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April 2, 2025

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Wash. Relaunches Cap-and-trade Rulemaking to Link with Calif., Quebec

Washington state has relaunched rulemaking that will pave the way for linking the state’s cap-and-trade program with the already-linked programs of California and Quebec. 

The new rulemaking will replace previous linkage rulemaking for Washington’s cap-and-invest program, which is the state’s name for cap-and-trade. The latest rulemaking will cover a wider range of topics, the Washington Department of Ecology announced March 31. 

The earlier rulemaking started in April 2024. The Department of Ecology held public meetings and released draft rules July 1. Comments and information gathered during the previous linkage rulemaking will be used as part of the new rulemaking, the department said. 

The potential rule changes will help Washington’s cap-and-invest program align with cap-and-trade programs in California and Quebec, although a new rule won’t create a linkage among the programs on its own. 

In cap-and-trade programs, major greenhouse gas emitters must buy allowances that correspond to the amount of their emissions; the state also imposes an emissions cap that decreases over time. The state may use proceeds from allowance auctions to fund climate projects. 

Linking carbon markets of multiple jurisdictions allows for joint allowance auctions, a common allowance price and trading of allowances between jurisdictions. With a larger pool of buyers and sellers, the linked markets generally have more consistent pricing and fewer price swings, the Department of Ecology said. 

California and Quebec linked their cap-and-trade programs in 2014. Washington launched its cap-and-invest program in January 2023, and last year, the state legislature passed Senate Bill 6058, intended to facilitate the linkage with the California-Quebec market. 

“We believe linkage will strengthen our respective efforts to fight climate change and reduce air pollution, while also encouraging more governments to adopt scalable, market-based climate policies in the future,” the three jurisdictions said in a joint statement issued in September.  

Topics Covered

The new Washington state rulemaking involves changes to two rules: the Climate Commitment Act Program Rule and Reporting of Emissions of Greenhouse Gases Rule. 

The previous rulemaking considered a range of topics, including compliance period length, program registration requirements and allowance purchase limits. 

Electricity sector topics included reporting for electric power entities, coverage for imported electricity from unspecified sources, participation requirements for federal power marketing administrations and greenhouse gas emissions reporting methods. 

Additional topics will be considered in the new rulemaking, including: 

    • imported electricity associated with centralized electricity markets; 
    • the amount of allowances allocated at no cost to electric utilities that must be consigned to auction during the second compliance period; and 
    • adoption of allowance budgets for the second compliance period (2027-2030) to ensure that emissions reductions are aligned with the state’s greenhouse gas emissions limits for 2030, 2040 and 2050. 

The rulemaking topics may continue to evolve, the Department of Ecology noted, as California and Quebec work on potential changes to their cap-and-trade regulations. And legislation enacted in Washington state this year could prompt further rule changes. 

The department will hold public meetings for the new rulemaking this spring through fall. The department expects to release a proposed rule early next year and adopt rule changes in summer 2026. An environmental justice assessment will also be conducted as part of the rulemaking. 

The department previously projected that a linkage agreement could be in place in 2026, with linked markets beginning to operate in 2026 or 2027. 

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Reliability Projects Dominate CAISO’s $4.8B Draft Transmission Plan

CAISO’s 2024/25 draft transmission plan recommends 31 new projects at an estimated cost of $4.8 billion, slanting heavily toward reliability needs.

The plan is based on California Public Utilities Commission forecasts projecting the state must add more than 76 GW of new capacity by 2039, the ISO said in the draft.

“This reflects greenhouse gas reduction goals and load growth, including the potential for increased electrification occurring in other sectors of the economy, most notably in transportation and the building industry,” CAISO wrote.

The new capacity needs include 30 GW of solar generation spread throughout the state, 7 GW of in-state wind resources in existing wind development regions, and more than 4.5 GW of offshore wind in the Morro Bay and Humboldt call areas.

The plan also factors in the need to import an additional 9 GW of wind energy from Idaho, Wyoming and New Mexico, which will require “enhancing corridors from the ISO border in southeastern Nevada and from western Arizona into California load centers.”

The plan additionally considers the transmission access needs of co-located battery storage projects across California, as well as for standalone projects close to major load centers in the Los Angeles Basin, the Greater Bay Area and San Diego.

“Our draft plan reflects the ISO’s proactive approach to transmission planning and underscores our ongoing collaboration with local, state and regional partners to ensure California has the necessary infrastructure to deliver clean energy reliably and cost-effectively to consumers,” Neil Millar, CAISO vice president for transmission planning and infrastructure development, said in a statement.

The ISO noted some of the projects would use grid-enhancing technologies.

Mostly Reliability

Twenty-eight reliability-driven projects account for nearly all the proposed spending, at roughly $4.56 billion.

“While the resource planning needs have not increased materially from those reflected in last year’s transmission plan, the increased rate of load growth reflected in the most recent load forecast associated with building and other electrification, data center growth and transportation electrification results in significant reliability-driven needs in this year’s transmission plan,” the plan says.

The 2024/25 plan assumes the state’s peak demand will increase at a 1.53% yearly rate, compared with a 0.99% forecasted growth rate in the previous plan. Peak demand in the Greater Bay Area is now expected to grow by 2.14% annually (up from 1.22%), translating into a 2,000-MW increase in the region’s 2035 peak load forecast, “with most of the growth coming from electrification of the transportation and building sectors of the state’s economy and an anticipated increase in data centers associated with artificial intelligence.” (See Data Centers Contribute to 60% Increase in San Jose Load Forecast.)

The Bay Area would host the priciest reliability projects in the plan, including Pacific Gas and Electric’s North Oakland ($1.13 billion) and Greater Bay 500-kV transmission ($700 million) reinforcement projects. San Diego Gas & Electric’s Downtown Reliability reinforcement project comes in third at $500 million.

Three policy-driven projects would entail about $289.5 million in spending.

All three recommended policy projects are in PG&E’s territory, including two in Fresno and one in the North Coast/North Bay local area. “They are needed to meet the renewable generation requirements established in the CPUC-developed renewable generation portfolios,” the ISO said.

CAISO said the plan identified no economically driven projects, representing those that would reduce costs for ratepayers but are not needed for reliability.

The ISO said the 31 recommended projects “represent significant investments that are phased in over lead times of up to eight to 10 years, which are reasonable for some of the projects to be completed.”

Costs would translate into about 0.5 cents/kWh over the life of the projects and will be phased in as lines come into service, the ISO said.

CAISO will hold an April 15 public stakeholder call on the draft plan and is taking comments through April 29. The ISO’s Board of Governors is expected to vote on the plan at its May meeting.

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Maine Floating OSW Negotiations Halted

Negotiations on what could have become the first floating offshore wind array in the U.S. have halted amid the uncertainty that has gripped the country’s offshore wind industry. 

The Maine Public Utilities Commission on March 28 granted the request of Pine Tree Offshore Wind to suspend talks on a contract to support construction of a research project with up to 12 turbines with a capacity of up to 144 MW. 

The move is the latest setback for the state of Maine’s long-running ambitions to exploit the windy waters off its coast for environmental and economic benefit through installation of wind turbines and creation of a new commercial/industrial sector:

    • The depth of the Gulf of Maine dictates that floating turbines be used there, and floating wind technology is still in development.
    • The state lost out on a $456 million federal grant to develop an offshore wind port; also, the chosen site is a nature preserve, and development is strongly opposed by some advocates. (See Maine Chooses Nature Preserve for Floating Wind Port.)
    • The first-ever Gulf of Maine commercial lease auction was a lackluster affair, with four of the eight offered lease areas drawing just $22 million in combined winning bids and the other four going unsold. (See Gulf of Maine OSW Auction Results in Four Leases Worth $21.9M.)
    • And of course, Donald Trump was elected president on a platform that included halting offshore wind development. Pine Tree is only the latest of several developers to pause their efforts in U.S. waters amid Trump’s efforts to follow through on his campaign pledge.

The state of Maine requested the research lease in October 2021 and designated Pine Tree as its operator. The U.S. Bureau of Ocean Energy Management executed the research lease (OCS-A 0553) in August 2024. (See Maine Approved for Floating Wind Research Lease.) 

The zone totals nearly 15,000 acres roughly 28 nautical miles southeast of Portland. 

The Maine PUC opened the docket (Case 2022-00100) for consideration of Pine Tree’s contract in April 2022. In December 2024, Pine Tree requested and received an extension to March 31, 2025, of the deadline to submit a proposed contract supporting the offshore wind research array. 

The negotiations apparently were fruitless: Pine Tree subsequently requested that they be suspended “due to recent shifts in the energy landscape that have in particular caused uncertainty in the offshore wind industry.” 

On March 28, the PUC approved the request for suspension, finding that “good cause exists” and noting that no objections were raised by the other negotiating parties: the governor’s Energy Office, the Office of the Public Advocate, Central Maine Power and Versant Power. 

The suspension will continue until Pine Tree requests that negotiations resume. 

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Newsom Issues Order to Speed Undergrounding of Lines in Los Angeles

California Gov. Gavin Newsom has suspended environmental laws to accelerate the undergrounding and hardening of utility equipment in communities ravaged by the Los Angeles wildfires.  

Newsom’s executive order removes requirements under the California Environmental Quality Act and the California Coastal Act in an effort to speed up “the rebuilding of utility and telecommunication infrastructure, including the undergrounding of equipment,” according to a March 27 news release. 

A previous executive order similarly suspended the environmental laws and applied to infrastructure damaged in the wildfires. However, that order was limited, and projects to move equipment underground or upgrade existing infrastructure may not qualify under the previous suspension, the most recent order stated. 

“We are determined to rebuild Altadena, Malibu and Pacific Palisades stronger and more resilient than before,” Newsom said in a statement. “Speeding up the pace that we rebuild our utility systems will help get survivors back home faster and prevent future fires.” 

In a Feb. 27 letter, Newsom urged Southern California Edison and Los Angeles Department of Water and Power to develop plans by the end of March on how the utilities can rebuild safer and resilient electric infrastructure, including by placing electric distribution infrastructure underground. 

Jeff Monford, a spokesperson for SCE, told RTO Insider the utility appreciates “Gov. Newsom’s action to help expedite permitting so the fire-damaged communities can rebuild stronger. We look forward to continuing our work with federal, state and local officials to shorten permitting times under this executive order.” 

SCE has already launched efforts to underground several miles of lines in Altadena and Pacific Palisades, “and some sections of the grid will be completed in a few months,” Monford said. 

Monford could not share specific cost information but noted that undergrounding costs significantly more than building the grid with power poles. 

“There’s a lot going on in these burn areas, and the expedited permitting, siting and permitting that the governor’s order will allow will certainly help move that along,” he added. 

Local utility Pasadena Water and Power, which operates in the Altadena region that was devastated following the Eaton fire, said in an email that “nothing in the orders change any policy direction and capital projects that we have planned.” 

The Eaton Fire began shortly after 6 p.m. Jan. 7 and burned more than 14,000 acres and killed 17 people. The deadly fire engulfed parts of the Altadena community, with thousands of structures either damaged or destroyed, according to Cal Fire. 

The Pacific Palisades fire burned 23,448 acres, destroyed 6,837 structures and killed 12 people. 

SCE faces several lawsuits, alleging the utility’s lines started the Eaton fire. SCE has said it is investigating possible links between its equipment and the fire. (See SCE Probes Link Between Equipment and Eaton Fire.) 

SCE utility has previously acknowledged that its equipment may have sparked the Hurst Fire, which burned roughly 799 acres and damaged two homes. There were no reports of fatalities or injuries associated with the fire. SCE has said it is cooperating with a Los Angeles Fire Department investigation. 

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TVA Board Promotes Nuclear Veteran from COO to CEO

The Tennessee Valley Authority board of directors March 31 announced it will elevate COO Don Moul to become the fourth CEO of the federal utility.

The promotion further positions TVA for a nuclear-dominant future. Moul previously served as a chief nuclear officer and senior nuclear reactor operator, among other primarily nuclear roles at American Electric Power, Duquesne Light Company, FirstEnergy, GPU Nuclear Corporation and Public Service Electric & Gas.

Moul, who has 38 years of experience in the power industry, replaces outgoing CEO Jeff Lyash, who also has an extensive background in nuclear operations. (See TVA CEO Jeff Lyash Announces Plans to Retire.) The appointment becomes effective April 9 and makes Moul the second TVA COO to earn a CEO promotion. TVA’s first CEO, Tom Kilgore, was also COO before Congress established the CEO position in 2005.

Before joining TVA in mid-2021, Moul was executive vice president and chief nuclear officer at NextEra Energy, where he oversaw operations at seven units as well as decommissioning of the Duane Arnold Energy Center.

Announcement After Senator Criticism, Board Member Dismissal

Moul’s advancement follows Sens. Marsha Blackburn and Bill Hagerty, both Republicans of Tennessee, authoring a March 20 op-ed in POWER Magazine calling for the next TVA leader to lead the “nation’s nuclear energy revival” and fall in step with President Donald Trump’s vision for more nuclear power.

The senators criticized the utility’s leadership and board for moving too slowly on nuclear development and said they were concerned that “TVA’s next CEO would be hired from within.”

TVA holds the country’s only early site permit for small modular reactor (SMR) construction at its Clinch River Nuclear Site in Oak Ridge, Tenn. U.S. Energy Secretary Chris Wright and Hagerty toured the site in mid-March. While TVA’s board authorized $350 million in 2024 to explore nuclear solutions, it has not yet voted to approve an SMR at the site. Lyash has said that TVA eventually aims to build a fleet of SMRs in its footprint.

“The presidentially appointed, Senate-confirmed, TVA board of directors lacks the talent, experience and gravitas to meet a challenge that clearly requires visionary industrial leaders. The group looks more like a collection of political operatives than visionary industrial leaders,” Blackburn and Hagerty wrote.

A week later, TVA board member L. Michelle Moore, an appointee of former President Joe Biden, was fired at the direction of Trump, according to a Securities and Exchange Commission report. The Trump administration has not provided a reason for Moore’s termination. In a statement, TVA said its board members serve at the pleasure of the president.

Moore’s term would have expired on May 18, 2026. The Southern Alliance for Clean Energy called the firing a “hyper-partisan action.”

The board currently has five members and four vacancies.

TVA Underscores Nuclear in Announcement

In a press release on Moul’s hiring, TVA focused on its nuclear advancements. It said under Moul’s leadership, “TVA is a national leader in driving advanced nuclear technologies forward.”

“Don is ready to be the hand guiding TVA in a time of rapid change and growth, and he will continue to propel TVA’s nuclear leadership,” Lyash said. “In his role as COO, he has led the development of next-generation nuclear technologies and has a deep knowledge and appreciation for nuclear power — the most reliable power the world’s ever known.” Lyash also said TVA hired Moul four years ago “with succession planning in mind.”

Moul said he expected his transition to be “seamless” for TVA.

“We’re in a period of growth like we’ve not seen before, and to meet that growth, we are making one of the largest capital investments in our history,” Moul said. “TVA needs a steady hand right now. I will build on the momentum that Jeff and our team have created — making sure we continue to invest in new generation, strengthen our grid and enhance system reliability.”

Moul told the Knoxville News Sentinel the board conducted an internal and external search for a new CEO before they offered him the job after a series of interviews. TVA confirmed that the offer was extended on March 25 and predated Moore’s termination.

Board Chair Joe Ritch said the board search was exhaustive.

“The TVA board took a structured, deliberative approach to CEO succession — evaluating a strong slate of both internal and external candidates,” Ritch said in a statement to RTO Insider. “The board evaluated multiple search firms, reviewing in detail their process for candidate identification and assessment, ultimately selecting a firm with deep experience and expertise in the energy industry. The board also leveraged a third-party leadership assessment firm and an independent compensation consultant.”

Lyash is set to retire as the highest-paid federal employee, making $10.5 million in total compensation over 2024.

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FERC Announces Impending Order on ISO-NE Order 2023 Compliance

FERC plans to rule on ISO-NE’s compliance proposal for Order 2023 on or before April 4, the commission announced in a short notice March 31 (ER24-2009, ER24-2007). 

The announcement came on the date of a key deadline for ISO-NE’s compliance timeline after repeated requests for rapid action by state officials and generation developers. 

ISO-NE initially requested that FERC accept its compliance proposal with an effective date of Aug. 12, 2024. The RTO suspended its work implementing its proposal in October 2024 because of the lack of a ruling from FERC. (See With FERC Inaction, ISO-NE Delays Order 2023 Implementation.) 

In recent months, stakeholders have voiced worries that the delay may hinder resource development in the region and increase prices in upcoming capacity auctions. (See New England Clean Energy Developers Struggle with Order 2023 Uncertainty.) 

Some stakeholders have expressed particular concern about the fate of ISO-NE’s proposed transitional capacity network resource (CNR) group study, which is intended to enable late-stage projects with complete system impact studies to achieve capacity interconnection rights.  

In its original filing, ISO-NE wrote that the transitional CNR study, set to occur prior to the transitional cluster study (which would include all other interconnection requests), “avoids the need to include these requests in the transitional cluster study, thereby creating efficiencies by reducing the number of requests included in that study.” 

ISO-NE had said it would need an order by the end of March to align the transitional CNR study with the 2025 Interim Reconfiguration Auction Qualification process, which includes a show-of-interest submission deadline at the end of April. But in late March, ISO-NE told stakeholders it likely would not be able to proceed with the transitional CNR study. (See ISO-NE to Reopen Queue as it Continues to Wait on Ruling from FERC.) 

In response to FERC’s announcement, an ISO-NE spokesperson said the RTO will assess its options once the order is issued.  

ISO-NE also confirmed that it reopened the interconnection queue April 1. The queue has been closed since June 13, 2024, which is the RTO’s proposed deadline for projects to have a valid interconnection request to participate in the transitional cluster. 

It is unclear if projects that enter the queue after this date will be eligible for the cluster, and ISO-NE has said it “cannot guarantee the treatment of [interconnection requests] submitted after the June 13, 2024, eligibility date.” 

Alex Lawton of Advanced Energy United said FERC’s announcement “has given us renewed hope that the ISO can reverse course and proceed with the transitional CNR group study as previously planned. Should the FERC order largely accept the compliance filing, we are confident the ISO will explore how to proceed in a manner that causes the fewest delays and resembles our stakeholder-supported original plan as much as possible.” 

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Company Briefs

States End Wells Fargo Probe After Bank Drops Net Zero Goals

A group of 18 states ended their investigation into Wells Fargo & Co.’s climate efforts after the lender ditched goals to curb greenhouse gas emissions. 

Eighteen Republican-led states had been investigating whether Wall Street banks’ net zero policies violated antitrust and consumer protection laws and restricted financing. Wells Fargo said last month it was discontinuing its 2030 and 2050 targets related to net zero emissions. 

Tennessee Attorney General Jonathan Skrmetti said the multistate investigation into other banks was continuing. 

More: Bloomberg 

Schneider to Invest $700M in US Operations to Support Energy, AI Sectors

Schneider Electric last week said it is planning to invest over $700 million in its U.S. operations through 2027 to support the nation’s energy infrastructure to power AI growth, boost domestic manufacturing and strengthen energy security. 

The company’s latest investment, along with previous investments in 2023 and 2024 to strengthen its North American supply chain, will surpass $1 billion. 

More: T&D World 

Hyundai Celebrates Opening of $7.6B EV Plant in Georgia

Hyundai last week celebrated the opening of its new $7.6 billion electric vehicle factory in Georgia by announcing plans to expand its production capacity by two-thirds to a total of 500,000 vehicles per year. 

The plant, which spans 3,000 acres and churns out a finished vehicle about once a minute, is currently producing two electric SUV models — the Ioniq 5 and the larger Ioniq 9 set for release this spring. 

More: The Associated Press 

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State Briefs

CALIFORNIA 

Newsom Suspends Environmental Laws to Speed Rebuilding After Fires

In an effort to expedite rebuilding after Los Angeles’ devastating firestorms, Gov. Gavin Newsom last week suspended state environmental laws for utility providers working to reinstall key infrastructure. 

The executive order eliminates requirements to comply with the California Environmental Quality Act and the California Coastal Act for utilities working to rebuild “electric, gas, water, sewer and telecommunication infrastructure” in the Palisades and Eaton fire burn zones. The move builds on Newsom’s prior executive orders that exempted work rebuilding homes and businesses destroyed or damaged by the fires as well as wildfire prevention efforts from the two environmental laws. 

Newsom also encouraged the undergrounding of equipment when feasible. 

More: Los Angeles Times 

DELAWARE 

Senate Passes Resolution to Explore Nuclear Energy

The state Senate last week passed a resolution to explore the feasibility of nuclear energy, creating a task force to assess its potential benefits and challenges. 

The resolution establishes the Delaware Nuclear Energy Feasibility Task Force, which will evaluate the viability of small modular reactors as part of the state’s energy portfolio. 

It now heads to the House. 

More: WRDE 

IOWA 

House Votes to Ban Eminent Domain for CO2 Pipelines

The state House last week voted 82-12 to approve a bill that would stop liquefied carbon dioxide pipelines from using eminent domain. 

The bill would take effect in May and apply to any eminent domain filings made on or after that date. 

Six other bills related to carbon sequestration pipelines, eminent domain and the Utilities Commission were combined into one bill, which also advanced.  

More: Iowa Capital Dispatch 

MINNESOTA 

Xcel to Issue $48M Refund for 2011 Coal Plant Disaster

Xcel Energy will refund customers $48 million for costs related to a 2011 catastrophic equipment failure at the company’s Sherco coal plant in Becker. 

The Public Utilities Commission ordered the refund in October, agreeing with an administrative law judge who found that Xcel was partly responsible for the disaster that sidelined a massive generator at Sherco for almost two years. The refund is for the cost of replacement power, which Xcel billed to customers, in place of the electricity Sherco’s Unit 3 would have generated. 

The refund will be distributed in April and give back about $12 for the average household. 

More: The Minnesota Star Tribune 

MISSOURI 

Evergy Announces Plan for Natural Gas Plant

Evergy last week announced plans to construct a 440-MW natural gas power plant in Nodaway County. 

According to filings with the Public Service Commission, Evergy plans for the simple-cycle natural gas plant to begin construction in the fourth quarter of 2026 or first quarter of 2027 and be operational by Jan. 1, 2030. 

The plant is the third of three natural gas plants announced by the utility since last year, joining two others in Kansas. 

More: Maryville Forum 

NEW YORK

NYC Comptroller: Pension Funds to Double Down on Climate Commitments

New York City Comptroller Brad Lander, who oversees five major retirement funds collectively managing around $284.2 billion, last week pledged to increase climate disclosures and step up investments in climate solutions. 

The New York City pension funds have long taken a stance on climate change, divesting from fossil fuel reserve owners in 2018 and becoming the first major city pension fund to introduce fossil fuel divestment policies. In 2023, they voted to exclude upstream fossil fuel investments across their private markets holdings. 

NYCERS, TRS and BERS, the three funds backing the divestments, say they have exceeded their interim targets and have brought down their Scopes 1 and 2 financed emissions by more than 30%. 

More: Net Zero Investor 

NYPA Takes Ownership of Somers Solar Project

Gov. Kathy Hochul last week announced that the New York Power Authority (NYPA) has acquired full ownership of the Somers Solar project in Washington County. 

The 20-MW project is the first to be acquired, owned and operated by the NYPA under its expanded authority, which was signed into law by Hochul in 2023. 

More: New York State 

RHODE ISLAND

PUC Approves Summer Rates, Has Legislation Filed in Response

Rep. Megan Cotter, in partnership with the Acadia Center and the Conservation Law Foundation, introduced legislation last week to create an intervenor support program that would fund customers’ participation in hearings about ratemaking and other issues before the Public Utilities Commission. 

The legislation is a result of the PUC approving higher summer rates for Rhode Island Energy, which will total about $142 for the average residential customer. Part of the reason the new rates were approved, despite public comments and protests, is that community members lack the necessary resources to get a seat in the rooms where decisions about energy are being made. The bill would enable individuals or organizations seeking legal representation to take part in evidentiary hearings at the PUC and the Energy Facility Siting Board. 

By including the Energy Facility Siting Board, the program would also provide resources to those hoping to intervene in cases related to solar and other energy infrastructure development. 

More: Inside Climate News 

VIRGINIA 

Danville Approves New Battery Storage Facility

The Danville City Council last week approved plans for a battery storage facility. 

Danville has an existing battery storage unit, but the growing population has increased demand beyond the capacity of a single unit. 

Construction is expected to begin later this year, with completion anticipated by May 2026. 

More: WSET 

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Federal Briefs

SCOTUS Declines to Hear Young Climate Activist Case

The Supreme Court last week declined to hear a petition filed by young climate activists who argued the federal government’s role in climate change violated their constitutional rights, ending a decadelong legal battle that saw many of the plaintiffs grow from children and teenagers into adults. 

The case was filed in 2015 by 21 plaintiffs, the youngest of whom was 8 years old. They claimed the U.S. government’s actions encouraging a fossil fuel economy violated their right to a life-sustaining climate. At one point in 2018, a trial was halted by Chief Justice John Roberts just days before it was to begin. 

Last year, acting on a request from the Biden administration, a three-judge 9th Circuit panel issued an order requiring the case be dismissed. The plaintiffs then sought, unsuccessfully, to revive the lawsuit through their petition to the Supreme Court. 

More: The Associated Press 

MARAD Approves Delfin Midstream Offshore LNG Port

The Department of Transportation’s Maritime Administration (MARAD) last week issued a license to Delfin LNG for the construction and operation of the nation’s first offshore liquefied natural gas export deepwater port. 

The license grants Delfin LNG the authority to own, construct, operate and eventually decommission the facility, which will be located between 37.4 and 40.8 nautical miles off Louisiana’s Cameron Parish coast. 

The port will use existing pipelines to support up to three floating LNG vessels, with a total production capacity of 13.2 million tons of LNG per year. 

More: Offshore Magazine 

Genatowski to Lead DOE LPO

Lane Genatowski, who served as the director of the Advanced Research Programs Agency for Energy under the first Trump administration, will lead the Loan Programs Office, effective immediately. 

Genatowski first arrived at DOE in 2018, starting out as senior adviser to the undersecretary for science. Before that he worked as managing director of power and utilities at JP Morgan and Bank of America. 

Genatowski replaces John Sneed, who departed last week. 

More: Latitude Media 

Trump Fires TVA Board Member Moore

President Donald Trump last week fired Michelle Moore from the Tennessee Valley Authority Board of Directors, according to a filing to the Securities and Exchange Commission. 

Moore, an energy nonprofit executive initially nominated by President Joe Biden in 2021, was set to stay on the board until May 18, 2026. 

The termination came exactly one week after state Sens. Marsha Blackburn and Bill Hagerty wrote an op-ed targeting the TVA board and calling for the Trump administration to replace them. 

More: Knoxville News Sentinel 

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NERC Responds to Interregional Transfer Capability Study Comments

NERC’s Interregional Transfer Capability Study represents “a crucial input in development of a modern, reliable, grid” despite its limited congressional mandate and time frame, the agency said in responding to comments on the report March 25.  

NERC filed the ITCS with FERC in November 2024 as directed by the Fiscal Responsibility Act of 2023. In accordance with Congress’ order, the study outlined current transfer capabilities across the U.S. grid, recommendations for prudent additions that could strengthen grid reliability, and recommendations to meet and maintain total transfer capability (AD25-4).  

After the public comment period ordered by the FRA, FERC will submit recommendations for statutory changes, if any, to Congress. 

The ERO’s recommendations included 35 GW of additional transfer capability across FERC’s planning regions, with more than 14 GW in ERCOT across the SPP-South connection and two entirely new connections. (See NERC Releases Final ITCS Draft Installments.) This suggestion prompted a comment from ERCOT, which pointed out that about 32 GW of solar and wind resources have come online in Texas since Winter Storm Uri in 2021 and said NERC’s analysis may not have fully accounted for these additions. 

“The nameplate capacity these resources have added to the ERCOT system is more than double the 14 GW of interregional transmission the ITCS recommends for the ERCOT region,” ERCOT said. “The ITCS’ attempt to account for future resource growth on the ERCOT system likely underestimates the resource additions that will actually occur as ERCOT continues to commission new resources at a record pace, connecting over 12 GW of new generation in 2024 alone, on top of the 7 GW connected in 2023.” 

ERCOT also cautioned that the ITCS “may be overly optimistic” in its expectations for the proposed transmission expansions, noting that “generation resources must still be available to provide power … over those transmission lines.”  

The ISO said market incentives, which the ITCS did not take into account, “are an indispensable part of energy adequacy and future generation growth [and] are actively being examined and refined in the ERCOT region.” 

In response, NERC said it recognizes the potential impact of market mechanisms on energy adequacy, although they were not a part of the ITCS. In addition, the ERO acknowledged that the effect of “connections such as ERCOT to” SERC Southeast — mentioned in the report — needed more study than Congress allotted time for. It pointed out the report contains a chapter with areas for future study to understand the relationship between transfer capability and grid reliability. 

NERC also replied to a comment from the Eastern Interconnection Planning Collaborative, an association of 18 planning authorities from the Eastern and Central U.S., which argued for expanding the ITCS by “adding credit for transmission products and plans” and warned against using the study “as a metric for determining prudent additions.” (See EIPC: Transmission Studies Need More ‘Granularity’.) 

The ERO observed that such a change “would have exceeded the scope of the” FRA and might even have usurped FERC’s responsibility to recommend regulatory action. However, NERC said it would continue separately to highlight the issues raised by EIPC and would urge policymakers and industry to take them under consideration. 

Finally, NERC pushed back on a comment from sponsors of the South Carolina Regional Transmission Planning Process and the Southeastern Regional Transmission Planning Process, which between them comprise a number of utilities, including Dominion Energy South Carolina, Santee Cooper, Associated Electric Cooperative and Duke Energy. The SCRTP and SERTP sponsors claimed that while NERC facilitated stakeholder engagement during the first phase of analysis, for the most part the ERO could not engage stakeholders during the second phase “due to time constraints.” 

NERC countered this assertion, saying it had engaged in outreach at every stage, including “consulting with transmitting utilities and other stakeholders” in the Southeast. The ERO also emphasized that its consultation process for the second phase of analysis consisted of multiple steps that continued through more than half of 2024, and that the ITCS Advisory Group of grid stakeholders “included two representatives from the Southeastern U.S.”