavailable,” he said. “By contrast, the Hartburg-Sabine project travels a short distance entirely within the eastern portion of Entergy Texas’ service area and provides few if any of the benefits of the MTEP 23 project. In fact, as MISO’s analysis shows, it provides no meaningful benefits, let alone benefits exceeding costs.”

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Energy Tech Group Pans Duke Indiana’s Planned Gas Plant

A trade association representing emerging energy technologies is criticizing Duke Energy Indiana’s proposal to build a natural gas power plant, saying a greener collection of solar, wind and storage resources can annually save customers several million dollars.

Advanced Energy United (AEU) released a report in February assessing alternatives to Duke Energy Indiana’s (NYSE:DUK) 2021 integrated resource plan that proposes to build a 1,221-MW combined cycle plant by 2027. The clean-energy advocacy group tapped consulting firm Strategen to assess Indiana’s changing market dynamics and develop a clean-energy portfolio to “match or exceed the energy and capacity” from Duke’s proposed gas-fired plant.

Strategen and AEU concluded that a combined 2.9 GW of energy from wind (1,600 MW), solar (1,300 MW) and four-hour battery storage (900 MW) could save ratepayers $68.5 million in 2027. AEU said it anticipates savings in subsequent years will be even higher.

The advocacy group said last year’s Inflation Reduction Act changes the playing field for the resource transition. It said its suggested portfolio can provide equivalent energy and capacity more cheaply than the cost of a large gas plant. The group added that its economic analysis of the two options included potential excess energy sales and market purchases.

Duke said in its IRP that a new gas plant would avoid “committing to dramatic resource changes prematurely, preserve its decision-making flexibility going into the 2024 IRP analysis, and shield customers from undue cost increases in the near-term.”

“Duke’s assumptions from 2021 are outdated,” AEU said. “Market trends and recent federal action to extend energy tax credits have dramatically shifted the economics of various energy resources. This created a need to revise current and future utility plans so that benefits can flow to Hoosiers.”

Contemplated portfolio mix (Duke Energy) Content.jpgDuke Energy Indiana’s contemplated portfolio mix through 2040 under its 2021 IRP | Duke Energy

 

According to the report, the Duke gas plant would generate 6,014 GWh during 2027 while the renewables portfolio will churn out 7,984 GWh and likely require 961 GWh of imports. Economic analysis pinned the clean energy portfolio at $227 million in 2027 and the gas plant at $274 million, accounting for capital expenditures, fuel costs and fixed and variable operations and maintenance costs. Strategen said it also factored in revenues from selling excess energy, which the clean energy portfolio has more potential for.

The firm said its gas plant estimates don’t include the possible carbon capture and sequestration equipment that Duke may need to install to reach its 50% carbon-reduction goal by 2030 and net-zero carbon emissions by 2050. It also didn’t put a number on the cost of converting the plant to green hydrogen.

“This analysis is conservative and understates the potential economic value of the clean energy portfolio because it is only considering the energy revenue when matching profiles with the [combined cycle plant],” Strategen said. “If allowed to operate purely economically, the battery storage would see added revenue by arbitraging energy to periods of high prices, not just when the renewable generation is short.”

AEU noted that volatile gas prices may make the gas plant a riskier bet. It said Duke studied a scenario in its IRP where gas prices are so high — Duke kept the fuel price forecasts confidential — that building a new plant would be uneconomic.

The advocacy group asked that Duke re-evaluate its plan to invest in the plant and to “consider further investment in clean energy resources through the added benefit of the IRA tax credits.”

Duke Disputes Clean Portfolio Savings

In an emailed statement to RTO Insider, Duke said it’s in the process of updating its IRP to reflect the IRA, new guidance from MISO on generation planning, and the changing costs of technology and commodities. The utility noted that it’s holding a third public session on the IRP update Feb. 27.

Duke said AEU’s report relies on generic cost data which “may not always capture the full costs” and doesn’t match the real market bids that it received in request for proposals issued last year. It said when it updated AEU’s proposal for current conditions in Indiana, it immediately found the clean energy portfolio to be more expensive.

The utility said the portfolio is “not a realistic plan” because it requires Duke to site large-scale renewable projects that need thousands of prepared acres within six years.

“Generation diversity is essential and a strength, and we expect our updated plan will be diverse and include a significant amount of renewables as well as natural gas resources that can be dispatched when needed, regardless of weather conditions,” Duke said. “Including a moderate amount of natural gas in the resource mix positions us to retire coal plants earlier and add more renewables on our system until new, economical carbon-free technology arrives.”

The utility added that it’s simply too risky to substitute a “core” on-demand resource with a generation mix that relies on solar, wind, four-hour storage and power markets.

“We have to plan in a way that ensures reliability and self-reliance and is not overly reliant on the weather and power markets,” the company said. “We are making the largest transition from coal-fired power in the state, and the renewable energy we add will be the largest addition of any of Indiana’s utilities. We have to do this right. We have to transition in a way that ensures reliability and affordability for customers as well as cleaner energy.”

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Moore Names Consumer Advocate to Head Md. PSC

Maryland Gov. Wes Moore (D) has nominated a consumer advocate to head the Public Service Commission and a gas industry advocate to fill one of two other soon-to-be open seats on the commission.

As part of his “Green Bag” nominations sent to the Maryland Senate on Friday, Moore’s PSC nominations included Frederick H. Hoover Jr., assistant people’s counsel in the Office of the People’s Counsel (OPC), and Juan Alvarado, senior director of energy analysis for the American Gas Association.

Hoover will be replacing outgoing PSC Chair Jason Stanek, who was appointed by former Gov. Larry Hogan (R) and whose term expires on June 30, according to a spokesperson for Moore. Alvarado will  take the seat of either Commissioner Patrice Bubar or Commissioner Odogwu Obi Linton, both of whose appointments were rescinded by Moore last month, the spokesperson said.

Bubar and Linton were also appointed by Hogan but have remained unconfirmed by the Senate. They were among the 48 appointments by Hogan that Moore rescinded, with no explanation, in a Jan. 23 letter to Senate President Bill Ferguson (D). Similarly, he provided no explanation for his PSC nominees, which were just two of the 307 names sent to the Senate in the Green Bag.

Moore could make a third nomination to the PSC later in the legislative session, according to Maryland Matters. Bubar and Linton will continue to serve on the commission until their replacements are confirmed by the Senate and sworn into office.

Maryland’s Green Bag is a tradition that dates back to 17th century England, when lawyers carried their papers in green bags, according to an article in a 2004 State Archives newsletter. The current Green Bag is hand-crafted leather, embossed with the state seal, kept in the archives.

While once seen as a symbol of political patronage — green being the color of money paid for such appointments — today the bag, containing a list of gubernatorial appointments, is delivered to the General Assembly on 40th day of its legislative session, as set in state law in 1851.

Moore boasted that the 307 appointments sent to the Senate on Friday represent a truly diverse Green Bag, with women accounting for 57% of nominations and people of color comprising 45%.

Climate activists had hoped Moore’s rescission of Bubar’s and Linton’s nominations — and the end of Stanek’s term in June — would be an opportunity for the new governor to reshape the PSC and further advance his vision for Maryland’s electric system to be powered 100% by clean energy by 2035.

But the choice of both Hoover and Alvarado could signal a more centrist, pragmatic position.

So Who Are They?

Hoover’s record can only be pieced together from a number of media reports and online research. He led the Maryland Energy Office during the administration of former Gov. Paris Glendenning and was the agency’s deputy under former Gov. Martin O’Malley, both Democrats. Following Hogan’s inauguration in 2015, he worked as a senior program director for the National Association of State Energy Officials.

He has been at the OPC at least since 2020. During that time, the office has pushed the PSC to take stronger action against the gas industry. In early February, for example, the office petitioned the PSC to curb ongoing investment in new gas infrastructure by Maryland utilities.

“Maryland’s gas utility operations, massive infrastructure spending and long-term plans conflict with market trends, state climate policy and the interests of customers,” the OPC said in a Feb. 9 press release on the petition. “To address the conflict, the commission should promptly initiate proactive, comprehensive regulation to manage the transition to a new age, broadly acknowledged, in which gas will play a far diminished role.”

Hoover has also served as past board chair of the League of Conservation Voters, according to Kim Coble, the organization’s executive director, as reported in Inside Climate News.

Hoover’s “experience in clean energy and his commitment to addressing climate change will be valuable assets to the PSC,” Coble told Inside Climate.

However, she also raised concerns about Moore’s nomination of Alvarado. Having a gas industry official on the commission “could present a challenge to the PSC’s efforts to advance utility and transportation services while also respecting the significant and unique role the commission plays in advancing the state’s climate goals and specifically the governor’s 100% clean energy goal,” she said.

Alvarado’s LinkedIn resume lists a 12-year stint at the PSC from 2008 to 2020, including seven years as the director of its Telecommunications, Gas & Water Division. Since 2020, he has worked as director and then senior director of energy analysis at the AGA.

In a recent promotional video for the AGA, Alvarado says that the replacement of coal with gas has been responsible for a major reduction in U.S. greenhouse gas emissions. “It’s going to be an integral part of further reducing emissions in the future, to the point where I think it can one of the paths to zero net emissions,” he says.

A spokesperson for Moore defended both PSC nominations, citing the nominees’ decades of administrative experience and knowledge of the energy industry, as reported by Inside Climate. “The administration is confident that these individuals will work tirelessly to ensure safe, reliable and economic public utility and transportation service to the citizens of Maryland,” the spokesperson said.

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NY CJWG Poised to Select a 35% DAC Coverage Threshold

The New York Climate Justice Working Group (CJWG) on Thursday appeared ready to designate 35% of New York’s 2020 census tracts as disadvantaged communities (DACs), after reviewing public comments on the draft criteria.

CJWG members attending the group’s meeting argued that inclusion is better than exclusion, saying that a 35% census tract designation is preferable as it places less logistical burden on the dispersion of funds, since DACs would likely be closer together.

The scope of the percentage designation is critical, since it impacts where and how climate investments will be distributed, and which communities will receive more decarbonization financing.

The CJWG plans to hold a final vote on the criteria determining what percentage of census tracts will be covered as a DAC on Feb. 23. It expects to release final criteria to the public and the state’s Climate Action Council in March.

The CJWG uses 45 indicators to identify DACs, which can be grouped into either environmental burdens or population vulnerabilities. In addition, it defines DACs as “households reporting annual total income at or below 60 percent of state median income.”

The state’s Climate Leadership and Community Protection Act (CLCPA) created the independent CJWG and charged it with developing criteria to identify DACs, as well as requiring the group to meet at least once a year to review its DAC identification criteria and modify them as necessary (S6599).

The CLCPA outlines a goal “for disadvantaged communities to receive forty percent of overall benefits of spending of clean energy and energy efficiency programs,” which aligns with Biden administration’s Justice40 initiative.

Several states, such as California and Oregon, are adopting similar policies that more equitably distribute climate funds, using criteria that include geography, climate risk and historical inequalities to determine DACs.

CJWG member Abigail McHugh-Grifa, executive director of the Climate Solutions Accelerator of the Genesee-Finger Lakes Region, said the CJWG must ensure “no low-income households are left behind, and that limiting the number of census tracts could result in community level projects being lost.”

Alanah Keddell-Tuckey, director of the Office of Environmental Justice at the Department of Environmental Conservation, reminded other members that communities not designated as a DAC, but considered environmental justice areas, will continue receiving decarbonization investments through other funding streams, such as the Environmental Bond Act. (See ‘NEW YORK: Voters Approve $4.2B Environmental Bond,’ Incumbents Successful in Most Contested Governors’ Races.)

Eddie Bautista, executive director of NYC Environmental Justice Alliance, told fellow members that the CLCPA’s intent was to “drive investment on a community level while diminishing historical disparities.” He said the CJWG must consider a designation that “gets us to the highest CLCPA compliance.”

Another CJWG member, Sonal Jessel, director of policy for WE ACT, said she supports a 35% designation because “we must ensure that we are covering as many people as possible.” She asked whether native lands were considered.

Alex Dunn, a consultant with ILLUME Advising who generated the CJWG Tableau maps, confirmed that native lands were part of the tracts considered and advised members to remember that whatever percentage designation they decide upon should balance community vulnerabilities with environmental burdens.

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NY PSC Accepts $2.75M NYSEG Settlement over Gas Leak Fire

The New York Public Service Commission on Thursday voted to accept a $2.75 million settlement agreement with Avangrid’s (NYSE:AGR) New York State Electric and Gas over a gas leak that led to a fire last February (22-G-0425).

The funds will be used for gas ratepayer benefits, at the discretion of the commission.

The Feb. 2, 2022, incident destroyed a two-family home in Brewster, a village in the Lower Hudson Valley. Subsequent investigations concluded that NYSEG improperly installed the PermaLock tapping tee that caused the leak, kept poor records and complicated fire-prevention efforts because employees lacked proper equipment. (See NY PSC Accepts NYSEG Proposal to Address Gas Leak Fire.)

The order adopting the agreement notes that the commission-approved remediation plan — which directed NYSEG to investigate and resolve further tapping tee violations — is ongoing.

However, the order states that the $2.75 million settlement “provides gas ratepayers with a substantial financial benefit in connection with the resolution of the 11 alleged violations identified.”

“The commission holds public utilities responsible for the maintenance and safety of their gas facilities, and expects utilities to be ever ready for, and respond promptly and effectively to, incidents such as the Brewster event,” Public Service Commission Chair Rory Christian said in a statement.

The commission also called for a new proceeding “wherein all gas distribution utilities in New York will confirm and report on the use of PermaLock tapping tees in their service territories and perform an examination of potentially improperly installed PermaLock tapping tees in their gas systems.”

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New Jersey BPU Grants Second Easement for OSW Project

The New Jersey Board of Public Utilities overruled opposition from local governments and the New Jersey Division of Rate Counsel Friday to grant the state’s first offshore wind project an easement to connect its turbines over county-owned land to a substation onshore.

The board voted 4-1 to back the plan, which would run the 275-kV line underground through the Jersey shore community of Ocean City, which is in Cape May County, to the PJM grid at a substation sited on a now closed coal-fired power plant in neighboring Upper Township.

To move ahead, the project — Ocean Wind 1, developed by Denmark-based Ørsted — needed a temporary 18-month easement and a permanent 30-foot-wide easement across county land in Ocean City.

The BPU’s approval was the second successful use by Ørsted of a controversial law (S3926) enacted in July 2021 that allows offshore wind developers to site power cables and equipment on public land regardless of whether local or state governments approve. The BPU in September granted a separate easement sought by Ørsted for Ocean Wind 1 through Ocean City using the same law. (See NJ BPU Approves Easement Plan for 1st OSW Project.)

The law allows the BPU to override local government opposition if the project can show that the element at issue is “reasonably necessary” for the construction and operation of the wind project. (See NJ Lawmakers Back Offshore Wind Bills.)

“We don’t take these kinds of actions lightly,” said BPU President Joseph L. Fiordaliso. “And there has to be a definite public need in order for this board to even consider this type of action.

“But we have to look at the whole picture and see what is in the benefit of the 9.3 million people who live here,” he said. Fiordaliso added that he believed that “the transmission lines that will go through this area will not in any way alter the appearance or alter the economic viability of the area.”

Matters of Dispute

Voting against the easement approval, Commissioner Dianne Solomon said she did not believe that the board had done sufficient review to back the developer’s application. She said the BPU should have referred the case to an administrative law judge for a more thorough investigation.

“Clearly, this is a contentious if not a contested matter,” she said. “The record is lacking for us to determine if the preferred route is ‘reasonably necessary.’

“Given the situation in which we find ourselves under the legislation passed, we should be seeking more information, not less,” she said. “By voting no, I am not expressing opposition to the petition. Rather, I am objecting to the procedure and bringing this petition to a board vote today.”

Solomon, who voted to grant the first easement in September, added that she believed the board “erred in our decision” in approving the first easement.

During two public hearings to gather stakeholder opinion, and a third hearing at which the developer and local officials made their closing arguments, Ørsted argued that the Cape May easement, and a series of consents needed to obtain environmental and other permits, were necessary to keep the project on schedule after the developer spent two years in a failed attempt to persuade county officials to grant the approvals.

Cape May argued that the BPU should slow the process and take time to explore alternative cable routes dismissed by Ørsted. The attorney who presented the arguments for the county, Michael J. Donahue, who also represents 10 of the 16 communities in Cape May County, said Ørsted’s proposed route “could jeopardize sensitive marshes and impact area historical sites, and utilities in the area, such as sewer, gas and water main lines.” (See NJ County Asks BPU to Slow Approvals for First OSW Project.)

Donahue argued that to limit disruption and negative impacts from the transmission lines, the BPU should consider cable routes for two other offshore wind projects approved by the agency — Ocean Wind 2 and Atlantic Shores — at the same time as the route and easements for Ocean Wind 1.

Solomon cited arguments made by the New Jersey Division of Rate Counsel, which opposed the granting of the easements. In a letter to the BPU on July 7, Director Brian O. Lipman argued that all the parties involved should be allowed to conduct deeper discovery than the BPU’s procedure allowed.

Maura Caroselli, deputy rate counsel, said at the October hearing that the BPU should require Ørsted to reveal the costs of the different routes that it considered, and whether the chosen route was the cheapest route. If it is not, the board should require the developer to “show why the least cost plan is not a reasonable alternative,” she said.

Lipman, in the final hearing on Nov. 10, said there were still “factual disputes” that required the BPU to “hold a proper hearing with proper ability to cross-examination, discovery.” Such a process, he said, would create a “robust record from which the board can make its ultimate determination.”