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December 30, 2024

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FERC OKs CAISO Plan to Streamline Interconnection Process

FERC on Dec. 16 approved CAISO’s request to further streamline its generator interconnection process in response to the high volume of requests in its interconnection queue.  

The commission’s order permits the ISO to apply six sets of tariff revisions related to its Generator Interconnection and Deliverability Allocation Procedures (GIDAP) and associated Generator Interconnection Agreements (GIAs) to resources that joined the queue in Cluster 14 — which opened in April 2021 — or earlier. 

The tariff revisions won’t apply to interconnection customers that already have executed GIAs or have requested that GIAs be filed unexecuted.  

In September, FERC approved a larger proposal to streamline the ISO’s interconnection process starting with 2023’s Cluster 15 and beyond. (See FERC Approves CAISO Plan to Streamline Interconnection Process.)  

The newest tariff amendments are intended to manage the “large volume of interconnection requests already studied but for which GIAs have not yet been executed,” the commission noted in its order (ER25-131). The revisions are a result of the ISO’s Interconnection Process Enhancements (IPE) initiative, which involved over a year of stakeholder engagement that led to the approval of refinements to the process.  

The IPE proposal is intended to complement — not replace — CAISO’s FERC Order 2023 compliance filing, which is still pending approval. The order states that, while the tariff revisions in the most recent filing touch on some reforms in the Order 2023 filing, “CAISO does not propose revisions to any section of its tariff pending commission acceptance.”  

The six sets of tariff revisions the commission approved Dec. 16 will:  

Subject new small asynchronous generating facilities in Clusters 14 or earlier to fault recording requirements that CAISO currently applies only to asynchronous generating facilities larger than 20 MW. 

    • Update the granularity of phase angle measuring unit data for asynchronous facilities by increasing the sampling rate of that data. 
    • Unify the payment and authorization schedules among interconnection customers sharing network upgrades to develop a construction timeline necessary to meet the earliest interconnection customer’s commercial operation date. 
    • Increase the material modification assessment (MMA) deposit cost from $10,000 to $30,000 and extend the estimated time to complete an MMA from 45 days to 60 days.  
    • Create a new “implementation deposit” of $35,000 to cover specific customer costs after completion of interconnection studies in order to avoid passing off those costs to other market participants.  
    • Limit the ability of a customer to linger in the queue after it gives up its deliverability rights. 

The commission said CAISO’s proposals “will improve the accuracy of data about the system, help mitigate reliability issues, enhance the certainty and efficiency of the network upgrade process, ensure that the costs of managing interconnection requests between GIA execution and commercial operation are not allocated to all market participants, and reduce administrative overhead.”  

The new rules become effective Dec. 17.  

Robert Mullin contributed to this article. 

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CAISO Launches New Initiative for Storage Resource Design

CAISO on Dec. 11 kicked off a new Storage Design and Modeling Initiative intended to tackle an array of challenges related to the market participation of storage resources, including further addressing bid cost recovery (BCR) issues and developing a default energy bid (DEB) formula specifically for batteries.  

The initiative piggybacks off the ISO’s prior storage BCR working group, which identified that BCR provisions don’t align with storage resources and led to passage of a proposal to modify the calculation used to determine BCR payments. (See Proposal to Refine Bid Cost Recovery for Storage Passes Unanimously.) 

But several stakeholders, along with CAISO’s Market Surveillance Committee and Department of Market Monitoring, emphasized that the proposal was only a first step in addressing the number of problems identified with storage BCR and their default energy bids.  

The new initiative will delve into previously identified problems, including the need for a holistic redesign of the uplift mechanism for storage and changes to the DEB that reflect the specific characteristics of the resources. It will also introduce new ideas designed to further integrate batteries efficiently into the ISO market, including a proposal to develop a state-of-charge (SOC) mechanism and a way for storage batteries to bid into the market based on their SOC.  

The working group’s effort will be separated into three topic groups: The first deals with BCR, the DEB and outage management systems (OMS); the second covers all topics related to state-of-charge management; and the third deals with distribution-level and paired resource topics.   

Bid Cost Recovery, Default Energy Bid Modification

While CAISO’s completed storage BCR and DEB initiative closed a major market design gap related to existing BCR for storage resources, the ISO identified a further need to address storage assets’ lack of exposure to real-time prices if they deviate from their day-ahead schedules. As a result, the new initiative will seek to redesign the storage uplift mechanism, Sergio Dueñas Melendez, storage sector manager at CAISO, said during the meeting to launch the effort.  

In prior working groups, stakeholders also recommended modifications to the storage DEB and the desire to consider standard approval for storage reference level change requests, which are currently manually processed by ISO staff. Automation and standard approval would provide clarity for market participants, Dueñas Melendez said.  

Lastly, the ISO is seeking to enhance the outage management system (OMS) to align with storage resources, which includes reviewing lower and upper SOC real-time biddable parameter use, clarification of how SOC physical outages impact Pmax and Pmin outages, and improvement of OMS functionality to better support outage submissions from storage assets.  

State-of-charge Management

The ISO is considering developing a “system SOC” mechanism that would track total energy available across the entire storage fleet.  

“Thinking about the fleet holistically may allow better optimization of that storage fleet in critical conditions,” said Dinesh Das Gupta, policy developer at CAISO.  

The system SOC mechanism will work in tandem with how the market operates, so it would be an addition to the system, not a replacement.  

CAISO is also considering developing a “biddable SOC market participation pathway” that would allow energy storage resources to offer charge and discharge bids in relation to their SOC.  

“The vast majority of storage resources participate in the market through the non-generator resource model, which approximates values through megawatt price bid pairings,” Das Gupta said. “A new pathway option centered on bidding at a given SOC may address multiple needs that are currently not found with the non-generator model.”  

Developing this new pathway would take additional time from a policy and technical perspective, Das Gupta highlighted.  

The ISO also highlighted the need to modify the SOC definition and calculation, after determining that resources may face physical constraints not reported to the market that prevent dispatch. Refining how SOC is defined and calculated would improve the ISO’s confidence in a storage resource’s ability to follow dispatch signals during tight system conditions, Das Gupta said.  

The working group will also consider the nonlinearity of a storage resource’s SOC. Non-generator resources are modeled linearly, but energy storage resources have non-linear maximum charging and discharging abilities. Better accounting for this nonlinearity, especially under extreme conditions, may improve storage resource performance, Das Gupta said.  

Finally, the ISO highlighted the need to explore SOC management for capacity awards. The current SOC calculation doesn’t fully model the impacts of capacity awards, particularly for the ISO’s flexible ramping product, which could result in storage resources being unavailable for other commitments, potentially jeopardizing reliability.  

“With the flexible ramping product, we’re seeing potentially serious implications given the price of the product and the high percentage of the product being provided by storage resources,” Das Gupta said.    

Distribution-level Resources

Distribution-level storage assets provide wholesale energy storage to the system via the distribution network rather than through a direct interconnection at the bulk transmission level. These assets fall under both the ISO tariff and the distribution level tariff, and aligning the two would “enhance operational confidence for both resources,” Das Gupta said.   

Additionally, due to significant growth in co-located resources, each with unique parameters and challenges, the ISO is also seeking to explore settlement provisions, including BCR, following increased operational experience with co-located resources.  

The last effort in this topic group seeks to address the lack of a DEB for hybrid resources. Developing a bid for such resources would allow bidding up to the soft-offer cap.  

Next Steps

CAISO expects to release a straw proposal for the initiative in March 2025, with a final proposal slated for July.  

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ERCOT’s Vegas Touts New Reliability Standard

Keynoting the Texas Reliability Entity’s December board meeting, ERCOT CEO Pablo Vegas touted the grid operator’s development of a new reliability standard for the market as “one of [our] more significant” accomplishments. 

He said rather than focus on an outage event’s frequency risk — the loss-of-load expectation, generally set at once every 10 years — as do other grid operators, ERCOT’s reliability standard will measure frequency (one in 10), duration (no more than 12 hours in any event) and magnitude. 

“When you couple or put together all three of those pieces and parts, you have a comprehensive reliability standard that better characterizes what the real risk probabilities are of a grid event and what the impact characteristics would be to consumers in the region,” Vegas told the Texas RE Board of Directors on Dec. 11. 

ERCOT staff are finalizing the magnitude element and working on the various parameters and scenario modeling for the new standard, Vegas said. 

“We want to set it at a level where it’s reasonable to rotate outages should you get into that scenario, so that people who experience a grid-related outage would not have an elongated, continuous outage, but rather would have the opportunity to have power restored as those rotating outages move through different customer groups,” he said. 

The Public Utility Commission approved the reliability standard’s framework in August. Criteria deficiencies are to be assessed at least once every three years, beginning in 2026. The PUC will approve the modeling assumptions and include a public review before the assessment begins. ERCOT is required to develop market design options that address the expected deficiencies.  

“The way this is going to be used effectively, we’re going to now have a yardstick that is going to effectively help us measure how we think the ERCOT market will perform in some period of time,” Vegas said. “I’m really excited to have the first really formal reliability standard in the ERCOT market with the completion of this work.” 

Vegas also briefed the Texas RE on the “remarkable load growth trajectory” ERCOT expects over the next five to 10 years — an additional 65 to 150 GW by 2030 — that could grow the oil-rich West Texas load zone to nearly the size of Houston, the nation’s fourth-most populous city. AI data centers, crypto miners and other large loads have accounted for about 63 GW seeking interconnection to the grid, he said. 

In response, ERCOT is considering 765-kV transmission backbones and trying to add smaller infrastructure as quickly as possible. The continued wave of energy storage and solar facilities is useful in meeting demand during tight periods and providing ancillary services. 

Alluding to the energy transition and thanking Vegas for his presentation, board Chair Jeff Corbett said, “All those of us in this world, we’re reading this every day, but when you come and talk about it, you put it in a nice package that allows us to actually take a step back and go, ‘Crap!’ 

“But I will say that I do sleep OK at night because Pablo is at ERCOT.” 

In other business: 

    • The board endorsed the Nominating Committee’s recommendation that Corbett continue to serve as chair and Suzanne Spaulding as vice chair in 2025.  
    • The Texas RE’s membership has dropped from 125 members to 107. Generation resources account for the bulk of the entity’s members, with 74. 
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LPO Announces $1.25B Loan to Help EVgo Install 7,500 Fast Chargers

The latest billion-dollar loan announcements from the U.S. Department of Energy’s Loan Programs Office are aimed at putting 7,500 new public electric vehicle fast chargers online in the next five years and replacing retiring coal plants in Wisconsin with upgraded hydropower, along with solar, wind and storage projects. 

On Dec. 12, LPO announced the closing of a $1.25 billion loan to EVgo, which is developing a national network of public direct current fast chargers. On Dec. 13, the office announced a conditional $2.5 billion loan to the Wisconsin Electric Power Co. (WEPCO), a subsidiary of the Milwaukee-based WEC Energy Group. 

For its loan, EVgo has committed to deploying 350-kW direct current fast chargers that will be compatible with both SAE J3400 and CCS EV connectors. Previously, only Tesla EVs used the J3400, or North American Charging Standard (NACS), connectors, while other automakers used CCS. However, almost all major automakers have said their new EVs will come with J3400 connectors, beginning in 2025.  

During a Dec. 12 investor call about the loan, CEO Badar Khan said the company would receive the first $75 million of the federal money in January, which should cover an initial deployment of 200 to 300 new chargers. The company expects to be able to cut its installation costs over the course of the five-year loan, which could add 1,600 more fast chargers to the 7,500 that LPO is funding.  

Khan also noted that while Tesla tends to locate its fast chargers near major highways, EVgo’s strategy is to place them in urban and suburban areas “closer to amenities,” which could draw EV owners living in apartments without chargers on site. As automakers produce EVs that can charge at faster speeds, “that will make the use case for DC fast charging more compelling to drivers,” he said. 

The company tries to avoid delays in interconnecting new chargers with a siting plan that includes having two or more potential locations for each new charging station, Khan said. For the DOE loan, 57% of the planned installations already have three or more possible locations, and an additional 15% have two possible locations.  

Khan said expanding the availability of fast chargers is “a key ingredient to the long-term competitiveness and sustainability of the U.S. automotive industry. There is an unmistakable trend towards electrifying transportation across the globe that China is currently winning.” 

The U.S. has about 100 EVs for every DC fast charger, while in China, the number is 50, he said.  

WEPCO

If finalized, the WEPCO loan could replace retiring coal plants with up to 1,650 MW of utility-scale renewable energy and storage projects, which could lower rates for the utility’s customers.  

It also would be the first LPO investment made under the office’s Energy Infrastructure Reinvestment program, funded by the Inflation Reduction Act. The program is designed specifically to help regulated, investor-owned utilities “retool, repower, repurpose or replace energy infrastructure that has ceased operations or enable operating energy infrastructure to avoid, reduce, utilize or sequester air pollutants or greenhouse gas emissions,” according to the LPO website. 

EIR loans also can be used to fund “multiple individual project sites, including individual project components that may be technologically diverse, geographically varied and at different stages of the utility planning and execution process,” LPO says. 

In addition, “EIR projects must demonstrate that the financial benefits received from the [LPO] loan guarantee will be passed on to the customers of, or communities served by, that utility.”  

The first project to be funded under the WEPCO loan could be an upgrade of the 16-MW Big Quinnesec Falls hydropower project, located in the northeast corner of Wisconsin. To finalize the loan, WEPCO will be required to meet specific technical, legal, environmental and financial conditions, according to LPO.  

The EVgo and WEPCO announcements continue the office’s accelerated pace for getting IRA dollars out the door in the final weeks of the Biden administration. On Dec. 3, the office finalized a $303.5 loan to EOS Energy to expand production of its zinc-based, long-duration energy storage technology. A conditional commitment for a second $303.5 million loan followed on Dec. 9 for Project IceBrick, a virtual power plant aggregating power from 193 cold thermal energy storage units installed in commercial buildings across California.  

Developed by Nostromo Energy, the IceBrick cold thermal storage system freezes a water-based solution during off-peak hours when energy is abundant and clean and then uses it to cool buildings during periods of peak demand when electricity is more expensive and may be dirtier. 

Speaking at the U.S. Energy Association’s Advanced Energy Technology Showcase on Dec. 12, LPO Director Jigar Shah said conditional and final loans should be safe from any claw-back attempts by the incoming Trump administration. Existing LPO loan contracts were honored during President-elect Donald Trump’s previous four years in the White House, and conditional commitments are signed contracts. (See Jigar Shah: ‘Loan Programs Office Is Government Doing its Job Well.’) 

As of Dec. 12, in the past four years, LPO had finalized 15 loans and loan guarantees totaling $14.51 billion and 18 conditional loans, totaling $40.24 billion pending finalization.  

According to Shah, the office continues to receive about one new loan application per week and is processing 212 applications requesting a total of $324.3 billion. 

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CAISO Monitor: ISO Easily Handled Annual Peak Demand in 2024

CAISO’s Department of Market Monitoring on Dec. 12 reported that the ISO saw “one of the highest demand peaks” in recent years, at 48,353 MW on Sept. 5 — but still well short of the record of 52,061 MW in 2022.

Speaking at the ISO’s Market Performance and Planning Forum, Guillermo Bautista Alderete, the department’s director of market analysis and forecasting, highlighted that the peak was also higher than the California Energy Commission’s forecast of 47,160 MW.

Annual CAISO demand typically peaks in July to mid-September. Besides the 2022 record, this year’s figure marked the highest peak load since Sept. 1, 2017, when demand rose to 50,116 MW. It was also an increase of about 8.6% over last year’s 44,534 MW on Aug. 16.

Monthly resource adequacy showings, which came out to be a little over 53,000 MW, slightly increased from 2023 and were sufficient to cover CAISO’s load plus operating reserves in September. That was “the reason why we didn’t have any tight supply conditions to the extent that we have observed in previous years,” Alderete said.

He also noted that there was a significant decrease in gas-fired generation coupled with a significant increase in storage resources: 3.6 GW compared to 5.5 GW.

“That aligns with the present trend that we have seen of quick penetration of storage resources exceeding the 10,000-[MW] mark sometime in 2024,” Alderete said.

Despite what Alderete described as a relatively moderate September, the ISO did support a “reasonable level” of wheel-through transactions, peaking at just over 500 MW.

September also saw the highest participation in the Assistance Energy Transfer (AET) program since its inception in 2023. Nine balancing authority areas opted into the program, accumulating approximately $720,000 in AET surcharges in August and September.

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Calif. Energy Commission Approves EV Charging Plan

California regulators have approved a $95.2 million funding plan for zero-emission vehicle charging infrastructure, with nearly equal amounts going to charging for passenger vehicles and medium- and heavy-duty trucks. 

The California Energy Commission on Dec. 11 approved the funding for the Clean Transportation Program for fiscal 2024/25. The package includes $40 million for light-duty EV charging infrastructure; $38.2 million for medium- and heavy-duty ZEV infrastructure; $15 million in hydrogen-specific funding; and $2 million for workforce development. 

The slightly higher funding amount for light-duty charging infrastructure comes after the program has given more money to medium- and heavy-duty ZEV infrastructure over the years, Commissioner Patty Monahan noted. 

“But this year, given the fact that we really want to make progress on reaching our state goals for charger deployment, we’re leaning in a little bit more on light duty, but with a very strong focus on equity,” Monahan said. 

California will require all new cars sold in the state to be zero emission by 2035. A CEC report finalized this year projects the state will need 1 million public or shared-private light-duty EV chargers by 2030, growing to 2.1 million chargers by 2035. 

The state now has about 152,000 public or shared-private EV chargers, a number expected to grow to about 359,000 when chargers are built with previously allocated funding. 

Charger Types Debated

CEC staff described the funding plan as a high-level view. Specific projects will be selected later through competitive grant solicitations, block grants and in some cases, direct awards or loans. Among the yet-to-be-determined details is how much funding should go to particular types of light-duty EV chargers.  

Bill Magavern with the Coalition for Clean Air made a case for funding Level 1 chargers, which he said could benefit low- and moderate-income drivers living in apartments. “We continue to think that there’s a role for Level 1 charging in providing a really low-cost alternative for some of those multi-family dwellings,” Magavern said. 

On the other hand, Commission Chair David Hochschild noted the importance of DC fast chargers to those who drive for a living. He said one in five Uber rides in California now is in an electric vehicle, compared to one in 10 rides nationally. “Time is money. If they’re stuck at a slow charger, it really impedes their ability to drive electric,” Hochschild said. “Access to fast charging is essential to that sector.” 

Future Funding

Funding for the CEC’s Clean Transportation Program comes from a surcharge on California vehicle registrations. The program also can receive money from the state’s general fund or the Greenhouse Gas Reduction Fund. 

But due to a budget shortfall, those sources did not provide funding to the Clean Transportation Program for fiscal 2024/25. The CEC expects that funding to resume over the next three fiscal years to the tune of $1.3 billion. 

Adding the anticipated state funding to this year’s base funding, the CEC investment plan envisions allocating $1.39 billion through fiscal 2027/28. That would include $659 million for light-duty EV charging infrastructure, $668 million for medium- and heavy-duty ZEV infrastructure, $15 million in hydrogen-specific funding, $46 million for emerging opportunities and $2 million for workforce development. 

The funding plan notes those amounts could change as future budgets are finalized. 

The Clean Transportation Program was created in 2007 through Assembly Bill 118. AB 126 of 2023 extended the program until July 2035 and required that at least half of the program’s funding go toward projects that benefit low-income and disadvantaged communities starting in 2025. 

Since its launch, the program has invested $2.3 billion into projects supporting ZEV infrastructure. As of July 2024, 63% of funds have gone to projects in communities that are disadvantaged, low-income or both. 

“Approval of the investment plan reaffirms California’s commitment to funding zero-emission refueling infrastructure,” Monahan said in a statement after the vote. “There is no doubt — ZEVs are here to stay in the Golden State.” 

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MISO, SPP to Revise Joint Agreement, Focus on TMEP Process in 2025

MISO and SPP staff told stakeholders Dec. 13 that they will not perform a Coordinated System Plan in 2025 but will accept transmission issues for their annual review early in the year.

“This next annual issues review will be more of a check-the-box type of exercise than the normal, which would inform our decision to embark on a study in that particular year,” Clint Savoy, SPP manager of interregional strategy and engagement, told members during a meeting of the RTOs’ Interregional Planning Stakeholder Advisory Committee (IPSAC).

“What we’re hoping to do with this process that we’re trying right now would result in updates to the process going forward. I think that’s something we’re going to be considering as we’re looking for ways to enhance the current CSP processes,” he added. “First off, how do we improve on the needs that we’re looking to provide solutions for and make sure we’re looking at the right things? We always consider the transmission issues that our stakeholders submit, and oftentimes those lead to more targeted studies.”

The IPSAC is scheduled to hold its annual meeting March 28, with stakeholders facing a Feb. 26 deadline to submit their issues for review. The meeting is required by the grid operators’ Joint Operating Agreement, as is a CSP every other year.

Five previous CSP studies have failed to produce any joint projects over differences in allocating costs. That led the RTOs to try a different approach with the Joint Targeted Interconnection Queue (JTIQ), which identified a five-project portfolio estimated to cost as much as $1.6 billion that could support up to 29 GW of interconnecting generation along their seam.

FERC approved the JTIQ framework and cost allocation in November, and the Department of Energy in 2023 awarded the portfolio $464 million under its Grid Resilience and Innovation Partnerships program. (See DOE Announces $3.46B for Grid Resilience, Improvement Projects.)

The commission’s approval of the JTIQ process has cleared the way for RTO staffs to revise the JOA language and refocus on their Targeted Market Efficiency Project (TMEP) process. They told stakeholders the new study approach will be much broader and forward looking and will be without predefined, specific historic issues to be resolved.

The RTOs plan to begin the study work in 2025. They are collaborating on a filing timeline and promised a stakeholder review will be shared at the IPSAC’s annual meeting.

The TMEP process was used in the 2022 CSP. It studies smaller, congestion-relieving, cross-border transmission projects already in use between MISO and PJM. (See MISO, SPP Take on 2nd Interregional Planning Effort.)

M2M Settlements Pass $600M

During a meeting of the SPP Seams Advisory Group, also on Dec. 13, staff reported that market-to-market (M2M) settlements with MISO have totaled $604.02 million through October in SPP’s favor.

Under the M2M process that began in March 2015, the grid operators exchange settlements for redispatch based on the non-monitoring RTO’s market flow in relation to firm-flow entitlements. Those settlements have steadily accrued to SPP, topping $100,000 in 2020, doubling in 2021 and doubling again in 2022.

However, the pace has slowed recently as the RTOs have added transmission to relieve congestion along the seam. Cumulative M2M payments exceeded $500 million in December 2023, but they only reached $600 million in October.

The notorious Neosho (Missouri)-Riverton (Kansas) flowgate accounted for $73 million in M2M settlements to SPP, according to a staff report to the SAG in December 2023. That number hasn’t budged since then, an indication that SPP did not have any M2M settlements on the flowgate this year.

“This issue is likely resolved by the transmission construction that occurred in the Neosho area over the last two or three years,” SPP spokesperson Meghan Sever said in an email.

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MISO Decides Against Revising Guiding Principles

THE WOODLANDS, Texas — MISO said it will leave the 10-year-old guiding principles for its market design untouched after it conducted a check-in with stakeholders to gauge whether they are still valid in a rapidly changing industry. 

Speaking Dec. 10 at the meeting of the MISO Board of Directors’ Markets Committee, Zak Joundi, executive director of markets innovation and strategy, said the RTO received a “relatively small amount of written feedback” after soliciting recommended changes and updates at stakeholder committee meetings. (See Changing System Drives MISO to Scrutinize Guiding Market Principles.) 

Although a few stakeholders made suggestions about adding nods to resilience or being more prescriptive about resource adequacy, Joundi said the community remains generally supportive of the principles a decade later. 

“We feel like this truly covers the whole gamut,” he said. 

MISO’s five guiding principles include standing up an “economically efficient” wholesale market system, fostering nondiscriminatory market participation, maintaining transparent market pricing, facilitating efficient operational and investment decisions among market participants, and aligning market requirements with reliability requirements. 

In public meetings, some stakeholders have said the principles still seem to make a lot of sense even considering the transformed landscape. 

However, at the Market Subcommittee’s meeting in October, the Clean Grid Alliance’s David Sapper suggested MISO consider adding an insertion encouraging coordination and collaboration among members, regulators and governments to maintain resource adequacy. Sapper also condemned the suggestion that members and states stall carbon-reduction goals for the sake of reliability, made by MISO’s Todd Ramey the previous month. (See “More Supply Alarms,” MISO Board Week Covers Supply Worry, SoCal Utility Exec Addition, $400M Budget.) 

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NERC’s RSTC Welcomes New Members for 2025

In a two-day virtual meeting, members of NERC’s Reliability and Security Technical Committee (RSTC) worked through what Chair Rich Hydzik, of Avista, called “a fairly strong agenda” addressing “issues … as intellectually fulfilling as any group I could imagine at NERC.” 

Hydzik opened the meeting by welcoming the RSTC’s incoming members, chosen in an election that closed Nov. 20. Scott Klauminzer, Gayle Nansel, Mohammad Awad and Drew Bonser will represent Sector 2 (State/municipal utility), Sector 4 (Federal or provincial utility/power marketing administration), Sector 7 (Electricity marketer) and Sector 10 (ISO/RTO), respectively. 

The new members will replace departing members Saul Rojas in Sector 2, Edison Elizeh in Sector 4 and Eric Miller in Sector 10, whose terms will expire Jan. 31, 2025. The seat for Sector 7 is currently vacant, having converted to an at-large seat after not receiving any nominations in the last election. 

Current at-large member Srinivas Kappagantula will take the seat of Mark Spencer in Sector 6 (Merchant electricity generator), whose term also is ending. The remaining seats in sectors 1, 3, 5, 9 and 12 will continue to be held by Todd Lucas, Marc Child, Nicola Parrotta, Darryl Lawrence and Christine Ericson, who were all re-elected. Sector 8 (Large end-use electricity customer), which was also converted to at-large, did not receive any nominations and will remain empty until the RSTC holds a special election. 

Strategic Plan and Other Actions

Members unanimously approved the RSTC’s 2025-2026 Strategic Plan, which “guides the functions and core mission of the RSTC [with] a sustainable set of expectations and deliverables,” according to the plan’s introduction (on page 22 of the agenda). 

A group of six volunteers from the RSTC membership reviewed the plan, according to Vice Chair John Stephens, director of power system control and planning at City Utilities of Springfield. He said the team “didn’t make any major changes” to the plan because the risk items identified by the Reliability Issues Steering Committee in its biennial risk report, on which the strategic plan is based, have not changed since 2023. 

However, Stephens said the team did note that the RSTC formed the Large Loads Task Force and the Electric Vehicle Task Force earlier in 2024 to study the reliability impacts of emerging large loads such as data centers and EV chargers, respectively. He said the plan has been updated to include the work of these groups. 

The committee then approved several white papers presenting recommended changes to regulatory processes to encourage the adoption of innovative technology in the electric industry and areas of improvement for identifying and addressing the reliability impacts of distributed energy resources. It also approved a technical reference document outlining how to perform energy reliability assessments. 

However, another technical reference document suggested by NERC’s System Planning Impacts from Distributed Energy Resources Working Group (SPIDERWG) ran into headwinds during the meeting, ultimately failing to gain the votes needed for approval. 

The SPIDERWG created the report to “document the type and tenor of industry comments” received on a standard authorization request it created to clarify the role of DERs in operational planning assessments and real-time assessments. SPIDERWG Chair Shayan Rizvi said that after the industry’s comments, the group felt that a new standard was not necessary to address the reliability concerns but that a technical reference document outlining the issues involved could be helpful. 

However, several attendees expressed concern over the document’s perceived lack of direction. Ahmed Maria, of Ontario’s Independent Electric System Operator, said that while “well written,” the paper “seemed to present a problem and not the solution.” Ryan Quint of Elevate Energy Consulting agreed, proposing that the document be sent back to the SPIDERWG for more development. 

“I think that it could really be useful to spend a bit more time laying out a path forward and making sure that it’s well documented, so that if it ever was picked back up, there is a purpose to it,” Quint said. “I just caution throwing this up there as a bunch of problems without solutions.” 

After more discussion, Hydzik asked Wayne Guttormson of SaskPower — who had moved to approve the document — if he was willing to withdraw his motion, to which Guttormson assented. Rizvi asked that Hydzik approve a 30-day comment period for the document so that members of the RSTC could share their thoughts in more detail, to which Hydzik agreed. 

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Jigar Shah: ‘Loan Programs Office is Government Doing its Job Well’

WASHINGTON ― President-elect Donald Trump’s November victory has not slowed the number of new loan applications coming into the Department of Energy’s Loan Programs Office, according to LPO Director Jigar Shah. 

The LPO has 212 active applications seeking $324.3 billion in federal dollars, Shah said during his Dec. 12 appearance at the U.S. Energy Association’s Advanced Energy Technology Showcase at the Ronald Reagan Building. The office continues to receive “an average of one application a week,” he said. “The latest monthly application activity report went up by $20 billion this last month. And so, it’s also been a surprise to me, but there’s been a lot of new applications that continue to come in.” 

What’s driving the ongoing activity is artificial intelligence and load growth and the need to maintain U.S. leadership in energy innovation and rebuilding domestic supply chains, he said. 

“We need to allow all these manufacturing facilities and onshoring and reshoring facilities to interconnect to the grid. [This] remains a priority, right?” Shah said. “AI, load growth remains a priority. We want to win AI, right? The technologies that we’re covering, everything from nuclear power to enhanced geothermal to next-generation grid technology to virtual power plants are all essential to meeting this moment. All of it, right?” 

Shah’s four years at LPO have been dedicated to making the office a “bridge to bankability” for clean tech entrepreneurs, which in many cases has meant mentoring early stage companies to the point where they can apply for a loan, he said. 

Trump’s pronouncements on energy policy since the election have focused on U.S. energy dominance and independence, goals Shah argues will make energy innovation and entrepreneurship critical. 

According to its most recent report, the office still has close to $400 billion in unspent loan authority, and Shah said the LPO provides essential financing to “the most exciting entrepreneurs and innovators that America has to offer. I think they’re irresistible. I think folks are going to want us to continue to do big things.” 

Pointing to technologies that have bipartisan support, he said, “if you’re going to scale up nuclear power, if you’re going to scale up clean hydrogen, if you’re going to scale up these technologies, there’s no other place to get affordable debt to do these first-time projects outside the Loan Programs Office.”  

Shah said Trump has yet to name a transition team for DOE, so he has not been able to talk with anyone from the incoming staff of Chris Wright, the CEO of Liberty Energy, a natural gas company, whom Trump has nominated to head the department. But Shah said his first step will be to introduce the transition team to the team of investment professionals and energy experts he has assembled at LPO. 

“We’ve built a world-class team, and this world-class team wants to put this money out the door to help American entrepreneurs and innovators to meet the moment,” he said. 

DOE and the LPO still face a range of unknowns, such as whether they might fall victim to the staff-cutting agenda of Elon Musk and Vivek Ramaswamy’s Department of Government Efficiency. 

Shah again remains confident. “When you look at the Loan Programs Office today, for the amount of debt that we’re putting out the door, the private sector would have three times the number of employees that we would have,” he said. “So, I think we’re probably a hallmark of government efficiency in terms of the way in which we’ve processed the loans, the way in which we’ve substantially reduced the time that it takes to get a loan.” 

Another strong selling point is “how much private-sector capital we’ve crowded in,” Shah said. “When you get a conditional payment from the loan programs office, every single one of our applicants has been able to successfully raise equity, which is not easy these days, right? … I think that the Loan Programs Office is government doing its job well.” 

Shah also said companies that have either received a conditional loan or finalized a contract should be safe from any clawback efforts. Conditional commitments are binding contracts, he said. 

“I think all of these projects are important to the communities that they’re in; they’re important to the states that they’re in; they’re important to the congressional districts they’re in,” Shah said.  

“I don’t know how many entrepreneurs and innovators you’ve met, but they are ferocious,” he said. “They will walk through walls to accomplish their goals. If they cannot build them here, they will go to another country to build them. I don’t know why anyone would want these entrepreneurs and innovators to leave our country and go to another country to commercialize American technology, because we make a mistake. All the R&D, all the invention was done here. Why would people not want them to scale them here?”