T&D World - March 2024 by Endeavor Digital Editions

Distributed Energy Resources 32 | Wildlife Mitigation 36 | Interconnection Process 40

MARCH 2024

tdworld.com

2024 IEEE PES T&D Conference & Exhibition

, page 22

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IN THIS ISSUE

Vol. 76 | No. 3

32 DEPARTMENTS

6 Global Viewpoint See You ‘IRL’

By NIKKI CHANDLER, Executive Editor

22 2024 IEEE PES T&D Conference & Exposition

10 Charging Ahead

27 IEEE PES T&D Conference & Exposition

16 Quick Clips

High-Tech Green Concrete By GENE WOLF, Technical Writer

Products & Services

FEATURES 32 PG&E’s Remote Grid Delivers Safety, Savings

DISTRIBUTED ENERGY RESCOURCES By ANDREW MULHERKAR, Pacific Gas & Electric Co., and NOA SCHACHTEL, BoxPower

36 Birds on a Wire: The Perils of Power Lines

Advanced Battery Energy Storage System Comes Online in Hawaii By T&D WORLD Staff

50 Solutions Center

Push for Undergrounding Drives Advances in Vault Covers By KEVIN MILLER and BRIAN PELTO, Ohio Gratings Inc.

WILDLIFE MITIGATION By BEN BAINBRIDGE, POWER Engineers

40 Consider A Customer DER Interconnection Process INTERCONNECTION PROCESS By BRAD BARNES and EDDIE CREIGHTON, Ameren Illinois

62 Focus: A Lineworker’s View Meet Kevin Adams, EJ Electric/ IBEW Local 3 By AMY FISCHBACH, Field Editor

44 Brazil Kick-Starts Electric Highway Initiative

ELECTRIFICATION By CARLOS GABRIEL BIANCHIN, RICARDO MUZZOLON SCHMAL, RAFAEL MOREIRA MIGGIORIN, RHAFAEL FREITAS DA COSTA, LUCIO DE MEDEIROS, LACTEC; and RODRIGO BRAUN DOS SANTOS, Copel Distribuição

63 Advertising Index 64 Straight Talk

Solutions Are Within Reach for Today’s Complex Challenges By LESLIE M. DUKE, Burns & McDonnell

ELECTRIC UTILITY OPERATIONS

54 Faces Of The Future 56 Reflecting on a Tragic Night and Resilient Recovery

By MARTY T. IVY, Mayfield Electric & Water Systems 60 Parting Shot

See page 8

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FERC’s Order No. 2023 requirements involve accelerating interconnection studies to mitigate project backlogs that have reached historic levels.... https://tdworld.com/21281962

Linelife Podcast: Line Life Podcast: Puerto Rico Grid Transformation Featuring Dr. Shay Bahramirad

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NERC Compliance: The First Step Toward Modernization In The Utility Industry

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GLOBAL VIEWPOINT BY NIKKI CHANDLER, EXECUTIVE EDITOR

See You ‘IRL’

y first assignment as an editorial intern at Transmission & Distribution World magazine back in the ‘90s was to compile the IEEE PES Transmission and Distribution Conference and Exposition pre-show section. Back then people were just starting to look at websites for information, but were still relying mostly on print programs, guides and of course magazines for most of their information. I remember the host utility was Los Angeles Department of Water and Power, so I learned all about the fun things to do in Los Angeles, along with what the IEEE PES event was all about. I didn’t get to attend the show that year since I was a part-time intern but I still felt the excitement in preparing the huge section for the print issue, which then included the floor map, the full exhibitor list and of course some of the same features we have today, including highlights of the show, the schedule at a glance and the products and services that will be on display. Now in 2024, we encourage you to go to the IEEE PES website to find the most up to date exhibitor list and floor map. Not long after that first assignment, I started full time as an associate editor on a different publication that covered public safety communications and jumped right into attending all the big industry events. As a young, intrepid editor, I quickly learned about the industry at those shows by seeing products demos, talking with experts, meeting exhibitors and moderating and sitting in on educational sessions. I even worked on a few “show daily” newspapers, where we would gather interviews and news to have a newspaper printed on site for attendees. Now we can instantly add news to the web, so it’s much easier and quicker to get new information to our readers. I did eventually get back to T&D World as an online editor, but throughout my career, I have found the quickest and most efficient way to keep tabs on what is going on in our industry and to learn about the trends and technologies is to get out to industry conferences and exhibitions. Even through ups and downs of our economy, we still made it a priority to attend a few shows a year. Then the pandemic happened, and that stopped for at least a little while. To be safe, we stopped going 6

to our offices, and of course traveling to events where there were a lot of new people. We “pivoted” in 2020 to virtual events. We learned about video calls and webinars and podcasts. That worked for a while, but it was NOT a replacement for live events. Maybe some thought it could be. Don’t get me wrong; there is still a place for webinars and Zoom calls in on workdays. They are a quick way to interact with experts and focus your precious time in learning about specific topics you need. However, there is something to be said for jumping in on a session you wouldn’t normally attend or meeting someone from a different utility or company during the coffee break. And being able to touch and interact with several different exhibitors on a show floor when you wouldn’t be able to travel to different areas for demonstrations can’t be substituted online. Meeting new people (and catching up with old friends) is also beneficial to your mental and cognitive health. According to a University of Michigan study conducted before the pandemic, spending just 10 minutes talking to another person can help improve your memory and performance on tests. Meeting new people can also be a mood booster; even for introverts. I won’t say meeting a lot of new people isn’t tiring, but having a face-to-face conversation can improve your mood and help you to learn different perspectives. And in my experience, it’s much easier to get things done and make decisions with a group when we are sitting across the table from one another and can have a give-and-take conversation. You have probably seen the old video skits of conference calls where someone tries to talk and is muted, you can’t really pick up on social cues as well, two people talk at the same time, or at least half the people are multi-tasking. So, I would recommend, especially for younger professionals, for you to get out to an industry event. It can be a conference, an exhibition, or a competition (Lineman’s Rodeo). If travel isn’t feasible, look for events within driving distance. Several industry associations put on smaller regional events that may include poster sessions, small exhibit floors, or networking events. See if you can take a technical tour or visit a substation or manufacturer. CIGRE, IEEE PES, APPA, EEI, ASCE, UBBA; I could keep going on the number of great groups in our industry. And don’t forget our own event, the T&D World Live Conference and Exhibition in Atlanta in October! This event mirrors the content that we cover in our magazine and website, so if you are reading this, you would probably get something out of it. See you in real life!

T&D World | March 2024

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SHOW INSIGHTS FROM OUR ADVISORY BOARD BY NIKKI CHANDLER, EXECUTIVE EDITOR

Perspectives from our Advisory Board: Darren Tillman

he T&D World Live expert advisory board is instrumental in selecting the topics, presentations and speakers for our program. One of our members shares his varied experiences, concerns for the utility industry and thoughts about T&D World Live here. Darren Tillman is supervisor of AMI Field Operations at Baltimore Gas & Electric, an Exelon company. He helps provide governance and oversight of contractor management, field execution, and inspection strategy for residential electric and gas meter maintenance, smart meter/advanced meter infrastructure installation, and gas service abandonments. Tillman has about eight years of energy utility experience, starting in 2015 in Chicago at ComEd working in field and meter Services, new business, and distribution operations business support. Q: How did you get into the utility industry? A: In 2015, I had just turned 23 and had the opportunity to become a meter reader for ComEd. I read meter by foot up until the opportunity came for me to be part of the AMI electric deployment. I did not have a plan to always be part of the utilities industry. I originally had planned to go into project management or finance. Q: Is there anything from your past that really pointed you to where you are now in your career? A: The main things from my past that helped me to get to leadership now were being intentional and proactive with networking, learning where other job functions were in and outside of my department and learning different sides of the business. Direct field experience of both gas and electric metering, to engineering and design quality assurance, to contract and project management all have prepared me as I deal with most of these same things today. It also allows me to help others in and outside of my department when necessary. Q: What is one of the biggest obstacles you have faced in your life or career and how did you get past it? A: The biggest obstacle to date has been swift change in departmental structure. You get used to a certain way and comfortability of operating business, but when change came, collaboration, best practice sharing, and being adaptable was very beneficial. Change is constant in life overall, but how we handle change and actions we take is what we make it most times. Q: What do you enjoy most about your job now? A: I enjoy being able to lead and build up people. While I have direct experience in the past doing the work, now that I’m overseeing it, helping a new team learn it, instilling key values and best practices for productivity, safety, and customer 8

experience, but also building them up. Building up also means being able to show them where they were, where they are, and expose them to opportunities to grow and network. Q: What is one of the more exciting things that has happened to you in your career? A: One of the more exciting things that’s happened to me in my career was speaking being invited to join the T&D World Advisory Board. Often, many see or hear about senior management or executive leadership on boards, and that those are the main opinions and perspectives that matter, but it’s not. As a front-line leader currently, I’m grateful to be on a utility industry board where I can learn from engineers, project management professional, operations professionals, safety, analytical professionals — which some are a mixture of individual contributors up to executive leaders. This allows me to truly focus and obtain perspectives across the industry. Q: From your corner of the industry, what are the major problems do you see that need to be addressed? A: There are several major problems (or concerns) including not enough attention and energy spent on addressing workforce development. Our industry is changing rapidly with the way we operate, the customer demand for solar energy and electrification, new processes and protocols, innovation to name a few things. Many talk about it, but many don’t get involved as they should. Another is grid hardening. Q: Any ideas on what can help those problems? A: While this has been a focus of discussion the last couple of years, areas of concern are still there. More proactive surveying, obtaining big, clean data, and looking for opportunities for undergrounding high risk areas exposed to frequent power outages and safety hazards. Vegetation management is part of this as well. Also, installation of more electric distribution viper/ distribution automation switches when appropriate. Of course, we know that a lot of money and investments will be needed. Q: What did you enjoy about last year’s T&D World Live event? A: Last year, I enjoyed T&D World’s attention to the carbon footprint, which was especially relevant to the host utility (SMUD) and California regulations. I also appreciated how T&D World mplemented its first workforce development panel session to discuss best practices and trends while providing each other and the audience on ways to get involved and to grow. Q: What are you looking forward to this year at T&D World Live? A: More collaborative efforts and key learnings. The industry is continuing to evolve year over year, so whether it’s electrification efforts, transmission load, undergrounding efforts, or how workforce development efforts contribute to meet customer demands and provide opportunities, it’s good for the industry, and I’m looking forward to it.

T&D World | March 2024

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International Competitive Bidding National Electric Transmission System of Chile. Within the framework of the General Law of Coordinador Eléctrico Nacional of Chile, in accordance with the provisions of Expansion Works Decrees No. 4 of 2024 and No. 200 of 2022, both of the Ministry of Energy, and with the provisions of Article No. 157 of the Regulation on Transmission Systems and Transmission Planning approved by Supreme Decree No. 37 of 2019 of the Ministry of Energy, the National Electrical Coordinator will carry out the call for International Public Bidding for the Award of the Construction and Execution of the following Transmission System Expansion Works: VI Referential [MMUSD]

Project Increase in Capacity of the 2x220 kV Nueva Zaldívar – Likanantai Line

10.48

Expansion at S/E Loica 220 kV (IM)

2.34

Enabling second circuit Line 2x110 kV San Pedro - Quillota

2.03

Expansion at S/E Casas Viejas (NTR ATMT)

5.38

Project

VI Referential [MMUSD]

Expansion at S/E Polpaico (Enel Distribución)

2.22

Expansion at S/E Rungue

3.01

Expansion at S/E Picarte

2.38

Vitacura Tap Section Reinforcement – Vitacura

0.88

2x220 kV Punta de Cortés - Tuniche Line Expansion: Incorporation of line panels

6.72

Sectioning Circuit N°1 2x110 kV Line Agua Santa – Laguna Verde in S/E Los Placeres and Increase in Capacity 2x110 kV Line Tap Placeres - Los Placeres

4.24

Expansion in S/E Calama 110 kV

7.36

Expansion at S/E Hospital (NTR ATMT)

4.60

Expansion in S/E Calama 220 kV

5.92

Expansion in S/E Taltal (NTR ATMT)

5.42

Expansion in S/E San Juan 66 kV (BPS), replacement of transformers (RTR ATMT) and sectioning of the 2x66 kV Pan de Azúcar - Guayacán line in S/E San Juan 66 kV

7.52

Expansion in S/E Retiro 66 kV (BS), new transformer (NTR ATMT) and sectioning of the 1x66 kV Parral - Tap Longaví line in S/E Retiro 66 kV

5.22

New Transformer in S/E Punta de Cortés

4.62

Expansion at S/E Paillaco (NTR ATMT) and Sectioning of the 1X66 kV Llollelhue – Los Lagos Line

4.37

Expansion at S/E Dalcahue (NTR ATMT)

3.44

Expansion in S/E Punta de Cortés for interconnection of the 2x220 kV Punta de Cortés -Tuniche Line

1.97

New Transformer in S/E Punta de Cortés

8.06

Increase in Line Capacity 1x66 kV Tap Loma Colorada – Loma Colorada and Expansion in S/E Loma Colorada

1.76

Expansion at S/E Pumahue

1.26

Expansion at S/E Chinchorro

1.82

Expansion at S/E Gorbe

0.98

Expansion at S/E Villarrica (NTR ATMT)

3.90

Laying second circuit line 2x500 kV Ancoa -Charrúa

60.26

Expansion at S/E Los Poetas (NTR ATMT)

3.75

Expansion at S/E Algarrobal 220 kV (IM)

2.19

Expansion in S/E Squadron

2.28

Sectioning Line 2x220 kV Ancoa – Itahue in S/E Santa Isabel

Expansion at S/E El Rosal 220 kV (IM)

1.50

8.59

Expansion in S/E Purranque (NTR ATMT)

3.75

Expansion at S/E Río Blanco

0.27

Expansion at S/E Ancud (NTR ATMT)

4.18

Line 1x110 kV Bosquemar – Tap Reñaca – Reñaca

3.64

Expansion at S/E Kimal 220 kV (IM)

8.14

Expansion at S/E Candelaria

1.80

Expansion at S/E Recoleta (NTR ATMT)

4.86

Expansion at S/E Pozo Almonte

3.58

Expansion at S/E Tineo 220 kV (IM)

1.47

Expansion at S/E Tamarugal and increase in line capacity 1x66 kV Pozo Almonte – Tamarugal Sectioning line 1x110 kV Arica – Pozo Almonte in S/E Dolores

3.19 3.02

Expansion at S/E Monte Mina 220 kV (IM)

2.89

Expansion in S/E Parinas (NTR ATAT)

34.97

Expansion in S/E Parinas 500 kV (IM) and 220 kV (IM)

5.97

*The final list of works will be confirmed during the bidding process To participate in this process, interested parties can acquire the Bidding Terms corresponding to the Call, which will be available from the last week of March 2024, and request registration in the Registry of Participants, in the manner that will be indicated in the aforementioned Bases, through the website: https://www.coordinador.cl/desarrollo/documentos/licitaciones/ampliacion/2024-obras-ampliaciondecreto-n4/ . These Tender Rules will be available free of charge at the link to the Website. Legal persons, both Chilean and foreign, may acquire the Bases and register in the Registry of Participants, who may participate individually or as part of a consortium or association, complying with the demands and requirements established in the General Law of Electrical Services and in the Bidding Rules. Coordinador Eléctrico Nacional de Chile

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CHARGING AHEAD

NEW TECHNOLOGIES & NEW OPPORTUNITIES FOR UTILITIES

BY GENE WOLF, TECHNICAL WRITER

High-Tech Green Concrete

or the past few months we have been looking at artificial intelligence (AI) as it goes mainstream. This controversial technology has been attracting both positive and negative responses, but like most innovative technologies, there are too many benefits to ignore. Like it or not, AI is here to stay. Our challenge will be utilizing AI safely because it’s improving the power grid, but I have a feeling that isn’t going to be easy. Wouldn’t it be nice to get a break from all this abstractness and look at something that’s more tangible. How about something called “green concrete?” Concrete is an age-old technology whose history stretches back thousands of years. Some would argue that it hasn’t changed much in all that time, but is that true? In the modern world science is everywhere even when it comes to concrete. Surprisingly, hightech concrete is becoming another tool in our battle against greenhouse gases.

As a substation engineer, I’ve installed a lot concrete in my career. We referred to the freshly poured concrete as being green. It simply meant the concrete had to cure before moving on to the next phase of construction, but that’s not the case now. Green concrete has taken on a totally different connotation. In today’s terminology means the concrete is eco-friendly or it’s a low-carbon concrete, which is hard to get my head around. Studies estimate that approximately 8% of all the world’s greenhouse gas emissions are generated by concrete manufacturing. Concrete’s environmental problem starts with the cement used in the process of producing concrete. The cement is made by converting its primary ingredient, limestone, into calcium oxide. This is an energy-intensive process. In 2023, approximately 30 billion tons of concrete was used worldwide. The manufacturing of the cement for 30 billion tons of

concrete released about 4 billion tons of carbon dioxide (CO2) into the atmosphere, which is a significant figure.

It’s Not Easy Being Green What started me on this train of thought was a simple press release. Well, actually two releases that hit about the same time. They were about two companies who are addressing concrete’s bad environmental image. Each company had developed a unique approach to the CO2 problem that complement the other’s technology. One company is Heirloom, a California climate technology company, developed a process to remove CO2 directly from the atmosphere. Heirloom can store the CO2, but storage space can be limiting, and this issue really needs a permanent solution. That’s where the other company, CarbonCure Technologies, comes into the story. They have developed a process that takes atmospheric CO2 and injects it directly into concrete. According to CarbonCure the CO2 reacts with the calcium ions in the cement mix and forms calcium carbonate. This is an extremely hard substance that not only makes the concrete stronger, it effectively entraps the CO2 inside the concrete. A company spokesperson pointed out that the carbon remains trapped even when the concrete is demolished. These two companies signed a partnership agreement last year that extends through 2025. Heirloom’s captured CO2 will be stored in concrete utilizing CarbonCure’s mineralization technologies. It has gotten a lot of attention from the Department of Energy and investments from Amazon, Microsoft, and Blue Earth Capital. Carbon removal technologies and their removal credits are seen as opportunities by many industries, so I think this is going to be a trending technology area when it comes to the power delivery industry. In addition to these two approaches there are others that have been racking up successes over the years. They are focused on research and looking for small changes that produce big results. Brimstone, an Oakland based company announced their carbon-negative cement has raised over US$60 million for development. Their process uses carbonfree silicate rock instead of limestone. It has been tested by a third-party and has received certification that their cement is structurally and chemically the same as traditional cement. There’s a great deal of research and development taking place. Some of it seems to be a little whimsical while others make sense. Only time will tell if hempcrete, fiber-concrete, bamboo-concrete, coffee-concrete, to name a few will be successful or not. One thing is certain, concrete production is one of the world’s leading industrial polluters. It’s primarily due to the energy-intensive process used for producing cement. By adopting techniques that capture CO2 and entomb it in concrete or using processes that don’t produce CO2 we are reducing the power grid’s carbon footprint!

T&D World | March 2024

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CHARGING AHEAD

BY GENE WOLF, TECHNICAL WRITER

Dependable Power In An Undependable Environment The grid’s new normal is a moving target we haven’t reached yet.

he first quarter of 2024 saw some interesting weather patterns taking place around the world. It’s not news that global climate change is responsible for the extreme weather related havoc, but it’s the variety of weather that’s getting attention. We have experienced record breaking arctic cold bringing large blizzards followed by drenching downpours causing widespread flooding. Making things worse, these extreme weather events have been coming in rapid succession giving utilities and their contractors very little time to put things back together before the next anomaly hits.

setting new records for adding new capacity to the system. When Wood Mackenzie published their “2023 US Distributed Energy Resource Outlook” report, it provided an interesting window into what’s happening within the DER market. The report estimated that roughly 262 GWs of new DER and demand flexibility capacity will be installed from 2023 to 2027. To put that into perspective, the report said that approximately 272 GWs of utility-scale resources are expected during that same period – they’re almost equal. Statistics like those support the Department of Energy (DOE) recent claim that the grid’s edge is evolving faster than the bulk power system when it comes to integrating new technologies. The Inflation Reduction Act and the availability of easy financing have given DERs a boost. It also helps that rooftop solar and energy storage costs continue to drop. In addition, electric vehicles (EVs) are growing in acceptance and are becoming more affordable. Manufacturers have added to their attractiveness by advertising those EVs can be used for backup power during outages. The overall result is commercial, industrial, and residential customers embraced DER technologies beyond anyone’s expectations.

Bottom Up Approach

Are these unpredictable winter conditions the new normal that headlines have been proclaiming? Scientist are convinced we haven’t reached that new normal status yet because it’s still a moving target. Studies indicate that as long as greenhouse gasses are continually pumped into the atmosphere the climate will continue to change and the power grid must continue to adapt. How can the power delivery industry provide dependable electricity in undependable times?

Broader Thinking Required That is a complicated issue that many believe is centered around the electric grid’s infrastructure. Doing more of what the industry has always been doing doesn’t seem to work in this changing landscape. Many authorities are saying the technologies coming from the behind-the-meter like the distributed energy resources (DERs) technology are the best approach. The DER market has been rapidly expanding and

This bottom up approach has been generating interest with a wide variety of industry stakeholders. It checks a large combination of boxes for the decarbonization segment, the grid modernization groups, and those pushing decentralization to make the grid more resilient. Regulatory support has also made this more attractive Like FERC’s (Federal Energy Regulatory Commission) Order No. 2222. The Order requires regional grid operators to remove barriers for DERs to participate in wholesale markets, but there’s room to improve. Utilities and grid operators need to get areas within enterprise like system planning, operations forecasting, and marketing involved. DOE pointed out, FERC Order No. 2222 came along at an opportune time because of a wide variety of DER technologies being utilized behind-the-meter (BTM), which has helped virtual power plants (VPP) to participate in this new marketplace. Quickly, a VPP is a decentralized assortment of small-scale renewable energy sources and energy storage systems that operate as a single large-scale asset. Most of us think of a VPP taking the place of the traditional power plant by

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CHARGING AHEAD harnessing an aggregation of participant owned devices for supplying power, but that’s only part of the story. Late last year, DOE published a report titled “Pathways To Commercial Liftoff For VPPs” that paints an interesting picture of VPP technologies. It shows how they have been advancing to the point they are poised to change the grid’s landscape in a very positive way. It starts by saying, “VPPs are not new and have been operating with commercially available technology for years,” but what follows is thought provoking. It asserts, “Most of the 30-60 GWs of VPP capacity today is in demand response programs that are used when the bulk power supply is limited.”

Sum Greater Than the Parts Typically VPPs have been associated with DERs and demand response has been associated with DERMS (demand response management systems), but this a much more broad thinking approach. Taking the two separate technologies and integrating them together expands the technical potential of both. The result is a demand response VPP that can perform a wider array of functions than either individually, but there are issues doing this. The demand response portion consists of enormous numbers of intelligent appliances and the DER segment contains many complex elements. Bringing these two different applications together to operate as a single coordinated system is easier said than done. One major problem area is data, big-data.

These BTM elements generate real-time big-data that has to be managed in real-time. That’s where artificial intelligence (AI) enhancements are used. Keeping it simple, AI scourers the big-data and makes sense of it. The results use machine learning to develop predictive models with proscriptive algorithms enabling real-time monitoring, fast control response, and understanding what is taking place on the network. AI augmented control systems utilizing cloud-based computing, sophisticated analytics, and complex management platforms keep everything operating efficiently. A demand response VPP can provide valuable grid services with a minimum impact to the DER/smart appliance owners. Getting back to the DOE report, it explained, “A VPP made up of residential smart thermostats, smart water heaters, EV chargers, and BTM batteries, for example could provide a peaking capacity at 40 to 60% lower net cost to a utility than alternatives (a utility-scale battery and natural gas peaker).” This flexibility lets the VPP respond to grid conditions rapidly. Non-wire grid enhancements like demand response VPP provide many valuable characteristics that traditional approaches lack when it comes to making the power grid dependable. In a power grid beset by lengthy interconnection queues, BTM-VPPs are not subject to queue delays. If it’s determined that the BTM-VPP isn’t large enough, its size can be increased as fast as new participants can be added, but regulatory support is needed to move these programs forward.

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CHARGING AHEAD On the Grid In August of 2022, San Diego Gas and Electric (SDG&E) launched their VPP pilot program to boost energy reliability and build a resilient community. SDG&E said the program would run through December 2023. The VPP program utilizes advanced software to aggregate and coordinate the functions of a collection of small-scale, decentralized resources to meet grid needs. This program takes advantage of a wide range of smart devices and resources. During the 2023 August heatwave SDG&E said their VPP operated and supported the grid during critical peak demand periods. It performed as expected and SDG&E is considering expanding the program. As 2023 was closing, Puget Sound Energy (PES) announced they were expanding their VPP partnership with AutoGrid they launched in 2021. It’s expected to grow to 100 megawatts by 2025. It’s networking resources from multiple sites. PSE said that initially the VPP consisted of smart thermostats and heat pump water heaters, but the expansion will include battery storage, EVs, along with other devices and offer valuable grid services to the network. Last year the California Energy Commission CEC) approved a statewide VPP program. The program is part of the CEC’s Demand side Grid Support Program and is focused on tapping into the thousands of distributed solar-charged and standalone battery systems located on the customer’s side of the meter. It’s estimated there are currently over 100,000

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customer batteries available. The program is available to all homeowners with energy storage and several aggregators are enrolling participants with guaranteed yearly payments. Using demand response applications with DER technologies makes a great deal of sense in today’s power grid with an unpredictable environment. These hybrid VPPs offer a grid enhancing technology that can quickly be deployed. It has been suggested there are steps that would encourage VPP implementation. It would help to simplify BTM-VPP enrollment, integrate them into utility planning and incentives, incorporate them into wholesale markets, increase standardization in BTM-VPP operations, and expand DER support with rewards for consumer participation. According to Research and Markets, they expect a significant industry trend for VPP technology. With the increasing adoption of solar storage, and smart home technologies, they are projecting the global VPP market to surpass USS2.6 billion in 2024. Other research groups see this expansion of BTM-VPPs continuing and growing, but many point out demand response BTM-VPPs are not competing with the bulk transmission system. They are complementing each other. They are also blurring the transmission-distribution boundary. This symbiotic relationship is providing a more adaptable power supply in an unpredictable environment. It’s moving the industry closer to achieving a decentralized power grid. BTM-VPPs are catching on, and that’s exactly what the grid needs now!

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QUICK CLIPS

BY T&D WORLD STAFF

ADVANCED BATTERY ENERGY STORAGE SYSTEM COMES ONLINE IN HAWAII

Plus Power has begun operating its Kapolei Energy Storage facility on Oahu, Hawaii, an advanced grid-scale battery energy storage system, helping transition the state’s electric power from coal and oil to solar and wind. According to Brandon Keefe, Plus Power’s executive chairman, it’s the first time a battery has been used by a major utility to balance the grid: providing frequency response, synthetic inertia, and black start. The KES battery project, located on eight acres of industrial land on the southwest side of Oahu near Honolulu, uses 158 Tesla Megapack 2 XL lithium iron phosphate batteries, each roughly the size of a shipping container. It offers the grid 185 megawatts of total power capacity and 565 megawatt-hours of electricity, acting as an electrical “shock absorber” often served by combustion-powered peaker plants — responding in the blink of an eye (250 milliseconds), rather than the several minutes it takes combustion plants to come online. Customer-sited solar power has become so abundant that Hawaiian Electric must regularly ‘curtail’ or turn off large volumes of existing utility-scale solar and wind to keep the electric system in balance. Hawaiian Electric’s modeling found that in its first five years in operation, the KES battery plant will allow the utility to reduce curtailment of renewable energy by 69% and integrate 10% more new utility-scale renewables than previous models had allowed,

while providing for the continued rapid growth of individually-owned renewables such as rooftop solar. According to Hawaiian Electric, the project will save customers money. The Hawaiian Electric filing for KES estimated it will reduce electric bills by an average of $0.28 per month over a 20-year contract life. The battery plant’s specifications include: • 135 MW / 540 MWH of capacity and energy • 50 MW / 25 MWH of additional ‘fast frequency response’ to help keep the electric grid stable • “Virtual inertia’ to replicate the power-smoothing function of a spinning turbine • ‘Black start’ capabilities, which will support grid recovery in the event of a blackout The KES plant interconnects near three of Hawaiian Electric’s critical power generation facilities, enabling KES to support the reboot of those power plants in the event of an island-wide emergency, otherwise known as ‘black start’ capability. The KES batteries will help replace the grid capacity formerly provided by an AES coal power plant less than a mile away. That plant once produced up to one-fifth of the electricity on Oahu, home to nearly a million of Hawaii’s 1.5 million people and Army, Navy, Air Force, and Marine Corps bases that require reliable power. The coal plant closed in September 2022.

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NEXTERA COMPETITIVE TRANSMISSION WINS TEE UP $1.9B IN SPENDING NextEra Energy Inc.’s competitive transmission business will invest nearly $2 billion over the next four years in three regional transmission organization projects, a push that executives say embodies the “growing imperative” for new wires to go with renewable-energy assets. NextEra Energy Transmission, which is home to more than 200 people, last year won contracts to build transmission capacity in the Mid-Atlantic region from PJM Interconnection, in New Mexico from the Southwest Power Pool and in California from the California Independent System Operator. The Floridabased company will put to work a combined $1.9 billion in capital on those jobs between now and the end of 2027, President and CEO John Ketchum said last after NextEra reported its fourth-quarter earnings. For context, that’s about $500 million more than NextEra Energy Transmission’s transmission capex, two excluding acquisitions, from 2019 through 2022. The division has built a portfolio of competitive transmission assets in California, the Northeast, Texas, parts of the Great Plains and Canada. In all, the venture has invested about $5 billion and last year contributed $411 million in adjusted EBITDA to its parent. That figure was helped by a positive accounting adjustment related to a past acquisition and substantially outpaced the $275 million to $350 million Ketchum and his team had expected in late 2022. For this year, executives expect NextEra Energy Transmission to produce between $300 million and $375 million in adjusted EBITDA. The midpoint of that range would have the business account for about 4% of the adjusted EBITDA of all of NextEra Energy Resources, the renewables group of NextEra that is on pace to control a 63-gigawatt portfolio by the end of 2026. “The momentum is terrific,” Rebecca Kujawa, president and CEO of NextEra Energy Resources, said on the Jan. 25 conference call. “And as we’ve highlighted, everybody

understands—maybe not to the extent that we think it’s going to happen—[that], in order to unlock the renewables opportunity that we and others see across the United States, transmission needs to be built. And we stand ready to be a part of the solution wherever we can be.” The ”wherever” in that sentence looks likely to cover a lot more ground in coming years: A 2019 report from consulting firm The Brattle Group estimated that the economy’s electrification from 2031 to 2050 will require at least $7 billion of incremental transmission investment annually on top of the roughly $14 billion that was invested each year from 2006 to 2016. Should electrification trends outpace baseline estimates, the Brattle team said, incremental needs could balloon to $25 billion annually—the majority of it to serve new renewables capacity. Investments by incumbent utilities will account for a large part of that spending but competitive transmission ventures will get their share, too. Some incumbents, however, have argued that regulators’ efforts in the early 2010s to open up transmission investments haven’t produced the expected results. In a 2022 report prepared on behalf of a consortium that includes Eversource Energy, Exelon Corp. and Xcel Energy Inc., Concentric Energy Advisors said the 25 competitive transmission projects carried out in the decade prior—six of which were won by NextEra—didn’t bring many new players to the bidding table. On top of that, Concentric’s report said, a sample of competitively sourced projects “have not delivered innovation, cost savings, or timely development of transmission.” Among those taking the side of more competition is the Electricity Transmission Competition Coalition. The group last summer lauded the Southwest Power Pool’s choice of NextEra, which projected that its work will save New Mexico customers $84 million. This debate isn’t close to settled. —Geert de Lombaerde

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GE EYES APRIL SPIN-OFF FOR ENERGY BUSINESSES General Electric Co. executives are targeting an early-April spin-off of their power and renewable energy businesses, which they said Jan. 23 are set to produce “substantial” profit and cash flow growth in their first year on their own. GE’s energy group comprises more than 80,000 people globally and markets gas-powered turbines, on- and offshore wind energy equipment and services as well as various grid products and services for utilities and industrial companies. Speaking after GE reported its fourth-quarter results, GE Chairman and CEO Larry Culp and GE Vernova CEO Scott Strazik said those units are on track to bring in nearly $35 billion in sales this year, up from $32.7 billion in 2023, when they manufactured 2,225 wind turbines and 91 gas turbines. “I’m encouraged by what our team accomplished in 2023 as we delivered meaningfully better results,” CEO Scott Strazik said on a conference call, pointing to the winning of a large contract to help supply turbines to Pattern Energy’s massive SunZia project in the Southwest as a recent highlight. The creation of GE Vernova and its pending split will cap a process, announced in late 2021, to separate GE into three more focused businesses. Culp and his team in early 2023 spun out GE

HealthCare, which has annual sales of about $20 billion, before progressing on the Vernova separation that will leave legacy GE focused on the aerospace sector. Inside GE Vernova’s story are several contrasting energytransition plot lines: The power group is a growing cash cow and last year produced more than $1.4 billion in profits on nearly $18 billion in sales while the renewables division lost about $1.4 billion on revenues of $15 billion. The money-losing culprit in the latter is offshore wind, where Strazik and his team are whittling down their $6 billion backlog and—along with other sector players—catching their breath during a reset of expectations and investment plans. GE Vernova’s onshore division began turning a profit in mid-2023 and is on a path to “improve significantly” this year, Strazik said. That’s a major turnaround from mid2022, when that business with hit by a lull in orders ahead of the Inflation Reduction Act as well as warranty issues from manufactur• For more than a 100 years LAPP INSULATORS USA has ing glitches. Combining that progress with provided grid critical solutions that protect our energy infrastructure better pricing dynamics and other manufacturing efficiency improvements has Strazik • Porcelain bodies made of high-quality upbeat about the numbers Vernova can put raw materials, providing unparalleled

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up this year. “We see a clear pathway in ’24 to accrete margin,” he said. “But also then to continue to accrete our margin beyond as we liquidate the rest of the tough economics with offshore in ’25.” Strazik and his team will dive deeper into their goals and plans for GE Vernova at an investor day in early March. —Geert de Lombaerde

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MISO APPROVES TRANSMISSION EXPANSION PLAN WORTH $9 BILLION The Midcontinent Independent System Operator’s (MISO) Board of Directors has approved the 2023 MISO Transmission Expansion Plan (MTEP23). MTEP23 underscores MISO’s commitment to ensuring reliability for our footprint as the grid evolves. MTEP23 is the largest in MISO’s history both by volume and investment (excluding the two years of accounted Multi-Value Projects/Long Range Transmission Planning (LRTP) portfolios). The groundbreaking $9 billion in transmission enhancements will fund 572 projects addressing aging infrastructure, new load and added generation due to retiring traditional resources. These projects total over 700 miles of new or upgraded lines. “I am extremely proud of the commitment and quality of work my team members and others throughout the organization did to make MTEP23 possible. It took extensive stakeholder processes and significant modeling and analysis over the past year,” said Aubrey Johnson, MISO’s vice president of System Planning & Competitive Transmission. Unlike typical MTEP cycles in which

investment is spread across the region, $3.9 billion (or 43% of the total investment) is planned for projects in Louisiana and Texas. This is largely in response to an increase in generation retirements and load associated with economic development. The changing resource mix continues to add complexity to both MTEP and LRTP planning. In response, our planning tools and processes must also evolve to sustain their role as key initiatives of the Reliability Imperative’s Transmission Evolution pillar.

DOE ANNOUNCES $34 MILLION FOR 12 PROJECTS ACROSS 11 STATES TO STRENGTHEN AMERICA’S AGING POWER GRID The U.S. Department of Energy (DOE) has announced $34 million for 12 projects across 11 states to strengthen and modernize America’s aging power grid by developing cost-effective, high-speed, and safe undergrounding technologies, under the Grid Overhaul with Proactive, High-speed Undergrounding for Reliability, Resilience, and Security (GOPHURRS) program. The selected projects, managed by DOE’s Advanced Research Projects Agency-Energy (ARPA-E), will work on innovative solutions to help upgrade and expand the nation’s grid infrastructure by lowering costs, reducing inefficiencies, mitigating disruptions from extreme weather events and adopting renewable clean energy resources. The electric power distribution system in the U.S. includes 5.5 million line-miles with over 180 million power poles, which are not only prone to damage by weather and its effects but also account for a majority of power outages in the country each year. March 2024 | T&D World 19

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DOE’S GRID OVERHAUL PRIORITIZES SAFETY USING AI MAPS OF UNDERGROUND POWER LINES Exodigo recently announced that it will provide the accurate, complete subsurface maps needed to improve undergrounding processes for power lines as part of the Grid Overhaul with Proactive, High-speed Undergrounding for Reliability, Resilience, and Security (GOPHURRS) program led by the U.S. Department of Energy Advanced Research Projects Agency-Energy (ARPA-E). In partnership with the Pacific Northwest National Laboratory and Rutgers, Exodigo will work with participating utilities - including Avista Utilities, Portland General Electric, and WEC Energy Group - to support GOPHURRS’ mission to strengthen and modernize America’s aging power grid through the development of cost-effective, high-speed and safe undergrounding technologies. “Our team at PNNL sees great potential through this ARPA-E project to speed up undergrounding operations and support improvements to the reliability and resilience of the nation’s electrical grid,” said Frederick Day-Lewis, a chief geophysicist at PNNL. The project aims to revolutionize underground power distribution line installation. With the deployment of Exodigo’s artificial intelligence (AI) system, it will be possible to streamline the processing of geophysical survey data into digital twin and augmented reality, allowing for the identification of subsurface

obstacles prior to installation. Exodigo’s advanced AI system will autonomously process data from multiple geophysical sensors, delivering accurate, complete subsurface mapping and utility identification. Ultimately, the project should drive significant cost savings and increased efficiency in the process of undergrounding power lines. “We are deeply honored to receive this federal funding as it is a testament to our team’s relentless innovation and dedication. Underscoring Exodigo’s commitment to revolutionizing undergrounding technology for power grids, we look forward to improving the resilience and efficiency of our nation’s energy infrastructure in collaboration with Pacific Northwest National Laboratory,” said Jeremy Suard, CEO of Exodigo.

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ince the early 20th century, when electrical systems began to illuminate homes and streets, our reliance on electricity has surged. Fast forward to the digital age, and we find ourselves depending heavily on an aging infrastructure. Our electrical grid, now a backbone for critical systems including the internet and healthcare, cars, and monitoring devices, plays a crucial role in national security and everyday life.

the likelihood of widespread damage. But physical threats like fires and natural wear are only part of the picture. The rise in vandalism and targeted attacks on substations has highlighted the need for comprehensive security measures. Robust security walls that consider factors like line of sight and access points are essential in deterring unauthorized entry and protecting these critical nodes of our electrical system. The digital aspect of modern substations, with their intricate control systems, also demands attention. Modern substations, brimming with digital controls, require secure communication lines. These lines, often decades old and vulnerable to environmental and human impacts, are critical for substation control. A solution lies in heavy-duty, high-loadresistant trenches that protect these cables from damage, thereby ensuring the reliability of substation controls. TruFireWalls from Oldcastle Infrastructure are installed to safeguard transformers at a substation.

There are numerous reports on threats to the electrical grid infrastructure, including fires, aging components, and even attacks on substations. Focusing on safeguarding the reliability of this critical infrastructure is imperative, as is adopting preventative measures to ensure threats and damages can be contained. Among the most pressing concerns is the risk of fires in substations, particularly those involving transformers filled with flammable oil. In these scenarios, a highquality firewall is essential. While options range from non-fire-rated to four-hour fire ratings, the latter is advisable, particularly in rural areas with slower emergency response times. Firewalls with a longer fire rating mitigate the risk of ambient heat affecting adjacent transformers, reducing

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Installation of Plastibeton® trench in substation March 2024 | T&D World 21

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Attendees can browse the exhibits of more than 800 exhibiting companies on the show floor.

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IEEE PES T&D CONFERENCE & EXPO

Accelerating the Grid of the Future The 2024 IEEE PES Transmission & Distribution Conference and Exposition will focus on grid modernization and improving resiliency.

tilities — unlike nearly any other companies in the world — don’t compete with one another, swinging open the door of opportunity for knowledge sharing and collaboration. From May 6-9, 2024, in Anaheim, California, attendees from around the world can share experiences and learn from each other at the 2024 Institute of Electrical and Electronics Engineers (IEEE) Power Engineering Society (PES) Transmission & Distribution Conference and Exposition. “We have a tremendously powerful network we leverage,” said Joseph Svachula, SVP Transmission and Compliance at Exelon, and IEEE PES Transmission and Distribution Conference & Exposition director. “Many of the topics and panels will discuss real-world experiences of utilities.” California, the host of this year’s biennial conference, is at the leading edge of the clean energy transition, Svachula said. “It’s been 28 years since the IEEE PES T&D was held in California, so we are hoping to have over 13,000 attendees from more than 70 countries around the world.” Manuel Avendaño, senior engineering manager-transmission planning for Southern California Edison (SCE), the IEEE PES T&D 2024 Host Utility and the T&D local organizing committee co-chair, said power industry professionals should consider attending the event for three reasons. First, they can gain new technical knowledge from the exhibit floor and the panel sessions. Next, they can network with other technology professionals and industry experts around the world and finally, they can meet exhibitors from across the globe.

Learning About New Technologies At the event, attendees will have the opportunity to hear from the leaders within the industry during the Super Sessions, sit in on 45 panel sessions addressing the hottest industry topics like resiliency, artificial intelligence, climate change and grid modernization and sign up for half-day and full-day tutorials to earn continuing education units. The IEEE PES show follows the mission of the PES to be the leading provider of scientific and engineering information on electric power and energy for the betterment of society. To that end, all the March 2024 | T&D World 23

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IEEE PES T&D CONFERENCE & EXPO

The Anaheim Convention Center will be the venue for the 2024 IEEE PES Transmission and Distribution Conference and Exhibition.

technical content like panels and papers, are subject to the IEEE peer review process, which focuses on the technology and not the organization developing it, Svachula said. “The PES T&D Conference technical program has been established to give the utility engineers the information they need to do their jobs more efficiently and effectively,” said John McDaniel, principal engineer at National Grid and PES T&D technical program committee chair.

While attendees will be able to soak up knowledge during the technical sessions, they will also be able to learn about best practices and technologies through the technical tours sponsored by SCE and the city of Anaheim Public Utilities. Attendees can select between six off-site technical tours, said Ana Hafiz, engineering manager substation standards at SCE and technical tours chair. The locations include the Anaheim GIS Indoor Underground Substation; the SCE Mesa Air Insu-lated Substation; the Port of Long Beach; the Irwindale Energy Edu-cation Center and Emergency Opera-tions Center; the Reliability Utility Owned Energy System at the Hinson Substation; and the Center Peaker to see the world’s first low-emission hybrid battery storage, gas turbine peaker system. For these tours, space is limited, and separate registration is required.

Discovering Innovation

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Attendees for the event, slated for May 6-9, 2024, in Anaheim, will not only be able to earn CEU and professional development hours by attending the technical program, but they will also be able to explore the latest innovative technologies and services on the exhibit hall floor.

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IEEE PES T&D CONFERENCE & EXPO

SCHEDULE AT A GLANCE Sunday, May 5 12:00 p.m. – 5:00 p.m.

Onsite T&D Registration Opens

Monday, May 6 7:00 a.m. – 5:00 p.m.

Registration Open

8:00 a.m. – 5:00 p.m.

Tutorials, Plain Talk

9:00 a.m. – 2:30 p.m.

Technical Tours

6:00 p.m. – 9:00 p.m.

Conference Opening Reception

Tuesday, May 7 7:00 a.m. – 5:00 p.m.

Registration Open

8:00 a.m. – 5:00 p.m.

IEEE PES Plain Talk

8:00 a.m. – 9:00 a.m.

Opening Session

9:00 a.m. – 9:45 p.m.

Super Session 01: Mind the Gap - Policy and Regulation for Accelerating the Grid of Tomorrow

10:00 a.m. – 5:00 p.m.

Exhibits Open / Innovation Stage, Renewable Energy Stage, and Grid Edge Stage

12:00 a.m. – 1:00 p.m.

Conference Luncheon in the exhibit hall

1:00 p.m. – 5:00 p.m.

Technical Panel Sessions

Wednesday, May 8 8:00 a.m. – 5:00 p.m.

IEEE PES Plain Talk

8:00 a.m. – 9:00 a.m

Super Session 02: Transmission Buildout – The Solutions We Have and the Breakthroughs We Need

9:00 a.m. – 10:00 p.m.

Super Session 03: Meeting the Energy Needs of Tomorrow – Integrated Planning for the Customers, Distributed Energy Resources, and the Grid

9:00 a.m. – 4:00 p.m.

Technical Tours

10:00 a.m. – 6:00 a.m.

Exhibits Open / Innovation Stages, Renewable Energy Stage, and Grid Edge Stage

12:00 p.m. – 1:00 p.m.

Conference Luncheon in the Exhibit Hall

1:00 p.m. – 5:00 p.m.

Technical Panel Sessions

4:30 p.m. – 6:00 p.m.

Networking Reception in the Exhibit Hall

5:00 p.m. – 7:00 p.m.

Poster Session and Reception / Student Poster Contest

Thursday, May 9 7:00 a.m. – 2:00 p.m.

Registration Open

8:00 a.m. – 9:00 a.m.

Super Session 04: Powering Progress: Overcoming Obstacles towards the Energy Transition

9:00 a.m. – 10:00 a.m.

Super Session 05: Spark of Innovation: Exploring Decarbonization from Electrification

10:00 a.m. – 1:00 p.m.

Exhibits Open / Innovation Stages, Renewable Energy Stage, and Grid Edge Stage

12:00 p.m. – 1:00 p.m.

Conference Luncheon in the Exhibit Hall

1:00 p.m. – 3:00

Technical Panel Sessions

3:00 p.m. – 4:00 p.m.

Super Session 06: Climate Change Impacts on the Grid of Tomorrow

4:00 p.m. – 5:00 p.m.

Conference Closing Session – Student Poster Contest Recipients

At the event, attendees will have the opportunity to hear from the leaders within the industry during the Super Sessions.

“The 2024 IEEE PES T&D show floor is officially the largest ever,” Svachula said. “As a result, with over 200 new exhibitors, we will have the widest display of next-gen technologies with more exhibitors than any other industry event in the U.S.” Attendees can browse the exhibits of more than 800 exhibiting companies on the show floor. “These exhibitors will take over 260,000 sq ft of exhibit space focusing on all aspects of transmission and distribution products and services ranging from the cutting-edge technologies in the Grid Edge Technology Pavilion and covering 80-plus product categories,” Svachula said. The exhibit floor is never the same from one show to the next, he added. “The industry is on the precipice of transformative change in how the needs of customers and communities are met. The 800-plus exhibitors will be demonstrating new technology and products that are making tomorrow’s grid today’s reality.” At the 2022 conference, the Smart Cities Stage was one of the most popular locations, McDaniel said. “We expanded that to three different opportunities for 2024 including Grid Edge Technologies, Renewable Resources and Innovation Stages.” Because the IEEE PES T&D Conference & Exposition has been a successful event, the organizing committee doesn’t want to change what worked. At the same time, they want to increase value for those who are attending. “We added lunch to the exhibit hall and expanded the exhibit floor stages, which gives the attendees more of an opportunity to interact with exhibitors and each other,” Svachula said.

Connecting and Collaborating Whether they just started out in the power industry or have years of experience, attendees can network and make connections during the event’s social events. “The social networking activities at PES T&D are always memorable,” said Editha Toms, customer service advisor at SCE and activities chair for the PES local organizing committee. “The opening reception will be held at the Disneyland Hotel so attendees can have the opportunity to experience the magic of Disney while in Anaheim.” March 2024 | T&D World 25

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IEEE PES T&D CONFERENCE & EXPO “We have been working hard to establish a program that is focused on the needs of collegiate and young professionals in the power and energy industry,” said Gianela Gozalo, senior compliance engineer at SCE and student activities char for the PES local organizing committee. To encourage utilities to send as many employees as possible to the event, IEEE PES is once again offering the T&D Utility Saver Package. The package will allow companies to send 10 utility employees with full conference registration for $1,000 or five utility employees for $750. The 2024 IEEE PES T&D Conference and Exposition in Anaheim, California, is essential to unlocking the power of the The ABB Formula E race car visits each IEEE PES Transmission and Distribution Expo. industry, Svachula said. “You can expect In addition, the organizers will continue the tradition of hav- to connect with leading experts during countless networking ing a networking reception on the exhibit floor on Wednesday, opportunities, explore groundbreaking products, technologies May 8, and for the first time, lunch will be made available to at- and services across what is shaping up to be our largest exhibit tendees in the exhibit hall on Tuesday, Wednesday and Thursday. floor ever, and experience unmatched technical education.” The PES T&D Local Organizing Committee has also launched a program for its up-and-coming attendees including Editor’s Note: For the updated exhibitor list and floor plan and networking events, resume building, information on LinkedIn to register online visit https://ieeet-d.org/attendee/why-attend-td/ and interviewing tips, a poster session and reception. pricing-info/.

Join us at

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Calculating Rating Information

transmission and distribution, renewable and distributed energy markets. Through its history, it said to have designed and installed more of the world’s electric power capacity than any other company. Today, the company is helping to deliver the grid of the future, bring new technologies online, extend the life and efficiency of existing plants, implement renewable energy programs and deliver a new era of clean, reliable, and efficient energy to enable a smarter, more sustainable world. The company’s team of engineers, builders, planners, and strategic thinkers, along with clients and partners, are designing and building critical infrastructure to improve life across the globe. United Engineers & Constructors is a certified Service-Disabled Veteran Owned Business (SDVOB).

United Engineers & Constructors www.ueci.com Booth #5413

Porcelain Insulators IPS AFRM, Advanced Facility Ratings Management allows users to calculate rating information for all series equipment. Designed to meet the requirements of order FERC-881, IPS AFRM supports integration with live weather data for accurate ambient adjusted ratings and enables support for dynamic line ratings by allowing additional weather data such as wind speed, direction, and solar irradiance. IPS AFRM can accept rating information from any system, internal or external. Aggregates ratings for facilities are based on the network connectivity model (CIM data). It calculates any desired rating type, such as ambient adjusted, seasonal ratings, emergency ratings and more if needed. It also manages and stores all relevant rating data based on internal and regulatory requirements. The product Integrates the data to operational IS (like SCADA/EMS) and business systems such as regulatory reporting. It provides a central data hub for rating information inside the utility.

IPS-Energy USA www.ips-energy.com Booth #5469

Distribution and Control Equipment Powell Industries, Inc. has been designing, manufacturing and packaging equipment and systems for the distribution and control of electrical energy for more than seven decades. Headquartered in Houston, Texas, Powell is a customer-focused, technologydriven, and solutions-oriented company offering single point sourcing to customers, no matter how diverse the project. Product offerings include ANSI MV and LV switchgear, motor control, IEC MV and LV controlgear, DC switchgear and rectifiers, Iso-Phase, non-segregated phase and cable bus systems, power control rooms, E-Houses, offshore modules, digital solutions and power automation services, product life extensions, maintenance and support. Market segments served include data centers, utilities, renewables, pulp and paper, petrochemical plants, commuter railways, LNG facilities, mining and oil and gas.

Powell Industries Inc. www.powellind.com Booth #5870

Engineering, Procurement and Construction United Engineers & Constructors is an infrastructure engineering, procurement, construction and consulting company. Since 1905, it has served the power industry by providing comprehensive lifecycle services for the conventional generation, nuclear,

PPC porcelain long-rod insulators are used in transmission and distribution lines. The strength of the porcelain and modern design make them a safe and reliable solution for demanding environments. Compared to other types of insulators, they are suitable for a safe and stable power supply without power failure with low operating costs. Under polluted conditions, insulators can be subjected to extreme electrical field stress causing tracking and erosion. Porcelain insulators will only show minor surface marks but maintain 100% mechanical strength. Porcelain Long Rod insulators are not affected by UV, wind, rain, ice and temperature changes. They will provide reliable service for the life of the conductors and towers. Porcelain longrod insulators have high dielectric strength. Aluminum oxide ensures the low porosity of porcelain. This ensures the porcelain is impervious to moisture and will not lose its mechanical properties due to freezing. All components of porcelain insulators are fully recyclable in the manufacturing process and throughout their life cycle. Compared to other insulation materials, they leave a significantly lower carbon footprint. Once properly installed, the porcelain longrod insulators retain reliability for decades.

PPC Insulators, Inc. www.ppcinsulators.com Booth #6313 March 2024 | T&D World

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IEEE PES T&D PRODUCTS & SERVICES Camera Systems Kappa Optronics is a trusted partner for IEEE C.37.20.9-compliant switchgear camera systems (SGC), and its Switchgear Viewport Camera Systems allow users to confirm live switch positions to advance safety. The company’s specialization in onsite installation and support involves close collaboration with major clients in the power grid and power technology sectors, ensuring the delivery of mature solutions tailored to specific requirements. The switchgear viewing systems are based on specialized cameras for live monitoring. This allows operators to observe switches from a safe distance, either locally through a portable video unit or remotely from a centralized control room. The company provides a range of extremely robust switchgear cameras designed for safe, live monitoring of GIS, hybrid switchgear, GCB, and air-insulated applications in mediumand high-voltage networks. These cameras can be adapted to any type of viewport or equipment, meeting specific customer requirements. The switchgear viewing systems are designed to withstand electromagnetic interference (EMI) and seismic conditions, ensuring reliability even in the harshest environments. The company also offers a solution for on-the-go switchgear monitoring. The battery-powered portable video unit PVU is a suitable choice for service technicians, ensuring quick and efficient mobile viewport monitoring.

Kappa optronics GmbH www.kappa-optronics.com Booth #6214

Eco-Efficient Breaker In recent years, the need to reduce greenhouse gas (GHG) emissions from power grids, at both the transmission and distribution level, has emerged as a major priority for utilities. Now, more than ever, the world needs eco-efficient power grids, and a key focus of such efforts is the elimination of sulfur hexafluoride (SF6) gas. While SF6 has been the preferred choice for circuit-breakers and gas-insulated switchgear (GIS) in highvoltage substations for decades due to its insulating properties, it is also a potent

GHG. Given its global warming potential ~25,000 times higher than carbon dioxide (CO2), eliminating the use of SF6 is a point of urgency. At IEEE PES T&D, Hitachi Energy will be showcasing the first eco-efficient EconiQ 420 kV Dead Tank Breaker (DTB) developed for use at the extra-high voltage level. It combines a low carbon footprint, reliability, and low life cycle costs. This product offers easy operation at high-performance ratings, based on well-established gas circuit-breaker technology, used for decades in transmission systems worldwide. The eco-efficient DTB uses a gas mixture of fluoronitrile (C2-FN), Carbon dioxide (CO2) and Oxygen (O2). The gas mixture essentially eliminates the CO2equivalent emissions of the insulating medium.

Hitachi Energy www.hitachienergy.com Booth #4423

Robotic System for Bird Diverter Installation PLP and FulcrumAir have partnered to launch an automated robotic system for installing helically-shaped bird diverters on overhead power lines. The Mini LineFly is anunmanned system that automatically and precisely installs PLP’s BIRD-FLIGHT Diverters on overhead lines, helping to significantly reduce safety concerns for lineworkers while also increasing project efficiency. The Mini LineFly accurately places PLP BIRD-FLIGHT Diverters at predetermined intervals, maximizing the performance to help safeguard wildlife from accidental contact with power lines. This critical wildlife protection device reduces the probability of unintended bird collisions by enhancing line visibility, helping to protect diverse avian species and mitigate potential costly and problematic power outages. The first implementation of robotically installed PLP BIRD-FLIGHT Diverters took place during the recent High Banks Wind Project in Kansas. Nearly 15,000 bird diverters were installed using robotics along the 75-mile 345 kV transmission line spanning Marshall, Republic, and Washington counties. The High Banks Wind Project delivers about 600 MW of dependable renewable energy to customers in the American Midwest.

PLP Plp.com Booth #3220

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IEEE PES T&D PRODUCTS & SERVICES Elevated Foundations

MAGNUM Utility Grillage (MUG) systems are manufactured in the USA according to the company’s ISO 9001 approved Quality Program. Structural capacities are developed according to AISC 360 and NESC provision. The MUG is configured to fit any pole and ground line moment and can be secured using helical piles, driven piles, drilled shaft or micropiles. A client’s MUG system will be designed by the company’s full-time staff of engineers to coordinate with a pole, pile type and site soils to ensure a highquality foundation for your project. MUG foundation systems are available in many styles, sizes and capacities to fit the needs of your project. They are protected from the elements by hot-dipgalvanized, epoxy coating or a dual coat system.

Magnum Piering www.magnumpiering.com Booth #2823

Reactive Sealant MODULAR Elevated Foundations arrive ready for immediate installation. Precast modular platforms are constructed with a focus on durability and resilience. They are available on-grade or elevated and can help to secure infrastructure from floods. The product is suitable for transformers, control buildings, electrical substations, metering stations, data centers, energy storage, pipeline monitoring stations, cooling towers, equipment shelters and more. The company’s patented Kenner Chain Wall system suits both seismic and non-seismic applications, providing a sturdy on-grade or elevated foundation for your structures. The design ensures quick installation, eliminating potential weather delays, field quality control issues and extra costs associated with alternatives like cast-in-place or galvanized steel platforms. Deployed nationwide across various industries, including energy, fiber, telecom, oil and natural gas, transportation and emergency services, Kenner collaborates with certified precast concrete plants for seamless manufacturing and delivery.

This product is a polyurethane two-component reactive sealant consisting of resin (A component) and curing agent (B component). After thoroughly mixing the sealant (tan curing agent and resin) during use, inject it from the injection port into the housing cavity and wait for it to fully cure. The product does not contain solvents. It has the characteristics of minimal shrinkage, good permeation resistance, high volume resistivity and good insulation after curing. The product is constructed under room temperature and operated conveniently. It effectively combines waterproof property and insulation, and has become a special material for sealing, fireproofing and flame retardant of underground high-voltage cable joints.

Ningbo Tonylum New Material Technology Co., Ltd. www.tonyhoo.com Booth #5497

Savings Calculators

Kenner Innovative Design Systems LLC www.kennerchainwall.com Booth #3403

Foundation Systems

Designed by Southwire’s CableTechSupport Services team of engineers, the company’s suite of calculators can help users to improve cost savings without compromising safety. Two of the featured calculators include the Concentric Neutral Calculator

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IEEE PES T&D PRODUCTS & SERVICES and the CIC Labor Savings Calculator. The Concentric Neutral Calculator can be used to design made-in-America MV products to accelerate grid modernization, renewables and bipartisan infrastructure projects while reducing neutrals. The CIC Labor Savings Calculator can calculate potential labor savings that can be realized when using preinstalled CIC for your next UD installation. With multiple construction options and man-hour rate estimates, this calculator provides quick and accurate savings estimates.

Southwire www.southwire.com Booth #5515

Energy Storage Stark Tech will be exhibiting its Microgrid on a Skid and Battery Energy Storage Systems at the 2024 IEEE PES show. Its microgrid on a skid applications are customizable to support specific use cases and power up to 1500 kWh / 750 kVA. Its Lithium-ion Phosphate (LFP) chemistry is used in both Stark Tech’s Battery Energy Storage products and Microgrid products.

Stark Tech https://starktech.com/energy-solutions/solutions/ battery-energy-storage/ Booth #405

Electrical/Mechanical Shunts The most common causes of overhead conductor failures and outages are the degradation of splices and connectors due to corrosion, fatigue, thermal cycling or improper installation. Dynamic line ratings and methodology will allow utilities to increase ampacity on lines when the conditions of wind, ambient

National Engineering Firm Local Expertise Transmission Distribution Substation Survey Environmental Telecommunications

temperature, and nighttime radiation keep the conductors at a lower temperature to maintain sag. However, these conditions have virtually no effect on the electrical interface deep within the connector. Studies indicate the simple fact that an increase in conductor temperature will lead to accelerated aging and connector degradation at the electrical interface. Neglecting to address the connectors in the process will lead to catastrophic failures, line-down incidents, and unplanned outages. By implementing measures such as the installation of ClampStar Engineered, Electrical/mechanical Shunts, which can enhance the capacity and reliability of transmission lines, utilities can mitigate the risks associated with aging infrastructure and increasing power demand. The evaluation process for transmission lines should include a thorough assessment of overhead conductor connectors, considering their impact on system efficiency, safety, and capacity to ensure the reliable operation of the electric grid and minimize the risks of connector failures and subsequent disruptions. Therefore, with proper measures in place, Dynamic Line Rating technology can provide a positive outcome.

Classic Connectors classicconnectors.com Booth #4140

Electric Puller/Tensioner The new PES500 electric puller/tensioner offers 5000 lbs (2350 kg) max pull for overhead and underground operations. The reel of rope can easily be removed and replaced with a reel of conductor for tensioning operations. During the tensioning operation, the system is designed to use the pulling force to charge the battery. Condux Tesmec will also display the industry’s first allelectric underground puller at the show, the PE1250. The PE1250 all electric puller provides a maximum pull force of 11,240 lbf (50 kN) and an advanced user interface and remote control. Both units are said to be very quiet and eliminate emissions. The PES500 and PE1250 are equipped with lithium batteries and can be charged any standard EV charging station.

Condux Tesmec www.conduxtesmec.com Booth #4485

Pole-Mounted Transformer

westwoodps.com

Our pole-mounted dry-type CAREPOLE turns power distribution systems into safer, more environmentally friendly grids. Optimally protected by its cast-resin enclosure against normal and harsh environmental conditions, this maintenance-free transformer enables reliable operation while reducing total costs of ownership. SIEAERO, the company’s digital service for aerial power line inspection, provides comprehensive overhead line documentation and fault detection. Flights are performed with helicopters

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IEEE PES T&D PRODUCTS & SERVICES Polyethylene Insulators

carrying the SIEAERO high-end multi-sensor system, which was developed to meet the complex requirements of overhead line inspections. Since all necessary sensors and cameras are combined in one multi-sensor system, all relevant inspection data is recorded at once. This SF6 free product line uses vacuum switching technology and clean air insulation to produce zero harmful emissions without having to compromise on performance or economic feasibility. The company’s Blue products include gas insulated switchgear, dead tank circuit breakers, live tank circuit breakers, voltage transformers and gas insulated busducts. In addition, the company will be promoting its FACTS, HVDC, battery storage, arresters, voltage regulators, transformer, and digital grid products, solutions and services.

Siemens Energy www.siemens-energy.com Booth #4401

At the IEEE PES T&D show, Marmon Utility will be showcasing its Hendrix high-density polyethylene insulators, including vise tops and newly added trunnion and station line posts. These insulators are durable and backed by a lifetime guarantee. Polymer vise top insulators differ from their porcelain counterparts in that they won’t chip, crack or break, are up to 30% to 40% lighter, and eliminate the need for ties. They also increase installation efficiency with their clamping mechanism and shear bolts. Marmon will have samples available for attendees to experience the streamlined installation process first-hand. The company will also feature its ROW-maximizing 15 kV-115 kV compact Aerial Spacer Cable, 5 kV46 kV MV underground cable with free-strip insulation, and (5 kV138 kV) HV underground cable with discharge resistant insulation, permashield and a high-frequency attenuation. Marmon Utility is the parent company of Hendrix and Kerite, and their products are made in the United States.

Marmon Utility https://marmonutiliity.com Booth #5007

CBP-37-43-15A-MP-MG-22x24 Transformer/Meter Pedestal from Nordic

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Nordic’s Transformer Box Pad & Meter Pedestal installs anywhere you want it to be.

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Light weight, yet built strong and durable for single phase transformers ranging from 25kVA up to 167kVA.

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Install up to 3 meters on the meter plastic pedestal.

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Meter pedestal’s interior accommodates Factory installed three 6 port 350600MCM connectors.

ORDIC FIBERGLASS, INC. “Quality Products for the Electric Utility Industry” P.O. Box 27 Warren, MN 56762 Tel: 218-745-5095 Fax: 218-745-4990 www.nordicfiberglass.com

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DISTRIBUTED ENERGY RESOURCES

Construction crews install an integrated system of solar, battery storage and generation. Photo by BoxPower.

PG&E’s Remote Grid Delivers Safety, Savings PG&E deploys its first of many stand-alone remote grids, integrating solar, battery storage and generation. By ANDREW MULHERKAR, Pacific Gas & Electric Co., and NOA SCHACHTEL, BoxPower

ccording to the National Oceanic and Atmospheric Administration, the frequency of billion-dollar disasters due to climate change has increased by more than five times since the 1980s. Combined with the fact that 60% of U.S. distribution lines are surpassing their 50-year life expectancy, this means grid reliability is at greater risk than ever. Uprooted trees, tree limbs and other debris strewn about by powerful winds, mudslides and flooding resulting from winter storms and hurricanes can knock down poles and power lines, causing long-duration outages that affect vulnerable and rural citizens the most. Climate change requires utilities to take a proactive, vigilant posture in predicting and preventing damaging wildfires to their equipment. The frequency and severity of extreme weather events and natural disasters are increasing. Additionally, large areas across the West Coast of the U.S. are experiencing dry climates,

drought conditions and strong winds. In California alone, 75,000 miles (120,701 km) of overhead lines exist in high fire-threat districts (HFTD). Energy providers have achieved considerable progress in reducing risks within their service areas; however, wildfires ignited by power lines remain a major challenge. To meet this challenge head on, utilities are spending billions of dollars on distribution grid-hardening initiatives. According to the U.S. Energy Information Administration, distribution spending has increased over 64% since 2000, which is a difference of roughly US$22 billion. Utilities are using a variety of risk-mitigation strategies to tackle this issue, including vegetation management, conductor covering, undergrounding, data analytics, artificial intelligence, machine learning and remote-sensing technology. However, the relative expense of most conventional risk-mitigation wires solutions vs. distributed energy solutions in remote areas has created a new opportunity.

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DISTRIBUTED ENERGY RESOURCES

Instead of rebuilding distribution lines destroyed by 2019 Briceburg fire, PG&E opted for a localized, stand-alone power system. The Briceburg remote grid includes array of 97 solar panels. Photo by BoxPower.

Briceburg Fire Of 2019 Situated amid the rugged landscapes of Briceburg, California, residents have long contended with the risks associated with natural disasters, which routinely challenge the resilience of local infrastructure. Since June 2021, Briceburg has witnessed a paradigm shift in energy reliability, marked by the advent of a groundbreaking solution that has consistently demonstrated resilience against the forces of nature, at a cost lower than traditional grid infrastructure. In 2019, the Briceburg Fire decimated the power lines that served Briceburg, prompting a critical reassessment of infrastructure solutions. The historical line route was challenging to rebuild through the last 1.4 miles (2.3 km) of rugged, HFTD terrain. Additionally, conventional alternatives, such as hardened

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overhead lines and underground lines, were not only costly but also posed feasibility challenges given the location. This predicament led to collaborative work between Pacific Gas & Electric Co. (PG&E) and BoxPower, whose software and hardware solutions focus on optimizing the performance and accelerating the deployment of solar-plus-storage microgrids. Their collaboration culminated in the implementation of a remote grid system that operates stand-alone from the centralized grid and permanently replaces existing distribution lines. This system was designed and engineered to withstand the diverse array of environmental challenges, thereby ensuring year-round reliable power supply to the residents of Briceburg. The objective transcended mere power supply continuity; it aimed at fortifying grid resilience and aligning with California SB100’s mandate

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DISTRIBUTED ENERGY RESOURCES a crucial component in this high fire-risk area. Both PG&E and BoxPower can remotely monitor and control the system by satellite, ensuring performance monitoring, reporting and automated propane delivery capabilities.

Resilience And Reliability

Battery energy storage system and backup propane generator. Photo by BoxPower.

to reduce greenhouse gas emissions, targeting 100% renewable electricity by 2045.

Solar Plus Storage For this project, BoxPower developed a dual solar array — one ground-mounted array and one container-mounted array — with a nominal photovoltaic power of 36.5 kW and a 69.12-kWh lithium-iron-phosphate battery bank. The system can deliver up to 27.2 kW of continuous power output with a surge capacity of up to 48 kW. Additionally, it incorporates two integrated 35-kVA propane prime power generators as a backup and features a fire-suppression system,

Since its commissioning in June 2021, the Briceburg remote grid has been a testament to resilience and steadfast reliability, maintaining 99.9999% power reliability through September 2023, with only 16 seconds of total downtime for the five customers it serves. The stand-alone power system has generated 94% of its power from renewable sources, with the solar and battery components being the primary sources and only 6% emanating from the integrated dual propane generators mostly during winter. PG&E and BoxPower’s design consideration to integrate backup generators was pivotal, ensuring redundancy and guaranteeing uninterrupted off-grid power 24/7/365, a feature particularly crucial during the winter months when solar generation is inherently reduced due to shorter days and cloudier weather. The Briceburg system’s operation during extreme weather events exemplifies its unmatched resilience. It remained operational without issues during a historic winter storm in December 2021 and weathered an August 2021 heatwave seamlessly. Moreover, during the 2021 Oak Fire, with a wildfire raging just a few miles away and PG&E proactively shutting down power to the entire area, the Briceburg stand-alone power system stood as an exception, continuously and safely powering PG&E customers, including two residences, a visitor center,

Remote grids are expected to provide better levels of electric reliability, significantly reducing service interruptions caused by weather and public safety power shutoff events. Photo by BoxPower.

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DISTRIBUTED ENERGY RESOURCES and telecommunications and transportation facilities. This resilience was again demonstrated in January 2023, when the Briceburg system remained unyielding during the atmospheric river storms in California, underlining the system’s capacity to ensure power supply under diverse and challenging conditions. Financially, the remote grid solution has provided PG&E substantial savings compared to the alternative of reconstructing the previously destroyed distribution lines. The estimated cost of distribution line rebuilds and system hardening efforts can reach millions of dollars per mile. Remote grids are intended to meet customer needs at lower lifetime costs and a significantly lower risk of fire than conventional solutions in targeted rural locations.

grid modernization and utility evolution in roles at Bidgely, Southern Co. and Greentech Media. Mulherkar holds an MBA degree from Yale University and bachelor’s degrees from Tufts University and New England Conservatory. NOA SCHACHTEL (noa@boxpower.io) is marketing coordinator at Grass Valley, California-based BoxPower, which designs, deploys and scales stand-alone plug-and-play solar-plus-storage microgrid power systems. Schachtel focuses on marketing strategy, research and asset enablement. He gained his experience working for multiple startups, including EVmatch and Sourcefit. Originally from Honolulu, Hawaii, Schachtel graduated with a degree in philosophy and ethics from Claremont McKenna College, in Claremont, California, where he also served as a fellow at the Center for Innovation and Entrepreneurship and as an analyst at the Roberts Environmental Center.

More Remote Grids PG&E’s collaboration with BoxPower and other microgrid vendors heralds a transformative era in energy infrastructure, with the successful Briceburg initiative serving as a stepping stone. As of November 2023, PG&E has four additional stand-alone power systems in operation, for a total of five operational systems. It plans to deploy up to 30 systems through 2026. PG&E has identified hundreds of potential locations for remote grids across its California service area, highlighting the adaptability of this innovative solution across various environments. The utility is engaging with customers who reside in high fire-threat areas to provide a clean and wireless alternative to traditional grid power. These remote grids are expected to provide better levels of electric reliability, significantly reducing service interruptions caused by weather and public safety power shutoff events. The community will also benefit from reduced greenhouse gas emissions since the solar-with-propane backup system provides up to an estimated 89% renewable energy. PG&E is committed to redefining traditional grid infrastructure and mitigating wildfire risks through the removal of overhead power lines, while simultaneously enhancing service reliability. The strategic development of remote grids signals a promising future in addressing utility-related challenges and advancing renewable energy solutions. ANDREW MULHERKAR is a product manager on the remote grid team at Pacific Gas & Electric Co. (PG&E), where he focuses on strategy and project development. Prior to PG&E, Mulherkar worked on March 2024 | T&D World 35 2403TDW_MarmonUtility.indd 1

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WILDLIFE MITIGATION

The routing and siting of power lines plays a significant role in the reduction of avian collisions, as lines placed near high-concentration avian areas, such as known migration corridors or night roosts, present a greater risk of avian collision. Photo by POWER Engineers.

Birds on a Wire: The Perils of Power Lines Keeping different bird species separate from power distribution and transmission equipment is a crucial task for grid reliability and animal safety. By BEN BAINBRIDGE, POWER Engineers

ince the first power lines were constructed in the early 1900s, birds have used the wires and poles as places to perch, hunt for prey or even build a nest. Although it may sound harmless, the reality is that power poles and overhead lines pose a serious risk to avian species. In fact, bird collisions with telegraph lines were first reported in 1876. But in 1936, the Rural Electrification Act brought electricity to rural areas and greatly increased the amount of power lines in the country. While the Migratory Bird Treaty Act (MBTA) was established in 1918, it wasn’t until the 1970s that scientists and wildlife managers began paying attention to the extent of the impact power lines have on avian species. Since that time, the utility industry, wildlife resource agencies, conservation groups and manufacturers of avian protection products have worked together to better understand the various interactions between birds and power lines.

As communities continue to grow and the demand for electricity increases, so does the need to understand avian safety and implement environmental regulations that successfully protect birds.

Regulatory Protection and APLIC Three main federal regulations protect almost all native avian species. The Endangered Species Act applies to species that are federally listed as threatened or endangered. As the name implies, the Bald and Golden Eagle Protection Act provides additional protection to both bald and golden eagles. First established between the U.S. and Canada in 1918, the MBTA has since expanded to include Mexico, Japan and Russia, and currently protects 1,093 North American migratory bird species. On Jan. 7, 2021, the U.S. Fish and Wildlife Service (USFWS)

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WILDLIFE MITIGATION published a final rule regarding “take” prohibitions under the MBTA, stating that incidental take is not excluded under the law. The January 7 final rule was formally revoked on October 4, 2021. Currently, incidental take is considered a violation of the MBTA. This means that, under the MBTA, birds dying by electrocution or collision with power lines, wind turbines, buildings, cars and the loss of nests during construction activities are considered a take. In conjunction with regulatory protections, the Avian Power Line Interaction Committee (APLIC) was formed in the 1980s when 14 whooping cranes — one of the most imperiled bird species in the U.S. — were injured or killed colliding with power lines. A flagship species of the ESA, the whooping crane fatalities prompted action from the USFWS, Edison Electric Institute, Audubon Society and 10 electric utilities to form the committee. Today, APLIC has expanded to include the National Rural Cooperative Electrical Association and more than 70 member utilities. The committee works in partnership with resources agencies, the public and utility companies to develop and provide educational resources to minimize incidents of avian electrocutions and collisions.

Common Causes of Avian Injury or Death Avian electrocution is a frequent concern raised by state and federal wildlife managers as they consider power line projects under their jurisdiction. Birds can be electrocuted on power lines if they span the gap between two energized conductors

The most common avoidance measure to reduce avian collision is line marking, achieved through the use of bird flight diverters. Photo by POWER Engineers.

or an energized portion of a line and a grounded portion of a line. While this is a concern on distribution lines, transmission lines rarely cause avian electrocution due to the larger spacing between conductors. Avian collision with conductors and shield wires is another power line risk for birds. Several factors come into play when

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WILDLIFE MITIGATION

Wildlife mitigation that considers bird species ultimately benefits the birds, power utilities, their customers and the ecosystem. (Inset), The author with a sage grouse, a ground-dwelling bird vulnerable to habitat disruption. Photo by POWER Engineers.

examining avian collision: bird physiology, activity of birds, climate, placement of power lines and design configuration, to name a few. The ratio of a bird’s wing size to its mass is called wing loading. Collision is more common in species with high wing loading — smaller wings and heavier bodies. Birds in this category — cranes, waterfowl and grouse — are typically more susceptible to avian collision, given their low in-flight maneuverability. Certain bird activities such as traveling in large flocks, actively chasing prey or engaging in mating displays can increase rates

of avian collision, as can inclement weather like fog or other low-light conditions.

Conductor Spacing and Insulators There are a few simple measures that reduce the threat of avian electrocution. First, considering the conductor spacing during design. APLIC’s Suggested Practices for Avian Protection on Power Lines: The State of the Art in 2006 provides design standards for numerous conductor configurations. Generally, the guideline for preventing electrocution is by maintaining 60 inches of horizontal spacing and 40 inches of vertical spacing between conductors. These measurements are based on the size of a golden eagle, which is the largest bird in North America, with the exception of the rare California condor. When vertical and horizontal spacing cannot be achieved, conductor insulators can be installed to minimize electrocution risk.

Routing/Siting and Shield Wires Because birds frequently pass between areas for roosting, nesting and feeding, power lines that bisect these areas increase the risk of avian collision. Photo by POWER Engineers.

Because birds frequently pass between areas for roosting, nesting and feeding, power lines that bisect these areas increase the risk of avian collision.

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WILDLIFE MITIGATION The routing and siting of power lines plays a significant role in the reduction of avian collisions, as lines placed near highconcentration avian areas, such as known migration corridors or night roosts, present a greater risk of avian collision. The shield wire, typically placed above transmission lines, presents a higher risk of collision than the larger diameter conductor wires below. Birds may see the larger conductors and gain altitude to pass them over, only to collide with the narrower and less visible shield wire. While very rare in practice, certain transmission line spans, such as those over large river crossings, have been designed without an overhead shield wire to reduce the risk of avian collision. This is uncommon, however, as overhead shield wires protect the conductors from lightning strikes and often include a fiber-optic communication cable.

Line Marking The most common avoidance measure to reduce avian collision is line marking, achieved through the use of bird flight diverters. APLIC’s Reducing Avian Collisions with Power Lines: The State of the Art in 2012 provides guidance on bird flight diverter application, spacing and effectiveness. The effectiveness of these diverters, however, has been difficult to quantify. Most studies indicate that bird flight diverters reduce avian collision by about 60%, but these results are highly variable. Studies about their efficacy often vary widely depending on study design, climatic factors, bird behavior and the location of marker installation.

Numerous bird flight diverter designs are commercially available, each with its own application method and spacing recommendations. Bird flight diverter designs vary greatly. Some include swinging plates that provide visible motion, some use durable static coils with no moving parts, and others feature easy-to-install clip-on devices.

Birds and Power Lines Can Coexist Despite varying designs, the functional goal for each bird flight diverter is the same — to increase line visibility. Birds approaching a power line should see the bird flight diverters, gain altitude to avoid collision and pass safely overhead. An understanding of avian interactions with power lines is a complex but necessary topic to help utility companies and birds successfully coexist. From effective routing and siting to power line design and spacing and the addition of bird flight diverters, each component plays a role in reducing avian loss or preventing adverse impact. These precautions ultimately benefit the birds, power utilities, their customers and the ecosystem. BEN BAINBRIDGE is a certified wildlife biologist with experience in laboratory and field research with mammal, avian and amphibian species, plant species, wetlands and silviculture. He has experience in population surveys for federal- and state-listed special status species and condition assessment of their habitats. Bainbridge has a clear understanding of the requirements and processes of the National Environmental Policy Act and has applied these principles to field research and the permitting of electrical transmission projects.

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INTERCONNECTION PROCESS

Ameren Illinois-owned solar facility in East St. Louis, Illinois. Photo by Ameren Illinois.

Consider A Customer DER Interconnection Process Policy changes in Illinois have spurred a surge in Ameren Illinois’s distributed energy resource interconnections, prompting the need for a process. By BRAD BARNES and EDDIE CREIGHTON, Ameren Illinois

ver the last several years, the state of Illinois has experienced exponential growth in the number of customerowned distributed energy resource interconnections of all sizes, from residential rooftop solar to large-scale solar farms. This growth can be attributed, in part, to a series of legislative actions that stretch back as far as 1997, when customer choice was introduced. However, it is more recent policy changes that have sparked the uptick in distributed energy resource (DER) penetration in the state. One such change was legislation in 2007 creating the Illinois Power Agency to develop and conduct procurement processes for resources, including energy, renewables and energy efficiency. In 2016, the Future Energy Jobs Act (FEJA) initiated renewable energy credits (RECs) to incentivize the deployment of customer-owned DER. The act also introduced the Solar for All program, which began the state’s community solar program. Another result of the FEJA legislation, Illinois’ smart inverter rebate provides additional financial incentives to DER owners. Then, in 2021, Illinois passed landmark climate legislation aimed at transitioning the state to 100% renewable energy by

2050. The Climate and Equitable Jobs Act (CEJA) mandated significantly increased financial incentives for all sizes of DER and established carbon-free emissions goals for the state. The CEJA legislation has catalyzed DER growth and spurred Ameren Illinois, the state’s second largest electric utility, to look at ways to continuously improve how it efficiently manages the volume of interconnections while ensuring the stability and reliability of the electric grid. As a result of these policy changes, Ameren Illinois has seen an increase in net metering customers and community solar subscribers over the last 15 years. While community solar subscribers do not individually account for interconnection applications, these customers do correspond to the large distribution connected solar applications Ameren Illinois receives. In addition to a large increase in the number of interconnections, the utility has experienced a substantial increase in connected renewable capacity. Connected renewable generation on the distribution system has increased from approximately 4 MW in February 2016 to around 450 MW as of Dec. 1, 2023.

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INTERCONNECTION PROCESS

Interconnection Applications

Customers

Accumulative Net Metering Customers Per Year With the surge in interconnection 20,000 applications, Ameren Illinois moved NM customers per year - including Community Renewable 18,000 to establish a more formalized DER Generation Project (GRGP) subscribers. 16,000 interconnection process. The utility’s NM customers per year - Personal On Site Generation (POSG) interconnection requirements are 14,000 designed to facilitate customer-sited 12,000 DER installations while simultaneously 10,000 ensuring the delivery of safe and reliable power to all customers. Many of 8,000 the requirements for customer DER 6,000 interconnections are defined in the 4,000 Illinois Administrative Code Title 83 2,000 (Admin Code). The Admin Code creates a categorization of projects based 0 2000 2005 2010 2015 2020 2025 on the size of the generation being inYear stalled and the amount of power the proposed generation will be able to export to the grid. These categories determine how Ameren Level 1 projects are reviewed using a set of screening questions Illinois processes applications and its timeline for completing primarily designed to verify the distribution service facilities administrative reviews. (service transformer and secondary wire) are sufficient to allow interconnection. There is a screen to identify reverse power flow Technical Considerations at the substation, but even if system modifications are identified When developing its interconnection process, Ameren Illinois for a given Level 1 project, interconnection costs are capped at factored in numerous technical considerations. The intercon- US$200, so these projects often move forward with construction nection screening process is primarily driven by the applica- regardless of the outcome of the interconnection screening. tion level and screening criteria defined by the Admin Code. Level 2 projects follow a two-stage review process, as applicable:

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INTERCONNECTION PROCESS Application Level Criteria Project Type

System Requirements

Description

Level 1 Projects

Required to have a nameplate generating capacity of 50 kW or less and a power exporting capacity of 25 kW or less.

Projects are common at residences and small businesses, and they make up the majority of applications that Ameren Illinois receives by volume.

Level 2 Projects

Export capacity between 25 kW and 5 MW for inverter-based generation, limited to 2 MW for synchronous or induction generation.

Projects are mostly medium to large commercial/industrial customers installing generation to offset load or are megawatt-scale facilities connecting generation directly to the distribution system. The latter are often referred to as remotely located generation, or RLG, because they are not located near the loads they serve. Instead, these generation facilities operate as Community Solar facilities.

Level 3 Projects

Projects on secondary networks that are required to have a nameplate capacity of 50 kW or less and are limited to no power exporting capacity.

While Ameren Illinois has several secondary networks, no Level 3 applications have been received to date.

Level 4/Part 467 Projects

Level 4: Projects greater than 5 MW and not greater than 10 MW.

Large industrial customer projects may fall under Level 4 or Part 467, but the majority of these projects are RLG projects connecting directly to the distribution system. RLG facilities in this category must sell power outside of the IPA procurement process due to the 5 MW limit for Community Solar. Many of these projects connect to the 34.5 kV and 69 kV systems.

Part 467: Projects greater than 10 MW

• The first stage is an expedited review, using statutoryprescribed screening questions in a context similar to that of Level 1. The primary difference between the two reviews is the outcome of failed screening questions. While Level 1 projects have capped interconnection costs of $200, Level 2 projects are required to pay for all required system modifications to allow the project to connect to the grid safely and reliably. If all screening questions pass, then the project moves forward with an interconnection agreement, without having to proceed to a second stage of review. • If a screening question is failed, then the project moves to the second stage, a supplemental review. This review is more in depth, using a system model to identify any adverse impacts the generation could potentially cause to the distribution system. This process also includes a review by the high-voltage distribution planning department to verify no issues will arise on the 34-kV or 69-kV systems,

as well as a review by the system protection engineer to verify existing protection systems are adequate. While many different types of work are needed to facilitate the interconnection of DER to the distribution system, the criteria that require system modifications generally fall into one of four categories: • Thermal capacity violations occur when DER creates reverse power flow that exceeds the maximum thermal rating of the conductor or devices that make up the circuit the DER is connected to. • Steady-state overvoltage may occur due to the DER raising the voltage to enable reverse power flow. • Rapid voltage change (RVC) is a phenomenon that occurs due to the intermittent nature of renewable generation. For solar generation, cloud coverage changes that occur throughout the day will result in output fluctuations that impact the voltage of the line. • Reverse power flow is possible any time parallel generation is connected to the distribution system and may render existing system protection schemes inadequate.

Witness Testing

Example of smart inverter used at Ameren Illinois-owned solar facility. Photo by Ameren Illinois.

All DER interconnections to the Ameren Illinois distribution and sub-transmission systems are subject to a witness or commissioning testing process. The primary goal of this testing is to validate the DER can operate in a safe manner when generating in parallel with the grid. This testing keys off performance requirements found in the IEEE 1547 standard and includes tests of the DER shutdown and start-up behavior during grid loss and restoration events. The wide variety of DER installations results in unique challenges for each general class of interconnection. The volume of residential interconnections has grown significantly since the passing of the 2021 CEJA legislation, resulting in a significant staffing and digital resource investment to meet the increased demand for witness testing these sites. In addition to this, many DER vendors are now offering residential systems that incorporate battery energy storage systems (BESS), with the ability to form a microgrid inside the residence during a grid outage. These systems are often complicated and require more

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INTERCONNECTION PROCESS time and resources to complete the associated witness testing. Larger behind-the-meter (BTM) sites can be challenging to test for various reasons. Identifying the devices that will be used to generate the utility loss-of-phase events can be difficult depending on the configuration of the site’s electrical system. This can also be impacted by the inability or unwillingness of the customer to have the site load impacted by the grid-loss events. This sometimes requires creative solutions to simulate the loss-of-utility events that impact the DER but not the site loads. In some cases, the design of the DER system and equipment used to interconnect the site inverters can negatively impact the ability of the DER system to properly detect a loss-of-grid event. Remotely located generation (RLG) sites (community solar) are typically straightforward with respect to the witness test procedure. The primary challenges with these sites relate to their ability to detect and shut down for single-phase grid-loss events. While the inverters used are certified to the requirements of IEEE 1547, experience has shown, in some cases, the fully assembled DER system can introduce components that diminish the ability of the inverters to accurately detect grid-loss events. Most developers of these larger RLG sites have adopted the strategy of installing a relay-controlled recloser on the DER side of the revenue meter. The relay on this device is programmed to sense and trip all three phases of the recloser for single- and three-phase grid-loss events. This has proven to be a solid solution to meet witness testing requirements, and it also protects the site from extended exposure to loss of single-phase events.

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Lessons Learned

From small to large interconnection projects, Ameren Illinois has accumulated valuable experience through its DER enablement, including the understanding that even interconnections that appear straightforward can become a challenge. Ameren Illinois is committed to further enabling DER adoption through enhanced processes and technological advances that provide maximum value to all stakeholders, while ensuring safe, reliable and resilient operation of the electrical grid for all customers. BRAD BARNES is a consulting engineer with Ameren Illinois. He started his career with Ameren Illinois in 2018, leading smart grid technology research efforts at the Ameren Illinois Technology Applications Center in Champaign, Illinois. Barnes transitioned to the Ameren Illinois DER integration team in 2021 and now works to continuously improve the DER interconnection process by working collaboratively with customers and various teams within the utility. Barnes received his BSEE degree from Rose-Hulman Institute of Technology in 1988. EDDIE CREIGHTON is an electrical engineer on Ameren Illinois’ clean energy transition team. He works with engineers to facilitate DER interconnections on a daily basis. Much of this includes leading the efforts to update interconnection standards, policies and procedures. Prior to this role, Creighton served almost five years as a distribution planning and operations engineer. Among other duties, he performed dozens of interconnection studies to facilitate the Illinois Renewable Energy Credit lottery, studied the impacts of parallel generation on load forecasts, and worked with customers and developers to commission several customer-owned solar fields. Creighton received a BSEE degree from Clemson University in 2015.

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ELECTRIFICATION

An electrocenter under development in Curitiba, the capital city of Paraná, Brazil. (inset) Electrical work was completed in accordance with Copel’s technical standards. Photos by LACTEC, Copel.

Brazil Kick-Starts Electric Highway Initiative Brazil explores the use of ‘electrocenters’ to charge EVs simultaneously and a demand control system to address the power limitations of charging EV batteries. By CARLOS GABRIEL BIANCHIN, RICARDO MUZZOLON SCHMAL, RAFAEL MOREIRA MIGGIORIN, RHAFAEL FREITAS DA COSTA, LUCIO DE MEDEIROS, LACTEC; and RODRIGO BRAUN DOS SANTOS, Copel Distribuição

ike many countries around the world, Brazil has seen a significant increase in the utilization of electric vehicles. During the pandemic, the country saw an increase of 80% in utilization per year. This growth has spurred the need for robust charging infrastructure, particularly in the cities. According to the International Energy Agency (IEA), 860,000 public charging stations were installed in 2019 globally, and by the end of 2022, that number climbed to 2.7 million — an increase of 214%. Brazil is still in the early stages of rolling out its charging infrastructure. According to a 2021 report on Brazilian electric mobility from the National Electric Mobility Platform (PNME), it is estimated 150,000 charging stations will be needed by 2035 to meet a fleet of 3 million pure electric and plug-in hybrid vehicles. This represents a total investment of about US$2.5 billion to build the charging station infrastructure. The infrastructure to charge electric vehicle (EV) batteries requires more energy, which can pose a risk during simultaneous charging. To address this problem, Brazil implemented an intelligent charging system. The system communicates with the

charging stations, acquiring operational and technical information. Then an algorithm provides analyses of instantaneous power consumed by number of vehicles and — through a power limitation algorithm — controls the maximum energy level delivered to vehicles simultaneously, to avoid reaching peak power. The solution has been implemented in two electrocenters in Curitiba, the capital city of Paraná. The project was carried out in partnership with Copel Distribuição, through the Brazilian Electricity Regulatory Agency (ANEEL) research and development program. Copel initiated the project as part of its initiative to implement the largest electric highway in Brazil.

Charging Station Control EV charging stations have been developed with multiple communication systems (for example, LTE and Wi-Fi) and open charge point protocol (OCPP). While numerous protocols exist, the most widely used is OCPP. This open-source protocol provides flexibility in the communication and management of charging stations. It is possible

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ELECTRIFICATION

(Left) At the Copel site, access is free, whereas at Lactec, access is free during the week and has a fee on the weekends. (Right) At the Copel electrocenter, it is possible to observe the loads, with visibility to the charging stations and other accessory loads (lighting and telecommunications).Photos by LACTEC, Copel.

to monitor a variety of parameters and send commands, and even update programs such as firmware of the charging station. OCPP is divided into sections. The so-called core is the main section and required for implementation. The other sections are more informative in nature but can serve as a management system.

Demand Management System The main proposal for the development of this project was based on the use of the central system and communication protocol

used by the charging station manufacturers (ChargePoint communication infrastructure was already in place). For this project, version 1.6 of the OCPP protocol was used. Requirements for the central system were established, including minimum functionalities for integration with the management and billing platform: • OCPP 1.6 protocol implementation for communication with charging stations through WebSocket interface • Implementation of a database for recording configurations of charging stations and their owners,

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ELECTRIFICATION

Depending on the charging station manufacturer, demand control is enabled by instantaneous power or electric current. In this project, the manufacturer enabled instantaneous electric current control. Photo by LACTEC, Copel.

such as: model, charging capacity, type of plugs, number of plugs available, geographical location, owner identification, manufacturer, communication protocol and charger status • Registration of new charging stations, which could have different brands and manufacturers as well as use different communication protocols • Implementation of an algorithm to control load demand.

Electrocenter Locations

Sites were surveyed to determine where to place the electrocenter. In the end, the final decision was to divide it into two locations, one on the premises of Lactec, one of the largest research, technology and innovation centers in Brazil, and the other on the premises of Copel, both in Curitiba. At the Copel site, access is free, whereas at Lactec, access is free during the week and has a fee on the weekends. They are both open to the public, so any user can access the site and charge their electric vehicle. Electrical work was completed in accordance with Copel’s technical standards. For example, for the Lactec electrocenter, the electrical project included installing the electrical connections, loads (charging stations and accessory loads) and a photovoltaic system as a carport. At the Copel electrocenter, it is possible to observe the loads, with visibility to the charging stations and other accessory loads (lighting and telecommunications). The Lactec electrocenter counts on a photovoltaic energy generation system that provides 30 kW of peak power and injects all the energy generated Electrical work performed as part of electrocenter construction. Photo by LACTEC, Copel. into Copel’s low-voltage grid (220 V to 46 T&D World | March 2024

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ELECTRIFICATION 380 V), where the EV charging stations are connected. By Brazilian legislation, the energy injected into the grid can be used as credits at this location and others belonging to Lactec (in this case, Lactec holds the responsibility for the energy bill of the Copel utility that feeds the charging stations). Users can download an app (available in iOS and Android) to their mobile phone, register and carry out the charging process by releasing a plug for connection to their EV. This system was developed in a different project by Lactec, Copel, Eidee and Xpert, and it presents different charging values depending on the power available for vehicle charging. The system developed for this project allows, at the same time, the operational management of the charging stations to control the maximum power available for each station, from the power demand contract. This sys- Users now have access to numerous charging stations with different power capacities and can charge EVs simultaneously. Photo by LACTEC, Copel. tem of demand control per charging station enables the maximum power of a set of stations not to accept the command after charging has started. Therefore, the exceed the maximum contracted with the distribution utility. A tests carried out in this project considered alternating charggreat advancement, this feature enables stations to be installed ing stations with a maximum power of 22 kW. The continuin an existing installation without the need to rewire the electri- ous charging stations will be included in the demand control cal system or redo the contract with the energy concessionary. system only with regard to the availability, or lack thereof, The demand limitation per charging station is dynamic, that of the station. Depending on the charging station manufacturer, demand is, the available power value changes during the day, allowing each EV to experience different power levels depending on the control is enabled by instantaneous power or electric current. time of day and power consumption of the installation. The In this project, the manufacturer enabled instantaneous electric number of EVs filling up simultaneously can also affect this limit. current control. Once it has set the power limit value for each station, the control system sends this limit using the set-charging-profile Electrocenter Operation command within the OCPP. The electrocenters became operational in December 2022, with users registering by the mobile app. Users are billed per minute Charging Stations of charging, and the amount depends on the maximum power At Lactec, the electrocenter has six charging stations: four each charging station can deliver to the vehicle. stations with two Mennekes T2 plugs at 22 kW each and two The use of each charging station is simple: The user requests fast-charging stations with Mennekes T2, Chademo and CCS2 the release of the plug in the mobile app, connects the plug in plugs (in this station, the alternating output has a maximum the vehicle and, from there, the handshake is made between power of 43 kW and the CC charging outputs have a maximum the station and vehicle, and the charge initiates. The user can power of 60 kW). select some charge parameters, but the most used, is the full At Copel, the electrocenter has three stations: one alternating charge. The user can interrupt the charge of the vehicle at any charging station (identical to Lactec’s, with 22-kW maximum time, either in the app or by the vehicle. power and two plugs), one fast-charging station (identical to Demand control is active and operational, but as the numLactec’s, with three plugs — Mennekes T2, Chademo and CCS2) ber of EVs is still limited, no action has been taken at either of and one ultrafast-charging station (with 150-kW maximum power the electrocenters. and a CCS2 plug). Since the start of operations, both electrocenters have supplied a total of 2.86 MWh. The average of each charge is 11.4 kWh.

Demand Control

According to the OCPP protocol, demand control has not yet been implemented in continuous charging systems, regardless of the power. The explanation is that different vehicles do not

A Complete Solution The electrification process, which was initiated by Copel with an implementation project of the largest electric highway in March 2024 | T&D World 47

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ELECTRIFICATION this power is not achievable with most EVs operating in Brazil today. This system also counts on demand control, which limits the power of all charging stations in each electrocenter to the maximum value contracted with the electric utility. The association with the photovoltaic system in one of the electrocenters has allowed the monthly energy bill to be significantly reduced due to the energy that is being injected throughout the day. As a business, this helps to ensure the two electrocenters are sustainable. Finally, the junction with another project that developed the mobile and billing system, associated with demand control, offers users a complete solution for charging EVs with operational reliability and highpower availability. Brazil expects the user base will expand in terms of power delivered for charging. This system also counts on demand control, which limits the power of all charging stations in each electrocenter to the maximum value contracted with the electric utility. Photo by LACTEC, Copel.

Brazil, reached a new level with the rollout of the two electrocenters in the city of Curitiba. Users now have access to numerous charging stations with different power capacities and can charge EVs simultaneously. The period of operation is short yet most users prefer the higher 150-kW equipment, even though

Acknowledgment

The authors would like to thank Copel Distribuição for its funding through the ANEEL research and development program resources (code number 2866-0517-2019). CARLOS GABRIEL BIANCHIN (bianchin@lactec.org.br) has BSEE and MSEE degrees as wel as a D Sc degree in 2017 in power converter for recharge electric vehicles and is a researcher at LACTEC, the Institute of Technology for Development. His responsibilities include static converters, electrical power distribution, digital control by digital signal processors, power quality, power factor, rectifiers and battery charging for EVs. RICARDO MUZZOLON SCHMAL (ricardo.muzzolon@lactec.org.br) has a degree in computer engineering and a post-graduate degree in biomedical engineering. Employed at LACTEC, he has worked on metering systems, phase identification and the construction of an underground chamber for training teams. Currently, Schmal is engaged in the development of charging systems for EVs. RAFAEL MOREIRA MIGGIORIN (rafael.miggiorin@lactec.com.br) is an electrical engineer experienced in software and firmware development for embedded applications. Currently a system development engineer with Siemens. RHAFAEL FREITAS DA COSTA (rhafael.costa@lactec.com.br) graduated in Information Systems from the State University of Northern Paraná - UENP/CLM. Postgraduate, specialization level in Database from the University of Northern Paraná - UNOPAR. Professional master’s degree in technology development from the research institute for development. He currently works at LACTEC as a Software development specialist. LUCIO DE MEDEIROS (lucio.medeiros@lactec.com.br) is a senior researcher at LACTEC. He has more than 25 years of experience in energy efficiency, statistics modeling, and forecasting methods applied to the energy sector. He is also a senior researcher at LACTEC Instituto de Tecnologia para o Desenvolvimento. He has previously worked at ICF International as senior energy manager, and at ENEL Rio de Janeiro as an energy market and regulation specialist. RODRIGO BRAUN DOS SANTOS (rodrigo.braun@copel.com) is project manager in smart grid and special projects division with Copel Distribuição, Curitiba, Brazil.

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Utility vault covers are available in both metal bar grating and solid plate to meet the requirements of any application. Photo by Ohio Gratings.

Push for Undergrounding Drives Advances in Vault Covers New ADA-compliant utility vault covers improve safety, cut liability costs for utilities, and provide access to underground infrastructure.

tilities across the U.S. are moving toward underground installation. Undergrounding improves street views, minimizes weather damage and reduces wildfire risk while protecting vital infrastructure. The rise of undergrounding highlights a growing need for reliable, safe and effective utility vault covers. New covers provide innovative solutions for safety, compliance, and access, enhancing construction projects and protecting utility companies from liability. Public safety is a primary concern for electric utilities. However, existing vault covers do not always meet current requirements for vehicle loading and pedestrian protection. New covers should be designed to comply with American Association of State Highway and Transportation Officials’ (AASHTO) H-20 vehicular loading requirements and Americans with Disabilities Act (ADA) guidelines. AASHTO H-20 vehicular classification refers to an axle load of 32,000 pounds or wheel load of 16,000 pounds. Vehicles in this category include fire trucks, emergency vehicles, sanitation trucks, concrete trucks and delivery vans. Hazardous conditions result from these types of vehicles driving onto a sidewalk and damaging improperly rated bar grating or solid plate covers. Damaged covers might go unnoticed until a pedestrian or

worker trips, slips or falls, resulting in injury. Installing robust products specifically designed to withstand heavy vehicular loads can prevent these hazards from occurring. New vault covers are also manufactured to meet or exceed current ADA guidelines for pedestrian safety. These guidelines stipulate that the gap between grating surface bars should not exceed 1/2 inch. Grating covers can surpass this requirement with an even smaller gap of 5/16 or 1/4 inch, which is ideal for bicycles and high heels. The percentage of open area ranges from 52% to 76% which typically complies with airflow cubic feet per minute (CFM) requirements for underground subway ventilation and heat emitting utilities like transformers. This promotes safety for pedestrians as well as for critical equipment.

Limiting Liability with High Traction ADA guidelines for pedestrian safety also require walking surfaces to meet current traction standards, which is vital for limiting liability. Each year, slip and fall injuries in the United States account for approximately $60 billion in medical and work loss costs, according to the Centers for Disease Control and Prevention. Additionally, each incident costs $48,000 on average

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SOLUTIONS CENTER and results in 14 lost workdays (National Safety Council). This is a risk that utility companies cannot afford to ignore. New grating covers address ADA traction standards in two ways. First, by spanning the surface bars perpendicular to the predominant path of pedestrian traffic, which maximizes the surface’s inherent traction capabilities. Second, by applying a metal traction surface that dramatically increases slip-resistance. The degree to which a surface resists slippage is measured as the dynamic coefficient of friction (DCOF). DCOF is tested on wet surfaces and measured on a scale of zero, the lowest traction, to one, being the highest traction. The American National Standards Institute (ANSI) A326.3-2021 / Hard Surface Test Standard establishes a minimum wet DCOF of 0.42 for acceptable traction. Traditional traction-enhancing products include paint-on sand and epoxy mixed with a fine aggregate. These older applications provide some initial benefit but lose slip-resistance over time as the material degrades due to wear and environmental factors. A superior alternative is an applied metal traction surface with wet DCOF averages that greatly exceed 0.42. Two of the most effective metal traction application methods are thermal spray and laser deposition. Thermal spray affixes molten metal to the base surface to create a sandpaper-like texture. Laser deposition uses CNC technology to weld individual traction features onto the surface metal. Both applications bond with metal bar grating or plate to achieve long lasting durable slip resistance.

BEFORE: Solid concrete vault covers hindered access, and grating sections were non-ADA compliant. Photo by Ohio Gratings.

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SOLUTIONS CENTER

AFTER: Vault top replacement includes new frames, ADA and AASHTO compliant grating covers and access doors. Photo by Ohio Gratings.

Compression spring cylinders counterbalance the weight of access hatch doors for safe, easy and ergonomic manual lifting. Photo by Ohio Gratings.

Choosing the right traction safety product ensures that vault covers will exceed industry requirements and ADA guidelines while protecting companies from excessive liability costs.

Smart Access with Lift Assist Vault cover safety is just as vital for field workers as it is for the public. This begins with ensuring that vaults are easily accessible for maintenance and repair. When vaults are covered by massive concrete slabs that are only removeable by crane, it impedes worker access and prompts road or sidewalk closures that result in excessive time delays. Metal covers also present a challenge and risk of injury due to the substantial lifting force required to open heavy access hatch doors. Utility vault covers with lift assist technology provide an innovative, ergonomic solution. An integrated lift assist system prioritizes worker safety and simplifies access by dramatically reducing or eliminating the lifting weight of access hatch doors. Lift assist systems can be equipped with either compression spring cylinders or electric linear actuators. Compression spring cylinders work by counterbalancing the weight of access doors. Using the system pictured at the right, a worker can open a 265-pound door with only 35 pounds of actual lifting force. Spring cylinders prove more effective and reliable than gas filled or pneumatic cylinders, especially in cold weather conditions. They are made from stainless steel, ensuring they are non-corrosive and extremely durable. Cylinders can be easily removed or replaced by unbolting the top and bottom stainless steel hardware assemblies. To enter a vault, workers unlock the hatch door, grasp the integrated handle, and easily raise it with lift assist. A steel locking safety bar automatically secures the hatch door in its fully vertical position, streamlining access while work is being completed. For added safety, hatches can be equipped with a removable light duty safety grate to protect against falls. Innovative collapsible folding barriers can also be integrated as another precaution. When exiting the vault, workers manually disengage the locking safety bar, allowing the lift assist system to gradually lower the hatch door. Once closed, it is secured with a locking mechanism. Electric linear actuators easily manage access hatch doors of any size or weight with no manual lifting. Actuators can

Electric linear actuators open ventilated and solid plate hatch doors of any size or weight with the push of a button. Photo by Ohio Gratings.

be installed in both bar grating and solid plate doors. The door pictured above is a 1,000-pound solid plate access hatch. To open the hatch, workers unlock an access panel and plug in a door controller. With the press of a button, the hatch raises to its fully vertical position, where it remains secured until work is completed. After lowering the hatch and locking the access panel, the door controller is stowed safely in the utility vehicle. Vault covers should provide easy access when it is needed and excellent security when it isn’t. Mechanical gravity locks and fivesided bolts provide a high degree of security with or without keyed entry. Linear actuators secure hatches without additional locking components. These methods prevent damage and tampering year-round, even in harsh weather conditions such as snow, ice and freezing temperatures.

Building for the Future In new construction, proactive utility companies are revising their standards for vault covers to comply with pedestrian safety guidelines and vehicular loading requirements. There are two options for new vault covers: solid metal plate and metal bar grating. Vaults use solid tops for utilities that do not require airflow, such as water, gas, cable, or fiber optics. Metal bar grating

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SOLUTIONS CENTER is necessary for subway ventilation grates and heat generating utilities such as transformers. Vault cover solutions can be customized with a combination of plate and grating elements to meet unique design needs. New covers can also be retrofit into preexisting frames. This helps property owners prioritize safety by replacing damaged or deteriorating vault covers before they become problematic. If the preexisting frame is too shallow, the cover’s deeper structural bearing members can be coped to fit the specifications of the frame. For vault top replacements, the original vault remains in place while the top portion of the vault walls and cover are changed. New galvanized steel frames are installed with concrete poured around the perimeter. Once the frame is set, the new properly rated vault cover is placed inside. Replacing or retrofitting vault covers is much more cost effective than a complete vault replacement and greatly reduces the annual cost of maintenance. Ohio Gratings, Inc. partnered with the Southern Company to complete one such vault top replacement in downtown Atlanta, Georgia. In this case, the existing vault was covered with concrete slabs that did not allow adequate ventilation for the transformer underneath. The few areas that were ventilated utilized a light duty grating product that was neither ADA compliant nor AASHTO H-20 rated. This presented a logistical and liability problem for the company. Ohio Gratings worked closely with the Southern Company’s standards engineers to identify utility requirements and develop solutions that included new frames, grating, and

access doors. “This was a collaborative effort,” said product engineer Aristotle Zournas. “The resulting covers are fully compliant, provide the appropriate percentage of open area for ventilation, and are properly rated for potential heavy vehicle loads.” The new installation is virtually maintenance-free and creates a much safer environment for pedestrians and workers in Atlanta. Once the solution was implemented, frames and grating panel sizes were standardized for use in future projects. Standardization allows the Southern Company to maintain a consistent vault size throughout the city, streamlining vault cover replacement and new construction. BRIAN PELTO (bpelto@ohiogratings.com) serves as the specialty products sales manager for Ohio Gratings, Inc. Pelto’s team serves the Bridge & Transportation, Park & Recreation, and City Sidewalk markets. His experience includes working with customers and clients including utility engineers, DOT engineers, precast firms, utility contractors, and architects to provide solutions for over 28 years. He is an Ohio Gratings member representative to the National Precast Concrete Association and California Precast Concrete Association, and a vendor representative the Western Underground Committee. KEVIN MILLER, P.E. (kmiller@ohiogratings.com) serves as the vice president of business development for Ohio Gratings, Inc. He is a licensed Professional Engineer who has partnered with customers and clients to provide strategic solutions for over 30 years. His experience includes civil and structural engineering, product design, and creating partnerships and solutions that provide positive results. He is a member of the American Society of Testing and Materials and the Transportation Research Board, serving on multiple research and standard committees.

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FACES OF THE FUTURE

BY AMY FISCHBACH, FIELD EDITOR

to my current spot in Oakley, Kansas, before I graduated and have been at Midwest Energy since.

Training on the Job At Midwest Energy, we primarily work on OHD and URD transmission, OHD and URD distribution and substations. About 99% of the training for me was in the field. For book work, I was in online Red Vector classes.

Challenges in the Trade Getting a start at a good place would be the hardest part. I was lucky enough to find a great company with great journeymen and foremen.

Transforming Apprentice Training

Theron Tucker Midwest Energy

My company is currently changing how apprentices are trained. Because I’m about to top out, I probably will not be a part of this new training. Even so, I would say more training equals safer work environments. We do not currently have a training center, but the apprentice trainer is working on a few things.

Working a Storm Theron Tucker, who competed in the 2023 International Lineman’s Rodeo, was the PLP Armor Rod Install Challenge champion at the Expo. PLP’s video of him competing in the contest captured more than 28 million views on T&D World’s Instagram page, Linemen World.

My first big storm work was from a 100-mph+ windstorm in western Kansas. This caused multiple fires to spark up and burn everything in its path. Work conditions were 10° weather with high winds blowing piles of ash over everything. It made it hard to breathe. It felt great, however, to get customers’power turned on for Christmas.

Achieving Work-Life Balance • Lives in Oakley, Kansas. • 4th year apprentice. • Currently building a few miles of 34.5 kV with 7620 underbuild. • Considers a good attitude as the key for success. • Having the experience of operating farm equipment on his family’s ranch helped him in his job in the line trade. • Currently, the crews’ best new tool is the electric staple gun, which has saved hours of stapling per day. • Sees a constant growth in electrical demand as the future of line work.

My favorite part of Midwest Energy is the balance that it gives you in between your work life and personal life. Sometimes we’re very busy, but a lot of the time I’m home before 5 p.m.

Staying Safe in the Field I advise other apprentices to not get complacent and to give your surroundings immediate attention. Also, the best thing for safety is to truly know what you are working on. In my opinion, the more knowledge you have of the electrical system, the safer you’ll be.

Inspiration to Work in the Trade

Looking to the Future

I was very interested in the line trade because of multiple people including my father’s friends and brother. By the time I was a sophomore in high school, I had made up my mind that I was going to be in line work.

In five to 10 years, I would like to be working with the same people and helping to train future apprentices.

Getting His Start I worked for a year at a grain and fertilizer co-op to save up for Northwest Lineman College in Denton, Texas. I applied

Editor’s Note: All profiled apprentice lineworkers will receive a tool package from Milwaukee Tool. Tucker will be featured in a future “Faces of the Future” Line Life Podcast series at linelife.podbean.com.

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ELECTRIC UTILITY OPERATIONS

BY MARTY T. IVY, MAYFIELD ELECTRIC & WATER SYSTEMS

Lives were lost and the town leveled as an unpredictable weather emergency wreaked havoc in just three minutes. Mayfield’s 600,000-gallon elevated water tank once stood here.

Reflecting on a Tragic Night and Resilient Recovery Mayfield Electric & Water Systems navigates devastation and outages during the aftermath of a fatal tornado in Mayfield, Kentucky.

ometimes warnings are just that: warnings. But sometimes, they are the precursor to disaster. The town of Mayfield, Kentucky spent the days leading up to Dec. 10, 2021, hearing constant storm warnings, but it had not the slightest idea of what was to come. One of the most

devastating weather events to ever take place in the community was on its way. A tornado with wind speeds reaching up to 190 miles per hour wreaked havoc in Mayfield, claiming the lives of 22 beloved neighbors and friends. The twister demolished nearly 500 homes,

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ELECTRIC UTILITY OPERATIONS businesses and community landmarks, and knocked out power to most residents. Two years may have passed, but the devastation that surrounded the town will never be forgotten. Emotions span sadness and grief, but also pride. The aftermath of the tornado was bleak, but also demonstrated pride for the line crews and the volunteers who swarmed the town to lend a hand. Together, they were able to shine a light in such a dark time. Using technology from Sensus, a Xylem brand, the utility implemented a swift power restoration process that led to all power being restored within just one month of the city being leveled.

The town’s collective damage added up to $45 million. At first, it was overwhelming, but hopefulness quickly took over as volunteers from across the country immediately came to the community’s aid.

Compassionate Partnerships Three days after the tornado, MEWS’s crew numbers had increased by five times with everyone from lineworkers to vendors to complete strangers pitching in. MEWS went from a small utility with 44 full-time employees to more than 200 employees and municipal aid workers. Just housing this many people and

Lessons of the Past A few things can be credited for this amazing response time and recovery. At the top of the list are the preparedness measures put in place by crews at Mayfield Electric & Water Systems (MEWS). In 2009, the utility experienced a severe ice storm that caused 10,000 people to lose power. The utility’s hands were tied. The crews and support teams didn’t know where to start because they had never prepared for an outage of that magnitude. The recovery efforts taught the team a valuable lesson; be prepared for anything. After creating a list of challenges, it was important to be honest about the mistakes made during the response and restoration efforts. This spurred ideas for how to be more efficient in the future. Twelve years later, remembering the lessons learned paid off. Having an emergency response plan already in place was a relief as the utility balanced its grief with outage restoration work in 2021.

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Work the Plan Immediately following the storm, the first part of the plan was to ensure all the employees were okay. MEWS contacted them and reserved 100 hotel rooms in neighboring communities for employees and potential crews who were en route to help with the rebuilding process. It was vital to get them the resources they needed first, so they could serve the rest of our community. Next, the team evaluated the equipment. Most of it had turned to rubble. The tornado blew out the windows and damaged the roof of MEWS’ main office. The harsh winds wiped out the computers and servers and totaled some of the fleet of bucket and digger trucks.

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ELECTRIC UTILITY OPERATIONS

Emergency preparedness from past lessons and advanced metering infrastructure (AMI) was key to a successful and efficient recovery.

The substation was back online within a week and the homes able to reconnect to the grid had power again within the month.

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ELECTRIC UTILITY OPERATIONS feeding them three hot meals a day is an amazing task within itself. The office staff handled this portion of the recovery for about four months each and every day without a hiccup. Xylem’s Sensus was one of the first groups to call and offer their support. It solidified the fact that our relationship with the smart technology company is not just a transactional one— they’re truly an extension of our team. Xylem engineers visited Mayfield, Kentucky, to ensure that both electric and water meters, along with the FlexNet communication network, continued robust and reliable operations. Other employees volunteered to assist MEWS with massive cleanup efforts. The camaraderie experienced during this time called to mind the values the utility industry embodies. The utility’s advanced metering infrastructure (AMI) and meter data management (MDM) system can also be credited for the successful recovery. MEWS remotely tracked when power was restored at specific locations. The data management system’s visual graphs mapped out the progress and provided the team with onthe-ground knowedge in near-real-time that allowed the employees to prioritize their remaining workload. West Kentucky Rural Electric Cooperative, another neighboring utility that experienced the same tornado, assisted MEWS in power restoration efforts. Just five days after the tornado touched down, the utility had all three circuits operating and restored power to the local hospital. After one week, the substation was back online, and in two weeks, more than 80 percent of the city was reenergized.

documented crisis response plan in place. While we hope we never see anything like it again, we’ll be ready.

MARTY T. IVY, C.P.E., (gensupt@mewsbb.com) is Mayfield Electric & Water

Systems’ general superintendent. He oversees day-to-day operations that contribute to community growth and progress. Ivy is in his 23rd year leading the utility and serves on several boards including the Kentucky Municipal Utilities Association and Kentucky Public Power Association. He is a graduate of Murray State University.

Big jobs call for big purchases. Or do they?

The Perfect Formula The pace at which this process moved was astounding given the desolation. MEWS had the perfect formula for addressing such a large-scale weather emergency: a plan + the FlexNet communication system + the kindness and aid of those in the utility industry. Perhaps most importantly, was the Mayfield Electric & Water Systems team. Their neighborhoods and homes came crumbling down around them, yet they worked tirelessly to serve the community and rebuild power and water access. Their precision and discipline were vital to the recovery efforts, and we are blessed to have such an amazing staff. Just like we did in 2009, MEWS continues to learn from this weather event in 2021. The utility now has a thoroughly

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PARTING SHOT

PHOTO BY JOHN LARSEN, CREATIVE PRODUCER, PEDERNALES ELECTRIC COOPERATIVE

A PEC lineworker in Central Texas responds during Winter Storm Heather in early January 2024.

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SAVE THE DATE

October 16-19, 2024 • Overland Park Convention Center Overland Park, KS • linemansrodeokc.com 2311TDW_House_LinemansRodeo.indd 1 2403TDW_61-62_Focus.indd 61

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FOCUS: A LINEWORKER’S VIEW

BY AMY FISCHBACH, FIELD EDITOR

Meet Kevin Adams EJ Electric/IBEW Local 3 Kevin Adams was nominated by Apprentice Michael Bosco, who considers him one of the most hardworking and knowledgeable lineworkers he’s come across during his apprenticeship. • Born and raised on Long Island, New York. • Married to his wife, Dani, and they have a five-year-old son named Kevin Anthony. • Enjoys being out in nature, going to the beach and swimming in the ocean. Also loves being in the woods and going bow hunting in the fall and winter. • His father, a heavy equipment operator, worked closely with lineworkers. He encouraged him to apply for the apprenticeship, and once he started climbing, he couldn’t get enough. • Currently in Queens, New York, doing a hot 27 kV reconductor/pole change out. He’s enjoying the work, and he never wants to stop learning. • Loves his classic hand tools and impact gun.

Early Years My first job was on a rear prop pole change-out crew. It was a great group of guys who had me in my hooks every day and taught me a lot right out of the gate. Shortly after I topped out as a journeyman lineworker, I started running a crew, and that continued for five years. I got to run some big jobs all over Long Island, New York.

Day in the Life I’m currently a journeyman lineworker on a three-person crew in Queens, New York, doing 27 kV junction cut and kicks almost every day. I really enjoy working in the city because there are so many different challenges. Just being able to wake up every day and go to work to solve another puzzle is a great feeling.

Safety Lesson When I was an apprentice, there was a capacitor bank that didn’t open up correctly and drew an arc that went phase to ground. Seeing that arc draw across and explode the way it did ingrained an image I’ll never forget. It’s a constant reminder that everything we’re doing is very serious, and we can’t get complacent. Know what’s going to happen with every move you make, and take extra precautions to protect yourself, even when things are unlikely to go wrong. It just takes one little malfunction or misstep that will cost you your life.

Memorable Storm I drove down from Long Island to help restore power following Hurricane Irma down in Miami for just about a month.

Entire pole lines were taken out, and trees were down everywhere. For the first day after the storm, we were on Daytona Island and had to wait for the flooding to go down before we could cross the bridge and get off. When we got to Miami, they put us on all the rear prop crane sets. The bird dog told us that other contractors were turning those jobs down so we got to stay longer just setting new poles and stringing wire.

Future Plans I would do it 100 times over. The places this trade has brought me and the world I’ve gotten to see because of it is such a reward. Being able to get thrown into messes and being able to figure it out is a great feeling. God blessed me to be able to do this type of work. I want to do as much as I can in every aspect of my life. But no matter where I am in the future, I feel like I have to be involved in line work to some degree. Editor’s Note: All profiled lineworkers will receive a tool package from Milwaukee Tool.

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March 2024 | T&D World

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2/19/2024 1:07:07 PM

STRAIGHT TALK

BY LESLIE M. DUKE, BURNS & McDONNELL

Solutions Are Within Reach for Today’s Complex Challenges

s our utility clients are facing new pressures, they are seeking out innovative ideas to address increased demand for clean, reliable energy. The solution-oriented mindset of engineers and construction professionals in the face of obstacles gives me confidence in our ability to facilitate the monumental changes underway in the power sector. Utilities are facing an unprecedented evolution in what regulators and customers expect from them. Optimizing their investments in building, operating and maintaining their assets is as complex as it is essential. Reliability and affordability remain the watchwords for electric utilities. Achieving and maintaining those objectives is a tougher climb when the global energy transition and increasing electrification are asking more of our critical infrastructure than ever. But I know we can reach our goals by working together and applying new and integrated solutions.

Miles of Work Ahead This year is poised to be a big year on the policy front, working through regulations to balance load growth, climate, reliability and affordability. Landmark investments in the U.S. electric sector are creating a generational influx of billions of dollars in funding and tax credits to upgrade the grid. The U.S. Department of Energy reports it is already seeing the infusion of these funds starting to emerge. The scale of renewables expansion is staggering. Renewable energy sources have made enormous leaps forward in terms of deployment and affordability, boosting carbon reduction initiatives. While they will struggle to achieve net zero emissions alone — and must pass through the congested interconnection queue gauntlet — they have an important role in moving toward decarbonization targets. Much of the electrical transmission and distribution grid requires upgrades to support two-way power flows. Communications and controls are critical to managing the complexity of the modern grid in real time. Many of these grid modernization efforts are already in the works or underway, but thousands of miles of work is yet to come. Another significant factor utilities must deal with is the cost of capital. Money is expensive, as interest rates hover near recent highs. Commissions have also been carefully scrutinizing rate cases, making it even more important for utilities to prepare strong, defensible requests as they launch into significant, multiyear investment programs. No surprise: Everyone wants decarbonized power and electrification, but paying for it — and all it entails — upfront is one of the great challenges of our time.

Success Is an Attitude There are good reasons for optimism. I believe we are in the

middle of a technology revolution. We must embrace, not fear, the changes coming. We are seeing a wellspring of new technologies, innovative ideas and reimagined processes. These new ideas are moving quickly and infusing value in creative solutions to the challenges confronting our critical infrastructure. Implementing new technologies — including smart meters, smart grid systems, cybersecurity measures, electric vehicle charging and battery storage — is a key area of investment for utilities. Diverse project delivery methods provide customized approaches to the wide range of project needs and budget requirements involved in strengthening the grid for decarbonization and electrification initiatives. Working with partners able to offer a variety of project delivery methods to suit your needs can make a dramatic difference in the implementation and cost-effectiveness of projects and programs. Integrated approaches can enhance communication, streamline approvals, and minimize the number and extent of change orders. Any or all of these can help utilities get more in a time of significant constraints on materials and personnel. Electric utilities will need contractors who complement and extend their capabilities, empowering the utilities to prioritize projects and maximize the impact of their capital investments in delivering reliable power. The work is thrilling, but it will take investment and collaboration across our entire industry in support of a greater cause.

Rising to the Moment In January I became chair and CEO of Burns & McDonnell, an opportunity to lead the company where I’ve spent 24 years helping clients and finding solutions to challenges. It has been an honor and a humbling journey. In those years, I’ve seen the economy rise and fall. I’ve seen trends emerge, bloom and pass. I’ve worked with hundreds and thousands of professionals across numerous industries and disciplines as we tackle the challenges of our time. When I say I have confidence in our ability to achieve extraordinary outcomes, it is because I have witnessed what resolute organizations can accomplish through adaptability and perseverance. A relentless focus on living and working safely is a vital piece of the puzzle. It is of paramount importance to me, personally and professionally, that we align our mindset and behaviors to create a culture of continuous learning, one in which individuals are just as important as outcomes. The energy transition is remaking our world, putting incredible strains on legacy assets as we feverishly work to reinforce and expand the critical infrastructure maintaining those connections and to make such infrastructure more sustainable. We’re just getting started. I know we can get there together. LESLIE M. DUKE is chair and CEO of Burns & McDonnell.

64 T&D World | March 2024

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