Pacific Gas and Electric’s plans to extend the life of the Diablo Canyon nuclear power plant through 2030 remain on track after a federal appellate court rejected environmental groups’ petition challenging an exemption to the license application deadline.
A three-judge panel of the U.S. Court of Appeals for the 9th Circuit issued an opinion April 29 rejecting the petition from San Luis Obispo Mothers for Peace, Friends of the Earth and the Environmental Working Group (23-852).
Diablo Canyon, a 2,200-MW nuclear plant on California’s Central Coast, provides about 8.6% of the state’s total electricity supply and around 17% of its zero-carbon electricity. PG&E had planned to retire Diablo Canyon’s two units in 2024 and 2025.
But in September 2022, Gov. Gavin Newsom (D) signed Senate Bill 846, directing PG&E to run the nuclear power plant until 2030 to improve the reliability of the state’s energy system.
In their petition, the three environmental groups asked the court to review the Nuclear Regulatory Commission’s decision to allow Diablo Canyon to keep running while the NRC considers its license renewal application. Ordinarily, such an action is taken if a renewal application is submitted five years before a license expires.
PG&E did not submit the renewal application before the five-year deadline and asked NRC for an exemption to the “timely renewal” requirement. NRC granted the request in March 2023, and PG&E submitted its renewal application in November 2023.
NRC has said it typically takes 22 months to review a license renewal application.
NRC regulations allow exceptions to its five-year application deadline under special circumstances if the exception won’t create health or safety issues.
The appellate panel noted “the highly unusual circumstances of this case,” specifically lawmakers’ direction to postpone Diablo Canyon’s retirement.
“But for the California Legislature’s determination of a material change in the electrical needs of its citizens, by all accounts PG&E would have terminated operations at Diablo Canyon,” the panel said in its opinion.
The environmental groups argued that the NRC exemption ignored the environmental concerns of running Diablo Canyon past its 40-year license term. But the appellate panel said the groups hadn’t presented “any specific evidence of concerns with Diablo Canyon.”
In addition, the panel said, “NRC’s continuing oversight authority assuages safety concerns.”
In response to the court’s decision, Caroline Leary, COO and general counsel for the Environmental Working Group, said the environmental groups would “explore all avenues to reverse the NRC’s irresponsible decision.”
“PG&E and California’s leaders are recklessly gambling with Diablo Canyon, endangering the health and safety of countless individuals,” Leary said in an April 29 statement.
Diablo Canyon Unit 1 has been in operation since 1985 and Unit 2 has been running since 1986. Operating licenses for the units expire in November 2024 and August 2025.
PG&E at one time planned to keep Diablo Canyon running and submitted a license renewal application in 2009. But the utility decided to retire the units instead, and it withdrew the application in 2018. Plans for Diablo Canyon changed again in 2022 with the passage of SB846.
The New Jersey Board of Public Utilities has opened its fourth offshore wind solicitation, with a planned capacity of up to 4 GW, as the state seeks to rebound from the sudden dissolution by developer Ørsted of two of the state’s first three projects.
The solicitation, outlined in an April 30 guidance document, seeks to create a “robust competition” and attract projects with a capacity of between 1.2 and 4 GW, and even larger “if circumstances warrant,” according to the guidelines. The solicitation will close at 5 p.m. on July 10.
It follows by just three months the BPU’s announcement of the favored projects in the state’s second solicitation. If the three ongoing projects backed by the state come to fruition, the state would have slightly less than half of its target of 11 GW by 2040. (See NJ Awards Contracts for 3.7 GW of OSW Projects.)
BPU commissioners, who voted 4-0 on the plan, touted the solicitation as a show of the state’s strength in the sector.
“This solicitation really demonstrates that we are committed to seeing the economic development that offshore wind is bringing to New Jersey, and will continue to bring, as well as the clean energy that is so important for the residents,” BPU President Christine Guhl-Sadovy said after the vote.
The BPU initially pursued a strategy of holding solicitations every two years, selecting the 1,100-MW Ocean Wind 1 in 2019, and the 1,148-MW Ocean Wind 2 and 1,510-MW Atlantic Shores Offshore Wind in 2021. But it has accelerated the process since Ørsted abandoned its two projects in October 2023 and left Atlantic Shores as the only ongoing project. (See Ørsted Cancels Ocean Wind, Suspends Skipjack.)
Commissioner Zenon Christodoulou called the task of preparing the solicitation a “really monumental task that you guys have accomplished in such a short time,” referring to BPU staff.
“We are admired across the country,” he said. “Other states look to New Jersey and look to what you have done and say: ‘We can do that.’ And they’re learning from us. They appreciate it. And you’ll see many states following our path.”
The guidance document sets out a schedule in which the BPU would select projects by the end of the year, with an expected completion date of 2032. Developers would submit bids stating the price of the Offshore Wind Renewable Energy Certificates (OREC) — a measure that represents the environmental attributes of 1 MWh — at which they would undertake the project. The BPU then would pick those viable projects that best meet the agency criteria and would be the most financially favorable to the state.
The document also contains a section that allows projects selected in the first two solicitations to submit a “Re-Bid Project.” The section effectively would allow them to seek to adjust their cost structure to adapt to the rising costs — from the supply chain, material prices and interest rates — that have prompted developers to pull out of OSW projects in the U.S. It would also enable them to seek additional state support.
Community Solar Capacity Doubled
In a separate action at the April 30 meeting, the BPU also agreed 4-0 to reopen the state community solar program on May 15 and expand its capacity from 225 MW to 500 MW.
The expansion comes in the first year of the program as a permanent entity after two pilot programs demonstrated the interest of solar developers and ratepayer subscribers.
The BPU opened the first permanent program solicitation on Nov. 15 with a target capacity of 225 MW, to be allocated in four capacity blocks, one for each territory serviced by the four electric utilities in the state. The board closed the solicitation after applications exceeded the available capacity, but a law signed Jan. 24 by Gov. Phil Murphy allowed it to increase the capacity available to 275 MW if applications exceeded 225 MW.
The law will allow capacity expansions in the future as well: by 250 MW if applications exceed 500 MW in 2025, and by an additional 150 MW in subsequent years. Under the current guidelines, if the capacity now allocated for community solar in 2024 is not used, it will be rolled over and available in 2025.
Fred DeSanti, executive director of the New Jersey Solar Energy Coalition, said he was “pleased to see the program move forward quickly” and added that it “shows that the board and this administration is committed to community solar.”
State officials see the program as a key element in helping the state reach its goal of 12.2 GW in solar capacity by 2030 and 32 GW of solar by 2050. The state had 4.8 GW of installed capacity as of March 31, according to BPU figures.
The state enacted its first community solar pilot program in 2019, and a second pilot in 2021. The first program, which attracted 252 applicants, approved 45 projects totaling 75 MW. The second pilot, which attracted 412 applications, awarded 105 projects totaling 165 MW. (See NJ Opens Community Solar and Nuclear Support Programs.)
The BPU board also approved some program rule changes April 30, including allowing low-income customers to “self attest” to their household income, rather than having to show proof — a change long sought by solar developers who said requiring customers to document their income dissuaded many from applying to participate in community solar.
Another rule change approved by the board requires utilities to discount a customer’s bill at least 20% for participating in the community solar program.
Facilitating DER Connections
The board also backed several rule changes designed to help distributed energy resources connect to the grid.
The BPU based the rules on the short-term conclusions of a Grid Modernization Study released in November 2022. The changes include creating a streamlined process for utility interconnection applications and making “clearer and more consistent distribution system information available to potential project applicants,” according to a BPU statement. Another section would fashion a “pre-application and verification process that will provide interconnection applicants with an early indication of feasibility and costs.”
Longer-term changes aimed at capacity expansion and further grid modernization will be addressed in an upcoming “grid modernization forum,” the BPU said.
President Guhl-Sadovy said the ability of the state’s grid to accept new DER resources is critical to its energy future. The development of new rules, she added, “marks a pivotal step toward making the interconnection process more efficient as we prepare to modernize the grid while mitigating impacts on ratepayers.”
Outlining the rules at the board meeting, BPU staffer Natalie Stuart said they are designed to “remove stakeholder-identified sources of confusion or delay in the DER interconnection process, and to prepare for a broader grid modernization effort that will enable the grid to host more DER capacity.”
“These rule changes will significantly reduce the uncertainty, inefficiency and delay applicants with viable DER projects seeking interconnection experience, while also clarifying the level of commitment and responsiveness expected from active applicants,” Stuart said. She added that the rules would facilitate the deployment of community solar projects by providing “greater assistance in navigating the interconnection process.”
The 1st Circuit Court of Appeals on April 24-25 affirmed denial of two challenges to environmental approvals of the Vineyard Wind 1 project under construction off the coast of Massachusetts.
One of the challenges was brought by a group of Nantucket residents (23-1501), and the other by solar company Allco Renewable Energy and its owner, Thomas Melone (23-1736).
The 806-MW Vineyard Wind 1 project already has multiple turbines in operation and will consist of 62 turbines when complete, potentially by the end of this year.
The challengers argued that the federal government did not properly evaluate Vineyard Wind’s effects on right whales, an endangered species. Both challenges were denied by the Massachusetts District Court prior to the appeals process. (See Lawsuit Against Vineyard Wind over Threat to Whales Tossed.)
In biological opinions issued in 2020 and 2021, the National Marine Fisheries Service (NMFS) determined that Vineyard Wind is “not likely to jeopardize the continued existence” of right whales and other endangered species, while determining the project “will have no effect on critical habitat designated” for right whales.
NMFS did note that the noise associated with pile driving could result in the “harassment” of some right whales but wrote that no right whale injury or mortality is expected from any aspect of the project.
To mitigate potential impacts, the Bureau of Ocean Energy Management (BOEM) required several mitigation measures in its approval of the project, including restrictions on when Vineyard Wind can conduct pile driving.
The challenge by the Nantucket residents, initiated in 2021, argued that NMFS’s biological opinion was deficient, and that BOEM’s environmental impact statement violated the National Environmental Policy Act by relying on a deficient biological opinion.
Allco’s challenge, which also began in 2021, alleged that NMFS erred in issuing Vineyard Wind 1 an Incidental Harassment Authorization.
Both challenges were heard by a panel of judges on the 1st Circuit entirely nominated by Democrats.
“NMFS and BOEM followed the law in analyzing the right whale’s current status and environmental baseline, the likely effects of the Vineyard Wind project on the right whale, and the efficacy of measures to mitigate those effects,” wrote Judge William Kayatta in response to the Nantucket residents’ appeal.
Responding to the Allco appeal, Kayatta wrote “it is clear from the record that NMFS applied its scientific expertise to consider the nature of Vineyard Wind’s activities and the type of harassment expected to occur,” and took no issue with NMFS’s finding that the project would have a “negligible impact” on the right whale species.
According to the law firm Bracewell, the rulings “mark the first appellate decisions affirming the federal government’s issuance of permits to the Vineyard Wind Project,” and will help set legal precedents that “will shape the trajectory of the emerging offshore wind sector.”
The 1st Circuit must still hear a pair of pending challenges brought by commercial fishing and seafood organizations, led by the Responsible Offshore Development Alliance and Seafreeze Shoreside, Inc. (23-2051 and 23-1853).
MISO plans to use the summer to polish its approximately $20 billion second long-range transmission portfolio and have it ready for board consideration by mid-September.
The grid operator last week said its planners will work to debut a draft portfolio by mid-July for a few weeks of evaluation and stakeholder feedback with its Planning Advisory Committee. MISO said it plans to have the PAC’s decision on whether to recommend the portfolio by mid-August.
By the end of August, MISO is targeting consideration by the System Planning Committee of its Board of Directors. Finally, MISO anticipates presenting the portfolio before its full board for a decision in September during its quarterly Board Week to be held in Indianapolis.
During an April 26 workshop to discuss the LRTP, WEC Energy Group’s Chris Plante asked if MISO is giving thought to the lower-voltage upgrades MISO will need to support a “superhighway” of 765-kV lines. He said he doubts there’s enough time for MISO to detect all smaller projects needed to accommodate the lines.
Executive Director of Transmission Planning Laura Rauch said MISO is hard at work identifying smaller upgrades.
“We think we have a schedule that gets us to September,” she said. However, she added MISO will revisit its timeline if analyses need more time.
MISO is contemplating including several transmission benefits in the impending business case it will make for the second LRTP portfolio. It is considering:
reduced risks from extreme weather impacts.
capacity and energy savings from smaller transmission line losses.
the lines’ contribution to decarbonization.
avoided transmission investment.
fuel and congestion savings.
reduced transmission outage costs.
avoided costs from adding capacity that otherwise would be necessary without the lines.
mitigation of reliability issues.
Some stakeholders attending the workshop criticized MISO for attempting to price minimized reliability risks into the benefits of LRTP using the RTO’s value of lost load. They said it isn’t guaranteed the lines will abate reliability issues.
Bill Booth, consultant to the Mississippi Public Service Commission, said NERC violations are anticipated only five years in advance. Booth asked how MISO is confident poor reliability conditions will occur on its system 30 years in the future absent the lines. He also recommended MISO contrast the price of LRTP versus building incremental reliability projects.
“How do we know that that is providing the least-cost reliability to customers? This is a speculative metric, and maybe doesn’t belong here,” Booth said.
Rauch said MISO will pit the LRTP second portfolio’s usefulness against several cases.
“Reducing risk of load shed is a value, and we can and should continue to talk about it,” she said.
Sustainable FERC Project attorney Lauren Azar said she supported MISO attempting to monetize the value of regional backbone transmission in avoiding the risk of future load shedding.
“There’s no precision in this. Just because we’re looking at reliability standard violations 30 years out, doesn’t mean mitigating them isn’t valuable,” Azar said. She pointed out that when transmission is needed to meet NERC reliability criteria, the projects are built no matter the cost benefit.
American Transmission Co.’s Thomas Dagenais said it’s “a dangerous precedent” to simply bank on real-time operation to avoid load shed and not factor the value of avoided load shed in regional transmission.
He likened the second portfolio to a decision to obey the speed limit on a morning commute to work. He said while he could go “100 mph and nothing bad could happen,” he’d prefer to follow the speed limit for added protection.
MISO said it will test large projects from its 2023 and 2024 annual transmission expansion cycles, it and SPP’s $2 billion Joint Targeted Interconnection Queue portfolio, and the Grain Belt Express and other merchant HVDC projects with signed transmission construction agreements to see if they handle some of the issues it’s prescribing LRTP lines for.
MISO said it “may modify, add to or remove transmission facilities” because of its testing.
WPPI Energy’s Steve Leovy said MISO asked whether it will study a scenario that includes the SOO Green HVDC Link, which is planned to run underground along existing railway corridors from Iowa to Illinois.
“You’re right that there are multiple HVDC construction discussions in the footprint,” Rauch said, but stressed that MISO will study only the portions of merchant HVDC lines that have signed agreements now. She added that SOO Green’s hypothetical output at the moment appears to be destined for PJM.
Several MISO stakeholders have asked that MISO include the $4 billion Grain Belt Express in base case models for long-term transmission planning. Multiple MISO state commissioners also have said the model should reflect the system that will exist by the time LRTP projects are built, and tacking on an after-the-fact sensitivity analysis that includes the merchant HVDC line isn’t adequate.
SPP has filled two vice presidential vacancies, naming David Kelley as its CFO and finance vice president and promoting Casey Cathey to Kelley’s former engineering VP position.
“I’m very excited to have both of them in these roles as SPP continues to grow, advance and mature in response to our stakeholders’ needs,” SPP CEO Barbara Sugg said in an April 29 statement.
Kelley was acting as SPP’s interim CFO following Deborah Sterzing’s surprise resignation in March after a little more than a year on the job. (See “CFO Sterzing Resigns,” SPP Board Approves Markets+ Phase 1 Tariff.)
He will be responsible for developing and executing SPP’s financial strategy. Kelley has more than 20 years of utility industry experience, having served in various engineering and market leadership roles at SPP since joining in 2008.
“I’m keenly aware [of] how critical it is to consider affordability and financial responsibility in everything we do as a service provider,” Kelley said.
Cathey will lead SPP’s evolving approach to consolidated transmission planning and will oversee the ongoing development of a transmission expansion plan and the advancement of regional resource adequacy policies. He previously was senior director of grid asset utilization, where he led a group responsible for developing and implementing novel industry policies, tools and procedures aimed at preparing it for the grid of the future.
“Our industry is navigating an evolving landscape with many challenges and opportunities, and I am eager to work with our stakeholders to develop and implement strategies that will safeguard and prepare our region’s energy future through innovative system planning,” Cathey said.
Federal regulators are moving ahead with plans to auction wind energy leases with a potential 18-GW capacity off the coasts of Oregon and northern New England.
The U.S. Bureau of Ocean Energy Management announced the plans April 30 and is seeking comment on the details before finalizing what would be the first such auctions in either location.
Most of the capacity identified in this plan is in the Gulf of Maine, where eight wind energy areas totaling nearly 1 million acres hold the potential for 15 GW of electrical generation.
The southern New England coast is the site of heavy wind energy development efforts, with one utility-scale offshore wind farm completed recently, a second under construction, a third about to begin construction and others seeking to rebound from economic setbacks that have delayed construction.
The water there is shallow enough that wind turbines can be installed with conventional fixed-bottom tower foundations. The Gulf of Maine is so deep in most places that wind energy development there would rely on floating turbine technology, which only recently is being used at scale worldwide.
Maine is attempting to position itself as an early leader in the floating wind industry, with research programs at the state university and an application with BOEM to place a floating research array off the central coastline. (See Maine One Step Closer to OSW Research Lease.)
The eight potential commercial lease areas BOEM identified April 30 are farther south in the Gulf of Maine, most of them closer to New Hampshire or Massachusetts than to Maine.
Speaking at the International Partnering Forum — Oceantic Network’s offshore wind conference April 22-25 — Maine Gov. Janet Mills (D) announced her state has begun the process to procure up to 3 GW of offshore wind energy by 2040. The state issued a Request For Information on April 24 to shape this process.
Floating wind technology will be needed along the Oregon coast, as well, due to water depths there. BOEM is considering adding lease stipulations that would award bid credits for bidders that commit to help develop the workforce and supply chain for the floating wind industry.
The two designated Oregon lease areas total nearly 200,000 acres and sit dozens of miles apart off the state’s southern and central coastline.
The U.S. Bureau of Ocean Energy Management is proposing to auction two wind energy lease areas off the Oregon coast. | BOEM
BOEM’s efforts to site offshore wind off Maine and Oregon have drawn opposition for their feared impact on commercial fishing. BOEM has made changes to draft proposals based on feedback from fishers and other stakeholders, and it said April 30 it would continue to consider their opinions.
“As we move forward with offshore wind energy in Oregon and the Gulf of Maine, the Bureau of Ocean Energy Management remains dedicated to close collaboration with our government partners and key stakeholders,” BOEM Director Elizabeth Klein said in the news release. “We’re excited to unveil these proposed sales and emphasize our commitment to exploring the potential for offshore wind development from coast to coast.”
Oceantic CEO Liz Burdock said in an April 30 news release:
“BOEM’s combined announcement solidifies two new regional markets for floating offshore wind, balancing the development of this industry sector across both coasts. New lease areas in Oregon will support a further buildout of the West Coast’s regional supply chain, adding strength to California projects. And in the Gulf of Maine, this new 15-GW potential will drive the creation of a floating offshore wind supply chain on the East Coast.”
FERC on April 26 approved a settlement requiring the Twin Ridges wind farm in Somerset, Pa., to pay ReliabilityFirst $30,000 over a “litany” of reliability standard deficiencies at the facility.
The commission said in a filing that it would not further review the settlement, filed by NERC in its monthly spreadsheet notice of penalty March 28 along with a separate spreadsheet NOP concerning violations of NERC’s Critical Infrastructure Protection standards (NP24-6).
Exus Management Partners, which claims to manage renewable energy assets worldwide with a total capacity of 11 GW, reportedly acquired the Twin Ridges facility in March from global energy developer Vitol. However, the settlement stems from five self-reports submitted to RF in July and August 2021, the year before Vitol purchased the wind farm from a private equity fund managed by BlackRock.
An operations and maintenance (O&M) company employed by BlackRock informed RF in July 2021 that the plant was in violation of PRC-005-6 (Protection system, automatic reclosing and sudden pressure relaying maintenance). The following month it submitted additional reports of infringements of COM-002-4 (Operating personnel communications protocols) and VAR-002-4.1 (Generator operation for maintaining network voltage schedules).
According to the first self-report, the Twin Ridge owners did not perform required maintenance on several protection system components, including the facility’s only sudden pressure relay, its battery bank and each of its lockout relays. The violation began Jan. 1, 2016, when PRC-005-6 became enforceable, and ended Oct. 20, 2021, when Twin Ridges finished mitigation activities. These included performing the skipped maintenance and implementing annual reviews of its protection system inventory and maintenance activities.
Regarding the COM-002-4 violation, the O&M company reported that “there was no formal program for communications training of the entity’s operating personnel under the previous ownership,” or at least no program for which records could be found. The violation lasted from July 1, 2016 — the effective date of the standard — to Dec. 6, 2020, when the owners finished training operating personnel in the relevant communications process.
The three VAR-002-4.1 infringements similarly involved a lack of records establishing that required maintenance had been performed. Noncompliance began Dec. 22, 2017, the day after RF audited the facility, and ended in January 2022 when the entity adopted new control-room alarm capabilities, a corporationwide VAR-002 procedure and training for operations personnel.
RF attributed all violations to a fumbled ownership transition, suggesting that records were mislaid during interactions between “multiple owners and O&M companies,” along with a lack of oversight by the facility’s former owners and operators in the case of the VAR-002-4.1 violations. It assessed a moderate risk from all the infringements, noting that the small size of the facility limited “its overall … impact and the potential magnitude of harm.”
While the regional entity observed that entities “will not be excused from [their] compliance and reliability responsibilities … merely because [they are] small,” it also remarked on the “proactive actions of new owners and a new O&M,” crediting both BlackRock (which it referred to as the “2018 owner”) and Vitol (the “2022 owner”). RF said it decided to limit the penalty in order to “promote the transparent review and self-reporting seen here.”
NEW ORLEANS — One of the most common friction points as the offshore wind industry sets up in the United States is its potential impact on commercial fishing.
The effects are hard to predict because there’s so little operational data from U.S. waters.
Environmental impact reports prepared for individual proposals have projected that wind farm construction and operation likely will have negative effects on commercial fishers, with the severity depending on the equipment they’re using and the species they’re pursuing. The cumulative or synergistic effects of multiple projects in the same region are expected to be greater still.
Reducing the resulting friction with the fishing industry was a workshop topic at the International Partnering Forum on April 23. One focus of conversation was the effort by the 11 coastal states from North Carolina to Maine to create a regional framework for compensating fishers for economic losses caused by offshore wind farms.
The Fisheries Mitigation Project of the Special Initiative on Offshore Wind has the standard goals of avoiding impact where possible, minimizing impacts that cannot be avoided and mitigating those impacts that occur, with financial compensation if other mitigation options are exhausted.
Kris Ohleth, director of the Special Initiative on Offshore Wind, moderated the workshop discussions.
Greg Lampman, director of offshore wind for the New York State Energy Research and Development Authority, noted the current effort is a significant shift from the early days of offshore wind planning.
“Back in 2018, that was a real third rail,” he said. “No one wanted to talk about compensatory mitigation because we were not going to be harmed by offshore wind in any way, shape or form. And to suggest [otherwise] was going to be problematic for the industry.”
Vineyard Wind was the first major U.S. project to put steel in the water, and it did so with a problematic compensation plan, said Geri Edens, head of permitting and environmental affairs for Vineyard Offshore.
She said the regional approach is needed, especially in areas where multiple adjoining wind farms will span multiple states’ coastlines.
“It’s impossible for every single project in every single lease area to confine and set up these programs when fishermen are fishing across these lease areas,” she said. “The way it’s set up, it’s fraught with potential disadvantages and discrepancies between fishermen. There’s lots of opportunity for double dipping, there’s all kinds of things that could become really problematic if we have like five, six of these different individual programs set up.”
The panelists speaking in this IPF24 workshop were drawn from the offshore wind industry and government. The fishing industry was not represented.
“The fishermen are in this really awkward position where in general they’re not in favor of offshore wind and would like to see it stop,” Lampman said.
If they participate in the mitigation project, he explained, they might be seen as supporting offshore wind or be blamed for a final product the industry does not like; if they shun the process, they have no voice in shaping that final product.
Education and outreach are needed to get these vital stakeholders into the process, Lampman said.
In one notable instance, industry representatives quit a Rhode Island advisory board because they felt their concerns were being ignored. (See Fishermen Quit RI Coastal Board in Anger.)
Brian Hooker of the U.S. Bureau of Ocean Energy Management said the regional mitigation project has the advantage of not starting entirely from scratch.
“There are other programs that exist,” he said, such as a fisheries contingency fund in the Gulf of Mexico and fishery disaster declarations by the National Fisheries Service.
The workshop included audience questions.
Gordon Carr, executive director of the New Bedford Port Authority, asked what would happen if projects the mitigation program is based on prove inaccurate.
“What if downstream, we start realizing that the impacts are greater?” he asked. “By the time we’re realizing that, it’s really late for the commercial fishing industry, and obviously that’s sort of an existential concern, both for us and for them.”
“My response would be mostly geared towards what we have under our authorities under the Outer Continental Shelf Lands Act and our regulations,” Hooker said. “But I do believe we have that regulatory authority to address an unforeseen harm.”
Lampman suggested the federal government create a disaster fund, given that it is pressing for offshore wind development and regulating it.
“One of the big questions that remains is ecosystem change, and how [do] the fisheries, fish population and population dynamics change as a result of the big picture? And it’s not a number that you can really pick out of the hat right now,” he said.
Edens embraced the idea of taxpayers paying for impacts on fisheries that exceed the contracted mitigation sums, because open-ended financial commitments are difficult for developers to make. “I know that people don’t want to hear this, but these projects have to be financed. People that invest in these projects need certainty.”
Peter Silva of Coastal Tribal Resources, an elder of New York’s Shinnecock Nation, said his concern is not so much for the commercial fishery but the wellbeing of fish and the environment in which they live.
He applauded the panelists and the entities they represent for their words and commitment but asked about all the unknowns that persist, now that the first large U.S. offshore wind farm is complete, the second is under construction and two more gear up to start construction this year.
Has boat traffic impacted commercially valuable fish in New York and New England waters? Are other species expanding their habitat into the area? Are breeding grounds affected? Are there changes in currents? Are dead zones expanding in Long Island Sound? Are water temperatures changing?
Those are excellent questions, Ohleth responded, but they are outside the expertise of panel members.
“I don’t think I’m the right person to speak the details there,” said Bryan Stockton, Ørsted Americas head of federal and regulatory affairs. “But I know that if your question is, as a determined condition of approval, do developers or government agencies in collaboration have a responsibility to continue to pursue robust monitoring, the answer is absolutely yes.”
Lampman said he, too, was unable to speak to fisheries population dynamics, but the Regional Wildlife Science Collaborative for Offshore Wind was established and funded for exactly that purpose, looking at not single projects but the aggregate impact of all offshore wind farms in the region.
Edens said Vineyard has multiple monitoring programs in place during construction that will continue through the project’s life. “So, I think we will get there, but it’s going to be a while before we have real answers to those very good questions,” she said.
“Thank you very much for your honest presentation and thoughts,” Silva said. “And hopefully the next time I’m here, if given the opportunity, I will hear [about] monitoring, and the good and the bad and the ugly of monitoring findings and corrective actions that we take.”
Additional IPF24 Coverage
Read NetZero Insider’s full coverage of the 2024 International Partnering Forum here:
Manny Cancel, a senior vice president at NERC who has headed the Electricity Information Sharing and Analysis Center (E-ISAC) for the past four years, will retire early next year, NERC said in a statement April 29. Stan Hoptroff, NERC’s vice president of business technology, also will leave the ERO in 2025, the statement said.
NERC plans to begin looking for candidates to fill both roles this summer and has retained executive search firm Heidrick and Struggles to manage the search.
“Both Manny and Stan have been exceptional teammates to NERC, the ERO Enterprise and our stakeholders. They have provided wise counsel and been stalwart contributors to our executive team as we navigated numerous challenges over the past years, and they will both be sorely missed,” NERC CEO Jim Robb said. “For both, this is their second retirement, and I wish them the best after their stellar careers in our industry. And I appreciate the time they have given us to prepare for their succession.”
Cancel joined NERC in January 2020, replacing Bill Lawrence as E-ISAC head. (See Former Con Ed Exec to Lead E-ISAC.) Before the ERO, he was chief information officer at Con Edison, where he was active on the Member Executive Committee, an advisory group for the E-ISAC.
His tenure as E-ISAC head has seen a marked rise in physical threats to grid reliability as well as damage to electric equipment. Some of these threats have political motivations, such as the neo-Nazi leader who allegedly plotted to damage substations in Baltimore to start a race war. Other attackers have smaller-scale goals, like the men accused of damaging electric facilities in Washington state to cover up a burglary. In the case of the Moore County, N.C., rifle attacks of December 2022, no suspects or motives have been identified.
Electronic threats also remain a major area of concern for the E-ISAC. In a media call earlier this month, Cancel said the center has seen a “dramatic increase in malicious cyber activity” amid rising geopolitical tensions between China and Taiwan, Russia’s invasion of Ukraine and Israel’s military actions in Gaza. (See Robb, Cancel Review Reliability Landscape.)
Cancel has represented the industry before Congress and in other forums such as the ERO’s annual GridSecCon security conference, and has overseen the past two iterations of the biennial GridEx security exercise.
Hoptroff has been with NERC since 2014; his previous positions at the ERO include chief technology officer. Before NERC, he worked with Southern Co. for 33 years in a variety of technology-related roles.
While at NERC, Hoptroff has had “overall responsibility for developing and overseeing the company’s IT strategy, systems, applications, budget and personnel,” according to his page on the ERO’s website. He has led such initiatives as the ERO’s Align software platform and Secure Evidence Locker, which went live in 2021 with the goal of collecting compliance and enforcement activities of NERC and the regional entities into a single secure platform.
NEW ORLEANS — Offshore wind is touted as a source not just of emissions-free electricity but also economic stimulus, giving many businesses at every level of the food chain a stake in each multibillion-dollar wind farm.
More than 375 exhibitors were on hand at the International Partnering Forum April 22-25, hoping to steer some of that money to their companies.
In dozens of booths across acres of floor space, they pitched everything from bird warning systems to construction vessels to training. Exhibitors ranged from startups to industry leaders, labor unions to national trade delegations.
On the last day of IPF24, NetZero Insider spoke with a random assortment of exhibitors about their impressions of the U.S. offshore wind market, their take on the convention and the products they were pitching. Here’s what they had to say.
Underwater Autonomy
A sleek machine on a three-axle trailer that looked like a cross between a torpedo and a submarine was neither — it was “Abraham,” Terradepth’s prototype autonomous underwater vehicle.
It is built to operate for up to a thousand nautical miles on its own, conducting underwater surveys for up to a month at a time and resurfacing as needed so its diesel generator can draw air and recharge the lithium-ion batteries that power it underwater.
It holds the potential of massive savings in fuel and personnel costs compared with survey operations controlled from a crewed surface vessel.
Terradepth is trying to bring Abraham to the attention of offshore wind and other marine industries, said Chief Operating Officer Kris Rydberg. It needs decision-makers to open their minds about a new way to approach underwater tasks and open their wallets to make that happen.
“This is not inexpensive and we’re a startup,” he said. “We bootstrapped it up to this point. We’re going to need some additional funding to go from prototyping to full-on commercial. But the concept, the technology is proven.”
Richard Fryburg, chief growth officer of Subsalve, said he is eager for American manufacturers such as his company to reap the benefits of the wind projects proposed off our shorelines.
With his broad New England accent and his stack of blazing fluorescent buoyancy sacks, Fryburg and his booth were hard to miss. But visibility was not translating to sales.
“We’ve been approached to provide our products by many of these companies coming in from outside the U.S., who have proposed that they want to buy locally,” he said. “They’re not buying locally. They’re bringing products, staff and equipment from outside of the country. And there’s a gap, and I’m not sure how that gets fixed, but I don’t see that local vendors and suppliers are benefiting that greatly from this insurgence of foreign companies.”
Fryburg added: “I think we’re competitive on price.”
Ironworkers Local 5 had one of the more visually striking displays in the exhibit hall and easily the most ironic swag: The same guys who assemble tons of structural steel were handing out balsa-wood toy gliders weighing a few grams apiece.
The thousand-member local hopes its members will gain from the spate of construction planned off the East Coast, said Ray Cleland.
What the union would like, as early as possible, is a list of certifications that managers want ironworkers to bring to a given project, Gary Armstrong said. Local 5 can draw workers from any local in the country and it can do training — if it knows the skillsets needed.
“Sparrows Point (Maryland) was contracted for some secondary steel components, and we had like 45 ironworkers there working,” Armstrong said. “Then Ocean [Wind] 1 stopped, and we lost that contract.”
But things are looking up onshore.
“I think there’s always going to be work,” Armstrong said. “With the big infrastructure money starting to roll out, there’s going to be a lot of other opportunities, too.”
Simon Thomson, international business development director for English boatbuilder Diverse Marine, had a glum assessment of the U.S. market for his company’s crew transfer vessels:
“Flat and dead.”
He partly blames politics. There is one permitting system in the United Kingdom and hundreds in the United States, often with significant variations from one state to the next.
Thomson said things take longer to get built in America, too. He pointed to a mural-sized photo of the newest Diverse crew transfer vessel, the Predator, speeding away for delivery to the customer.
“The length of time to build a boat like that — that was delivered two weeks ago — is about a third of the time it’s taking here [in the U.S.],” he said. “If you said to me today, I want to build four of those, just like that, you could probably start cutting metal within — let’s go for it — 10 days.”
The issue is moot, in a sense. Because of the Jones Act, Diverse cannot sell the vessels it builds on the Isle of Wight for use on U.S. offshore wind projects. So, it has a manufacturing partner in Washington state.
Does Thomson see a growth pattern for U.S. offshore wind?
“That’s a very difficult question to answer, because of all the issues you have and all the political decisions,” he said. “We look at the United States as separate countries all held together in a union. You all have different rules, laws and interests.”
Woods Hole Group is the commercial oceanography spinoff of the oceanography research institute of the same name in Massachusetts.
The data and data analysis the company provides is valuable for every stage of a wind farm’s existence, from planning and design to operation to decommissioning.
Woods Hole Group started this work in oil and gas, senior manager Rafael Ramos said, and it was a natural transition to wind. The company sees a good future in this sector.
“In the U.S., it got off to a flying start, and then we hit this barrier with projects being canceled,” Energy and Mining Business Unit Director Rob Smith said. “I think it’s a hiatus, I think it’s a rebalancing.”
James Jatho and Liège Olmos were on hand to represent Liebherr, a German crane manufacturer.
Jathos said IPF24 was a mixed bag from his perspective, because the company’s push at the show was its maritime products — the cranes mounted on ships and offshore platforms.
“I handle mobile crawler cranes,” he said. “So, we’re pursuing offshore wind in the sense that you need something to move stuff around on the ports. For me, the show wasn’t as successful for direct customers who would buy from us, but more so talking to engineering firms, the various ports, getting our product out in front of them so that when they do need a crane, they come to Liebherr first.”
Olmos said they attended IPF23 in Baltimore last year. “We had a small booth there, but the quality of leads we got there was surprisingly good, so we decided to go bigger this year. This year, I think the convention center is too big. We got less traffic, but the quality of the leads are good.”
Liebherr does have an answer for the heaviest offshore wind components, Jathos said: the L-13000, rated at 3,000 tons. The seven that have been built are the largest crawler cranes outside of China. The eighth is being built now, and the wait time for the ninth will be in the 18- to 24-month range.
At its booth, Spinergie was promoting its suite of fleet efficiency services.
During planning, construction and operation of an offshore wind farm, “there’s a lot to coordinate, there’s a lot of vessels that are orchestrating the project all at the same time,” said Patrick Sanguily, general manager Americas.
“We recently supported a survey campaign off the East Coast. I can’t say for whom. We tracked all the service vessels, facilitated the daily reporting from the vessel to the charterer, we gave them the metrics dashboards so they could monitor the survey.”
This type of data is valuable for cost control.
His take on IPF24 and the industry in general?
“The enthusiasm is consistent,” Sanguily said. “Of course there was some recent news, some reshuffling of the schedule. But the goals remain the same. There’s some moving targets out there but it seems the industry will continue to push forward.”
Virtual Career Awareness
Vinci Virtual Reality CEO Eagle Wu was demonstrating his company’s virtual-reality workforce development tools.
Their primary intended use is early career familiarity and training, Wu said, giving prospective workers some sense of what it’s like to work in a situation or setting that they cannot see firsthand.
“These projects in the U.S. are coming four or five years from now, which has its challenges,” he said. “But what many people now recognize is, if you want to have workers to hire in four or five years, you need to talk to students today. There’s a lead time.”
A simulated experience of working on a wind turbine or the associated support functions can recruit youngsters to the field, he said.
Sabik Offshore has been coming to IPF for a decade, ever since it was a small event in a hotel. The safety equipment manufacturer appreciates the conference because it has fostered the formation of a community, said North America regional sales manager Stewart Erwin.
Sabik works only in offshore wind. Not oil rigs, not ferry boats, just offshore wind. The company’s products, including fog warnings and railings, are in place on the early projects off the Northeast U.S. coast.
Sabik has a steady business elsewhere in the world, Erwin said, and expects the U.S. market to grow as well.
