T&D World - February 2024

Grid Security 20 | Outage Management 24 | Sustainability 30

FEBRUARY 2024

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Line Monitoring, New York Style

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IN THIS ISSUE

Vol. 76 | No. 2

N

S 20 DEPARTMENTS

6 Global Viewpoint

The Quest for Resiliency

By TERESA HANSEN, VP of Content

14

14 Line Monitoring, New York Style TRANSMISSION MONITORING

By ALAN ETTLINGER, New York Power Authority

FEATURES 20 Unlock CIP-014 For Comprehensive Security GRID SECURITY

By MEGAN HAPPEL, POWER Engineers Inc.

30 Destination: Real Zero

SUSTAINABILITY

By MIKE BEEHLER, Mike Beehler & Associates

36 Amarillo Substation Ready for Nature

A Failure To Communicate

By GENE WOLF, Technical Writer

13 Quick Clips

ComEd Grid Plan Denial Has Leaders Re-Evaluating Investment Plans

By T&D WORLD Staff

F

46 Focus: A Lineworker’s View Meet Jeffrey Rodriguez, Evergy

By AMY FISCHBACH, Field Editor

24 Carroll EMC Reduces Outage Duration By 38% OUTAGE MANAGEMENT

By JAMES LAYTON, Carroll Electric Membership Cooperative, and JASMIN GIROUX-MALTAIS, Eaton

8 Charging Ahead

f

47 Advertising Index 48 Straight Talk

O

Virtual Power Plants: Balancing Supply and Demand

By DANIEL COHAN, Rice University

SHOW INSIGHTS FROM OUR ADVISORY BOARD

SUBSTATION UPGRADE

By PERRY FOSTER, Xcel Energy

E

ELECTRIC UTILITY OPERATIONS

40 Faces Of The Future 42 Inventing Tools to Solve Field Challenges 44 Parting Shot

Industry Experts Reveal Industries Top Topics of 2024 See page 12

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GLOBAL VIEWPOINT BY NIKKI CHANDLER, EXECUTIVE EDITOR

The Quest for Resiliency

F

ive years ago, a video went viral on social media showing transmission towers playing jump rope with the transmission lines. The video was silent but when the tower hits the ground, you would hear a thud in your head. This phenomenon is known as synesthesia, when your senses get crossed in the brain.

There is no denying that transmission lines can move (almost) like that, sound or no sound when they gallop. They don’t quite jump rope, but they can move enough to cause equipment and pole damage. The flashover from phase-to-phase contact created by the large amplitude displacement can cause burns and damage to wires.

Just this week, my home utility Evergy shared a video of galloping lines as a result of high winds during some January weather. Evergy does a wonderful job of educating customers and keeping them informed about outage restoration, sharing videos, photos and specific details on social media. Actually, our entire industry does a great job of this, as I monitor utility activity across our nation every day.

This brings me to our cover story this month. New York Power Authority is employing a cool new technology for transmission line monitoring that uses a kind of fiber-optic sensing to find conditions in real time. The technology, created by an Israel-based startup, uses existing fiber-optic ground wire that sits on top of lines to connect the ground wire to an optical interrogator in the substation. I will let you read the article to see more about how it really works. But it can identify galloping lines and icing; it looks at cable characteristics along with the correct weather conditions. The technology has other potential applications as well, such as wildfire prevention and physical security.

Let’s Talk Substations Speaking of physical security, just about everyone in our industry knows about the infamous Metcalf substation attack in 2014 when gunmen fired on a PG&E facility, causing more than $15 million worth of damage. Physical attacks on the grid in 2022 were at their highest level since 2012, as Senior Editor Jeff Postelwait discussed in his March 2023 article on physical security. Duke Energy, Puget Sound Energy and Tacoma Public Utilities were some of the bigger utilities that encountered substation attacks that year. In fact, 6

a physical attack on a substation that could cause localized outages is more likely to happen than another “Carrington” event, the large geomagnetic storm of 1859 that caused telegraph systems to fail.

After the Metcalf attack happened, NERC enacted the NERC CIP-014 standard, to “identify and protect transmission stations and transmission substations, and their associated primary control centers, that if rendered inoperable or damaged as a result of a physical attack could result in instability, uncontrolled separation, or cascading within an interconnection.” The rule was purposefully broad and vague.

After the 2022 attacks, FERC called for NERC to expand the standard’s applicability, but NERC didn’t recommend expansion. Based on available data, NERC said it found no evidence that expansion of the criteria would identify additional substations as critical.

Chris Ott, a substation security expert interviewed in this issue, contends that NERC CIP-014 can apply to all substations. He joined a utility shortly after the Metcalf attack, and quickly became the subject matter expert due to his military experience in the Marine Corps and knowledge of grid architecture. Ott shares a ranking system for substations based on the NERC CIP-014 standard, as well as how digital twin technology can help utilities be more proactive.

Nature is another “bad actor” when it comes to reliability in substations and other energy facilities. This marks the third anniversary of the Texas power crisis of 2021, when Winter Storm Uri caused an energy infrastructure failure that left 4.5 million without power. Even as I write this column, we have faced several days of below-zero wind chills here in the Midwest (causing some of those galloping lines). Since then, Entergy Texas, one of the utilities who dealt with frozen gas plants, has taken several steps to mitigate extreme cold including insulating critical equipment and piping and building permanent wind breaks.

Another Texas utility, Xcel Energy Texas, has also made upgrades since 2021. Its Amarillo service area is even more subject to brutal weather, being that it’s located in the Texas Panhandle. Xcel Energy has seen ice, wind, heavy snow, and temperature drops of 40° in a few minutes. I love substation projects, and we feature a quick read on the Farmers substation project in this issue.

The dynamic challenges faced by the energy industry, from the mesmerizing galloping lines to the ever-growing threats of physical attacks, highlight the need for innovative solutions. T&D World will continue to be the utilities’ voice in solving the problems of our industry and in doing that, hope that we will have small part in solving the world’s problems. As we commemorate the Texas power crisis and witness nature’s impact on reliability, the industry’s continuous efforts toward resilience and adaptation are evident.

T&D World | February 2024

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Energy Sector News

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CHARGING AHEAD

NEW TECHNOLOGIES & NEW OPPORTUNITIES FOR UTILITIES

BY GENE WOLF, TECHNICAL WRITER

A Failure To Communicate

I

usually don’t pay much attention to the technologies being offered to improve the consumer’s infrastructure other than watching what is going on with rooftop solar and storage. Those two residential technologies, however, are having an immense impact on the power grid. A few days ago, however, I saw several advertisements pop up on my smartphone that I could not ignore. They started off saying utilities are selling dirty electricity, which was costing the consumer, and they had the device to stop it.

I know, it was click-bait, but I had to see where this was going. They said that utilities have known about the problem and have been suppressing this technology for years to rake in huge profits. The way it was written did not give any information about the technology or how it operated. What was clearly defined, however, was that these phenomenal gizmos would save the buyer from 40% to 90% on their electric bills.

Buyer Beware It was a scam plain and simple. They threw just enough technical jargon into their hard sell that the average consumer would be hooked and buy the gadgets. So why would consumers waste money on this scam? Utilities are investing heavily on advanced technologies to improve power quality and increase their efficiency. They’re redefining the power grid, but do consumers know that?

A few months ago I read a study from J.D. Power that throws some light on that. The study reported that the commercial and industrial customer (C&I) approval ratings of their electric utility service were at an all-time low. Rising electricity prices and a perceived lack of concern on the part of the utilities were listed as the key factors for this dissatisfaction.

Utilities aren’t communicating effectively. Their message is not getting to the C&I companies or their employees. J.D. Power pointed out that some utilities are doing a really good job of connecting with their C&I customers, but most, however, are not. Better communications has to be accomplished for all levels of the utility’s customers to be effective, so let’s look at some of the positive examples.

Technology Says It All I did a quick search of upbeat news stories from electric utilities, and there were many, but for the most part they’re not covered by the news media. In today’s fast paced world, slow moving improvements take a back seat to fast changing events.

With that in mind perhaps a little more hype on the utility’s part is needed to catch the consumer’s attention.

Con Edison recently reported that its customers have installed more than 554 megawatts of solar power on their roof-

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tops. It went on to say that if these customers were linked into a utility-scale solar generator, they would be the largest producer of solar energy in the state! That is a positive story that is enjoyable and informative. The story ended with Con Edison encouraging its customers to continue these installations.

In Colorado, wildfires are an intense topic on everyone’s mind since the wildfire season now covers the entire year.

Xcel Energy got attention with its announcement that it was expanding its high-tech wildfire detection camera network across Colorado. The system integrates data sourced from state-of-the-art high-def cameras, geostationary satellites, and other data feeds, 5G connectivity, artificial intelligence (AI), and cloud-based software that actively searches for smoke from new wildfire ignitions.

Several agencies were quoted as saying the system’s early detection ability has been credited with preventing small fires from becoming wildfires.

Portland General Electric (PGE) is also applying cuttingedge and some older technologies to its system for wildfire mitigation, and it is keeping its customer base apprised. One news release said it had started a program to replace wooden power line poles with ductile iron poles in fire prone areas.

In addition, they installed about 1,000 fire-safe fuses to their power network. PGE is also expanding its wildfire detection high-def AI camera system. The report included several other mitigation efforts, which PGE pointed out would allow them to make the public-safety power shutoffs their last resort.

Everyday more grid-enhancing technologies become available and our electric utilities are busy installing them to make the power grid more stronger and more resilient.

Power quality isn’t a buzz word for the men and woman challenged with keeping the system working, but we need to keep the communications flowing. If we don’t, someone will say we are selling dirty power and they have a con ready to sell them!

T&D World | Februray 2024

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CHARGING AHEAD

BY GENE WOLF, TECHNICAL WRITER

Smart Grid’s Big-Data And Granularity As the digitalization of the power grid grows, data optimization gets more complicated.

A

s 2023 ended, it was time to reflect. In the technological world, the staggering amount of big-data being produced by digital technologies made headlines.

Globally, it was said the worldwide of new data production was over 120 zettabytes (1 zettabyte equals a trillion gigabytes) in 2023. They went on to guesstimate that over 181 zettabytes of data will be created in 2025. If you look back at the last 15 years, each year represents a steady progression from about 2 zettabytes to the 2025 estimate.

Each year’s figures are astonishing, but combining all the amounts of data generated are overwhelming, and leaves one big question. How can businesses manage all of these zettabytes in data storage and those that continue to be produced? The simple answer is big-data analytics. Fortune Business Insights reports, “The data market was valued at USD 271.83 billion in 2022. It’s projected to grow from USD 307.52 billion in 2023 to USD 745.15 billion by 2030.”

Data Impasse

The use of these sophisticated analytic tools for data management has improved the reliability and resilience of the smart grid technologies imbedded in the power delivery system, but there are issues. Big-data needs to be compatible and warehoused to make it available throughout the enterprise. Energy management systems need information from across the enterprise. It may need data from the advanced metering infrastructure, or IEDs (intelligent electronic devices) in the field, or perhaps from an integrated asset management system.

How are these big-data’s problems addressed? By using granularity rather than using methods to generalize or summarize the data. Granularity along with advanced technologies like cloud-based computing and AI are taming the explosive growth of the massive influx of big-data, but what is this granularity? Think of data granularity as a way of selecting the degree of detail present in the data tailored into convenient proportions like weeks, days, hours, minutes, or seconds.

Sometimes Smaller is Better

Big-data analytic technologies are focused around advanced software and artificial intelligence (AI) combined with various forms of data manipulation developed to examine the databases. They organize the raw data and analyze it.

They’re looking for insights within hidden patterns, varying trends, collations, and others. The goal is looking at past organized data, and combining it with present data to make better decisions without guessing.

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Another issue with data is the fact that it’s mostly unstructured. Unfortunately unstructured data doesn’t fit into pre-defined data models.

Data produced by IEDs, sensors or automated systems so common in the grid’s intelligent technologies are unstructured and are not always compatible with each other. In today’s digital world industries can’t afford not being able to work with all types of data.

That helps explain why that these markets are evolving to be more granular which is driving the need for enhanced analysis tools. This ability to process all data in any form from any part of the enterprise is being seen as an important driver in many industries. This approach is finding acceptance within the power delivery system too. As grid modernization advances, utilities need to access all of the various data, data-sets, and databases no matter format or grouping.

T&D World | Februray 2024

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CHARGING AHEAD Understanding the Data Energy demands change rapidly, and the network must respond quickly. The markets are evolving to be more granular which is driving the need for enhanced analysis tools. Seeing this need, Hitachi Energy and Google Cloud have signed an agreement to co-create multiple sophisticated software products. This would be a good point to talk with the experts working with this cutting-edge technology and tap into their understanding. “Charging Ahead” contacted Michael Hinton, Hitachi Energy’s Global Head of Energy Portfolio Management and Bret Toplyn, Hitachi Energy’s Director of Product Management to discuss how leveraging granular data will improve energy transition.

Hinton started off the discussion saying, “Power is a unique commodity in the fact it must be used as quickly as it is generated. Supply and demand have to be kept in balance, but when supply and demand are out of phase it produces significant price changes. It’s a volatile market with huge price swings even though it has moved to sub-hourly time intervals. The time granularity has gotten very small, down to 5-minute increments, and it has gotten more complicated than using only time.”

He continued, “Sub-hourly pricing wasn’t enough. They also needed the cost associated with transmission and distribution networks used to move the electricity from where it is produced to where it will be consumed. It was a case of the more information the marketplace had the more they found they needed. Hitachi Energy and Google Cloud join together to collaborate on a tool set designed to mine that information.”

Hinton explained, “Hitachi Energy’s “Velocity Suite” has about 23 years of geospatial and asset data of substation nodes along with the networks between those nodes in North America. It also has pricing components associated with these data-sets and when it’s combined, it’s an enormous amount of data. Google’s cloud-based technologies add the ability to manage large amounts of data fast and efficiently. Google Cloud’s advanced data analytics and generative AI provides a fast comprehensive analysis of the data. Its query functions are designed to quickly mine data and bring the information back fast for the customer to work with.”

Toplyn pointed out, “Granularity is exponentially impacting the problem because it can reference pricing, time, and location databases for a more complete view of the energy information. The pricing component consists of three segments, cost of energy, a congestion factor, and actual power losses associated with pathway. This data not only presents pricing information but also points out problem areas affecting prices.

It can also be utilized for planning and operating purposes.

When historical 5-minute power increments are used with geospatially like substation nodes, the points of congestion become readily apparent.”

Toplyn continued, “They can be avoided or corrected. It’s an efficient way to identify zones for investment or areas where something unseen may have happened such as a power line down. This approach can recognize larger issues, such as too

much renewable generation in regions with insufficient transmission. It really increases the understanding of where more investment is necessary or how operating procedures need to be revised to work differently.”

Hinton explained, “High prices may be caused by congestion, or low prices may be an indication of too much generation. There may even be extenuating circumstances that affect the system that haven’t been evident.

Velocity Suite provides more detail about what is actually taking place in a specific service territory. A large geographical area can be broken down into nodes for better visualization of operation. The critical information is available into what is happening on the system and how to react to it.” Hinton continued, “Velocity Suite Power Prices in the Google Cloud can extract data providing the customer a faster understanding of their assets from a planning and operational point of view. It’s the first cloud-based data management tool available from the Hitachi Energy Google Cloud partnership, but it will not be the last. There is a growing need in the marketplace for software solutions like this in the power delivery industry.”

Better Decisions with Better Technology As we have discussed, the digital technologies are producing a great deal of complex big-data data-sets each year. Managing that data efficiently is one of the most critical tasks facing industry. Utilities have more data available than ever before, and effectively managing it is necessary to get the full value out of the data with valuable insights that help make informed decisions.

Modern data management is easier, quicker, and more cost effective with big-data analytics, cloud-based computing, and advanced software. Still we need to be more adept at collecting, enhancing, and applying data to make better decisions, but that isn’t meant to be negative. We have come a long way in a short time when it comes to data administration. A few years ago companies could never have managed the enormous amounts of data we’re seeing in play within the enterprise.

Next year we’ll probably being looking back at how antiquated today’s state-of-the-art big-data analytics were compared to what would then be commonplace. The pace of technological advancement has to be mind-blowing when we see how fast we are producing zettabytes of big-data each year.

Imagine the quantum leaps that will be experienced when digital twin modeling technology is combined with the digital expertise discussed above and is integrated into automated energy management systems. What if it is included in advanced asset management platforms? Think of the infrastructure awareness that would produce and it would be in real-time.

Streamlining operations, reducing risks in reliability while being able to lower required maintenance. It sounds a little like science fiction, but digital technology never advances sequentially, so there are no breadcrumbs to follow. Advancement is always exponential. That’s why it’s exciting!

February 2024 | T&D World

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SHOW INSIGHTS FROM OUR ADVISORY BOARD BY TERESA HANSEN, VICE PRESIDENT OF CONTENT

Industry Experts Reveal Top Topics of 2024

L

ate last year, the North American Electric Reliability Corp.

(NERC) released its 2023 Long-Term Reliability Assessment.

For those familiar with the industry, the key points in the assessment should come as no surprise. The report emphasizes that the “North American bulk power system is on the cusp of large-scale growth” and raises concerns about the grid’s ability to expand to meet the expected electricity demand growth across North America in the next 10 years.

While these concerns aren’t new, there is a growing urgency to address them. At T&D World, we pride ourselves in providing content from experts with real industry experience. The people who are each day dealing with the most critical issues and challenges faced by electric utilities.

In late December, the T&D World Live conference advisory board, composed of industry experts, most of whom work for utilities, met to discuss the upcoming conference and brainstorm content ideas. During the meeting, board members delved into what they believe are some of the most important industry topics.

AMI 2.0 and Grid Edge Approximately 25% of U.S. electric meters have yet to be upgraded to smart meters, but several large utilities are already transitioning from first generation advanced metering infrastructure to AMI 2.0. The advisory board members believe this move to more advanced AMI systems is crucial for success in the energy transition. AMI 2.0 provides detailed, real-time usage information, allowing utilities to better understand what is happening at the grid edge. Having knowledge about installed distributed energy resources like residential customers’ EV charging and rooftop solar installations allows better decision making during short and long-range planning.

Battery Storage Growth The board anticipates an increase in battery storage connected to the grid, not only for grid support but also for added capacity. The latest Energy Information Administration’s Short-Term Energy Outlook confirms their thoughts by predicting an increase of more than 30 GW in U.S. battery capacity by the end

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of 2024. California and Texas currently lead in installed battery capacity, driven by the rapid growth of solar and wind power in these states.

Black Sky Hazards Reliability and resiliency, especially related to storm response, sparked significant discussion. Advisory board members emphasized the need to improve storm preparedness, restoration processes, and forecasting ability, particularly given the increase in the severity of weather events. Microclimates, small areas with distinct climates, were also deemed worthy of greater attention.

AI, Machine Learning, and Generative AI The importance of artificial intelligence (AI) and machine learning is growing, and board members discussed the convergence of the two, along with numerous industry use cases. They also stressed the need for utilities to embrace generative AI safely and effectively, addressing cybersecurity threats and ensuring employees understand its potential and risks.

DER Interconnection and Standards As aggregated DER programs gain traction, the need for standards becomes urgent. Board members emphasized the importance of preparing for FERC Order 2222, centered around DER integration, set to be implemented in 2026. They stressed the urgent need to prepare.

Other Important Topics in 2024 • The necessity for reforms in rate structures to incentivize grid investment.

• The rise in organizational changes driven by industry transformations, influencing utilities to reconsider their organizational structure and management.

If you’re interested in keeping up with what the T&D World Advisory Board has planned for the 2024 conference, hearing from the industry experts who will be speaking, and learning more about the topics that will be covered, be sure to read this new, regular column that will be featured monthly.

1/19/2024 3:41:41 PM

QUICK CLIPS

BY T&D WORLD STAFF

COMED GRID PLAN DENIAL HAS LEADERS RE-EVALUATING INVESTMENT PLANS Leaders of Exelon Corp. say they are looking at trimming the 2024 investment plans of their Commonwealth Edison Co. subsidiary after Illinois regulators rejected ComEd’s multi-year grid plan and issued an order in the utility’s 2024-2027 rate case that, because of the grid plan denial, approved only about one-third of the company’s requested $1.5 billion in rate increases over four years.

In turning away ComEd’s grid plan (as well as that of Ameren Illinois) by a 4-1 vote, the Illinois Commerce Commission said the utility’s forecast did not comply with parts of the state’s Climate and Equitable Jobs Act, which calls for Illinois to move to a completely carbon-free power sector by 2045.

“Specifically, the Commission’s decisions found that both utilities failed to sufficiently incorporate customer affordability into their proposals and their grid plans did not outline how 40% of plan benefits will be directed to low-income and environmental justice communities, among other shortcomings,” the ICC said in a statement.

In a filing with the U.S. Securities and Exchange Commission, Exelon executives said they are appealing the ICC’s order, laying the foundation for regulators to respond in the first few weeks of next year. They also noted that they’ll need to prune ComEd’s plans in response to this first ruling. “ComEd will be evaluating its operational and investment plan in 2024 in light of the final order, while maintaining a safe and reliable grid,” the SEC filing said.

In their most recent presentation to investors, Exelon leaders estimated that ComEd—which accounts for 37% of Exelon’s rate base—would spend $2.55 billion on capital projects in 2024, in line with this year’s total. A little more than $2 billion of that figure is set to go toward distribution projects while the remainder is earmarked for transmission work.

Early forecasts call for ComEd’s capex to grow substantially in coming years, to more than $2.9 billion in 2025 and $3.1 billion the year after. It’s not clear how drastically those figures might change because of the ongoing rate and grid plan cases: ComEd officials and their attorneys on Dec. 22 filed an application to have the rate case quickly reheard, claiming that the ICC must “correct serious and fundamental legal and evidentiary errors” in their decision from earlier this month.

ComEd is asking commissioners to revisit several points, including that the rate case order sets an unrealistically low return-on-equity target for ComEd, in part because it used a discounted cash flow model “inconsistent with Commission practice and contrary to the record.” Another point of contention

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is that the grid plan denial is sidelining all investments above the company’s 2022 year-end rate base.

“This is a drastic outcome, and one not supported by the record or consistent with the law,” ComEd’s application says.

“Indeed, parties differed on some programs and investments as might be expected, but no party argued or ever suggested that the Grid Plan should be outright rejected.”

The ICC’s decision requires ComEd and Ameren officials to file new grid plans by mid-March. If the ICC approves those, commissioners also will be able to revisit their rate plan decisions, which today include the impact of not being able to make (and then recover) grid investments. —Geert de Lombaerde

ABB BREAKS GROUND ON ALBUQUERQUE

FACTORY FOR UNDERGROUNDING, GRID HARDENING GEAR

ABB Installation Products broke ground on its new manufacturing facility in Albuquerque, New Mexico to meet increased demand for ABB’s Elastimold cable accessory solutions used to improve grid hardening and help power millions of homes, businesses and communities.

The more than $40 million investment, announced earlier this year by ABB Installation Products, formerly Thomas & Betts, further strengthens ABB’s US manufacturing footprint with inventory for electric utility, renewable energy and distribution partners globally. ABB’s 90,000-square-foot greenfield facility is expected to begin operations in late 2024 to produce Elastimold cable accessories and solutions.

The site will also integrate ABB robotics technology, digital operations and a Center of Excellence to support job training, customer collaboration and advanced research and development.

ABB Installation Products currently employs more than 450 associates in Albuquerque who develop, test and produce a broad range of custom and standard utility solutions at its existing site on the 40-acre campus at 6625 Bluewater Rd NW. Building the additional facility on the campus furthers ABB’s strategy to develop technology, equipment, materials and installation methods that enable utilities to protect and improve the capacity and reliability of electrical systems.

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Line Monitoring , N

Drone view of the Princetown substation on the Central East Energy Connect transmission line.

Photo by Philip Kamrass | New York Power Authority.

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g , New York Style NYPA uses fiber-optic sensing, based on the principles of distributed acoustic sensing, to identify power line conditions in real time.

By ALAN ETTLINGER, New York Power Authority

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uring frigid days and pop-up winter storms, electricity demand can rise precipitously, with brutal and hazardous ambient weather conditions and congestion on transmission circuits to specific nodes. Loads can increase rapidly in regions under these conditions. For example, during winter storm Elliott in December 2022, temperatures dropped 30 degrees in a matter of hours in Denver, Colorado; the freezing line dropped as far south as Mobile Bay, Alabama, which partially froze; and Mount Washington in New Hampshire experienced a 151-mph (243-kmph) wind gust.

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TRANSMISSION MONITORING

View of CCRT 21/04 of the NYPA-owned 345 KV transmission system at Route 209 near Otisville, looking west. Photo by Philip Kamrass | New York Power Authority.

Foliage along completed work on the Central East Energy Connect (CEEC) high voltage transmission line, near Route 30 and Route 141 (Merry Lane). Photo by Philip Kamrass | New York Power Authority.

Events such as Elliott mean utilities must place a high importance on knowing the condition of transmission conductors, which are always susceptible to axial, bending moment and shear stresses as well as causing or experiencing cascading power failures. Even when generation resources remain online — which is often not the case, especially with natural gas-fueled units — ice and snow accretions can cause transmission lines to sag or a break in a line, or they can bend the transmission towers on both sides, taking a good portion of the network with them. Once faults or damages occur, they can take hours or days to resolve. Even short-duration power outages can impact the

public’s comfort, health and ability to work, especially in the postCOVID work-from-home era. Moreover, extended outages can cause substantial individual monetary and business loss, larger economic impacts and negative health-related consequences.

There is more of this weather to come. A recent National Oceanic and Atmospheric Administration (NOAA) study by its Modeling, Analysis, Predictions, and Projections (MAPP) program determined that “weaker Arctic polar vortex conditions and stretching disruptions are increasing in frequency for October through February” in the U.S. In the tight grid conditions that often occur during such events, utilities may need to deenergize conductors or even suffer failures, potentially causing blackouts across large areas in bitter cold. This is a major challenge for utilities that own and maintain transmission infrastructure.

Given so many recent occurrences of what used to be referred to as 100and even 1000-year weather events, it is important to consider how cold winters, a common occurrence in Upstate New York, may adversely affect the reliability of an already stressed and congested grid. In the face of these unprecedented challenges, the New York Power Authority (NYPA), the largest state public power organization in the U.S., launched its VISION2030 strategic plan to help lead the transition to a carbon-free, economically vibrant New York through customer partnerView of NYPA-owned transmission lines and a substation of the 345 KV transmission system, at Dolson Avenue.

Photo by Philip Kamrass | New York Power Authority. ships, innovative energy solutions and

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TRANSMISSION MONITORING the responsible supply of affordable, clean and reliable electricity. NYPA works with technology partners to modernize and harden its transmission assets while maximizing existing grid capacity to accelerate the path to a carbon-free grid.

Transmission Line Health Selected as the winner of the competitive 2021 NYPA & Israel Smart Energy Challenge, one example of that emerging technology exploration is NYPA’s work with Prisma Photonics, a Tel Avivbased company that offers power grid monitoring and preventive solutions that use a specific type of fiber-optic The dashboard designates a specific color for each span, marking those with a high risk of icing in red and sensing — called Hyper-Scan Fiber- orange based on the threshold set by the user. An ice icon indicates a significant potential for icing. By clicking Sensing — based on the principles of on the map, users can view details and the location of each span. On the left panel, there is a timeline display showing the progression of ice accumulation. Graphic by NYPA. distributed acoustic sensing (DAS).

This technology identifies power line conditions in real time, and analyzes signals from the fiber to sense what is happening detecting potential threats to the system, including weather on power lines. The analyzer detects and classifies events, pinconditions, electrical faults and even sabotage by human activity points them to individual tower locations with unprecedented accuracy and avoids the nuisance of false alarms.​ in proximity to towers.

The Hyper-Scan Fiber-Sensing system uses existing fiber-optic The interrogator transmits optical pulses that propagate ground wire (OPGW) that sits on top of power lines, connecting down the fiber, reflecting a minute fraction of light along each the ground wire to an optical interrogator that sits in a substation point by taking advantage of a physical phenomenon called

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TRANSMISSION MONITORING

Utilities must place a high importance on knowing the condition of transmission conductors, which are always susceptible to axial, bending moment and shear stresses as well as causing or experiencing cascading power failures.

Photo by NYPA.

Rayleigh scattering, the dispersion of electromagnetic radiation by particles that have a radius less than approximately one-tenth the wavelength of the radiation. The interrogator then measures the reflected light to determine the line attributes over hundreds of miles.

Beginning in the winter of 2021, NYPA embarked on a project with Prisma Photonics using its PrismaPower technology to monitor the transmission line from a substation in Gilboa, New York, to another substation in Fraser, New York, climbing the Catskill Mountains for more than 35 miles (56 km). Due to its position, this line experiences a wide range of weather conditions, including especially harsh winters with very cold temperatures, significant snowfall and powerful winds.

This initiative provides NYPA with a tool to identify specific problems before they become serious and enables the utility to plan preventive maintenance, improving both grid reliability

Niagara Falls frozen over in winter. NYPA was granted permission to develop the falls’ hydroelectricity capacity by act of Congress in 1957. Photo by NYPA.

and resilience. To this end, PrismaPower can identify a power line’s health at granular levels, including in weather-related conditions such as line galloping, sagging and high winds. It also identifies potentially catastrophic events, including flashovers, short circuits, partial discharges, vegetation strikes, and even tower climbing and vandalism.

Perhaps most importantly, this technology does not require adding extra sensors to the transmission infrastructure or any amplification or power sources along the fiber.

For nearly two years, Prisma Photonics collected data in the Upstate New York region over rugged mountains, through thick forests, and in the most extreme heat and cold. This data collection has allowed for deep comparative analysis, making it possible to see the effects that different weather conditions have on the grid.

For example, during the project, hits from all types of anomalistic behaviors were detected and identified on specific power line towers. Simulated sabotage events, such as tower climbing carried out by linemen, were detected as well, pointing to a specific tower.

From a preventive maintenance perspective, long-term analysis was performed to locate and create a threshold mechanism to identify high partial-discharge levels in specific towers. Towers with high partial-discharge levels can be treated separately before the matter becomes more serious (for example, by insulator washing or replacements). In the future, this analysis can help with optimizing maintenance by handling the needed towers.

Detecting Ice Perhaps most important to NYPA’s efforts to deliver reliable service in areas of New York that get extremely cold is Prisma Photonics’ ability to detect icing on line spans. Data captured directly from the lines through fiber sensing was correlated with weather information.

When cable tension in a specific span is high along with the right weather conditions (for instance, low temperatures and high precipitation), this is a good indicator of icing. In an icing dashboard, spans with suspected high icing loads are presented on a map and, by picking them, tower data can be seen. Having real-time notification of icing alerts enables NYPA to act and correct the situation before any damage is done to the asset.

The icing dashboard uses color coding to show different tensions and sagging of line segments. Spans suspected of icing are identified and marked for follow up. They can be analyzed using data captured on the wire itself. Picking one of the suspected spans, the operator can see the relevant location and geographical data of that specific span (for example, identification, length, elevation and estimation of the average weight per meter on the span).

By setting thresholds on the dashboard, deeper analysis can be used to better isolate problem spans and make correlations with information from other sources, such as ground patrols or cameras.

In addition to the work NYPA is doing on icing, there are, of course, considerably more benefits that can be realized with large-scale, continuous monitoring of power lines. The utility

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TRANSMISSION MONITORING can use the technology to detect wildfires, high winds and other extreme weather events that can affect the reliability of the grid.

Ongoing Innovation Using technology to monitor power lines is not new. Many transmission system operators (TSOs) have deployed fixed cameras as well as thermal, corona, light detection and ranging, and regular photographic sensors on high-voltage lines. Others have used helicopters, drones and human inspection, or a combination of these options. However, these technologies are limited in their ability to scale, and there is a low frequency and level of detail at which they can measure the condition and performance of conductors.

This effort plays an integral role in supporting one of NYPA’s five strategic priorities in New York’s energy transformation: to be the leading transmission developer, owner and operator in the state of New York. NYPA owns, operates and maintains 1460 circuit-miles of the transmission grid, managing this system continually feeding energy from power plants and renewable energy resources to distribution centers and consumers. A reliable grid is essential to everyone’s daily lives and typically operates in the background. Too often, it is taken for granted until it stops working. Once electric service stops, it disrupts people’s lives in ways that can range from annoying to life-threatening.

Strengthening transmission serves NYPA’s goals in battling climate change and ensuring environmental justice in communities across the state, integrating an environmental, social and governance framework into the utility’s DNA, and expanding

Many transmission system operators have deployed fixed cameras as well as thermal, corona, light detection and ranging, and regular photographic sensors on high-voltage lines. Others have used helicopters, drones and human inspection, or a combination of these options. Photo by NYPA.

its sustainability efforts to achieve better results. The utility is working tirelessly to address these challenges and embrace opportunities as it helps New Yorkers to meet the state’s climate goals, while providing ratepayers with the most reliable, resilient and affordable grid possible.

ALAN ETTLINGER, P.E., is senior director of research, technology development and innovation at New York Power Authority.

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GRID SECURITY

As substation attacks continue, utilities of all sizes are considering their options to protect the grid from malicious individuals and organizations Photo 1483614 © Chris Hellyar | Dreamstime.com

Unlock CIP-014 For Comprehensive Security Although NERC CIP-014 applies to critical infrastructure, it has great value as a foundation for building resiliency plans for all substations.

By MEGAN HAPPEL, POWER Engineers Inc.

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he North American Electric Reliability Corporation Critical Infrastructure Protection standards govern the critical infrastructure of all entities that materially impact the reliability of the bulk electric system. The goal of the Critical Infrastructure Protection (CIP) standards is to ensure appropriate security controls are in place to protect the bulk electric system, along with its users and customers, from threats that could impact the system’s timely and effective functioning.

These threats may include cyberattacks and physical attacks.

The North American Electric Reliability Corporation (NERC) CIP-014 standard, in particular, was developed to protect transmission stations, substations and their associated primary control centers from physical attacks. If these critical assets were rendered inoperable or damaged because of a physical attack, widespread instability, uncontrolled separation or cascading failure within

an interconnection could cut power to millions of users. CIP-014 aims to prevent this by identifying the transmission substations with the greatest need for protection — that is, the substations that would cause the most issues if they failed.

“However, the value of this standard goes beyond keeping critical assets secure,” said Chris Ott, physical substation security expert at POWER Engineers Inc. “Those responsible for infrastructure outside of CIP-014’s jurisdiction would do well to adopt these security requirements for their out-of-scope systems, too.”

While the standard recognizes which assets are most critical, its language on substation security is intentionally vague so as not to give bad actors hints on how to navigate around security systems. However, that ambiguity leads to gaps regarding which substations are considered critical. For example, energy customers like the U.S. Department of Defense, law enforcement,

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GRID SECURITY

Line of sight is used to detect vulnerabilities. Graphic by POWER Engineers, Inc.

big tech companies, and medical and health care facilities fall outside of the standard’s criteria — yet no one would argue they are critical utility customers that need reliable power.

Unidentified Infrastructure Regardless of how they are classified, substations with smaller load capacity or lower voltage can adopt the practices CIP-014 requires for critical assets. The criteria may not be exactly the same, but utilities can use CIP-014 to create a risk identification and mitigation strategy.

The NERC CIP compliance standards rate substations deemed critical on a scale of low, medium and high, but an expanded

ranking could be applied to substations that fall outside of the standard. Ott of POWER Engineers suggests utilities create five evaluation tiers, applying 1 to the most critical locations and 5 to the least critical. These rankings could be based on factors such as potential lost revenue, outage restoration times, replacement asset availability, public safety, types of customers and public relations mitigation.

For example, a substation that feeds a hospital, a sheriff’s department and a big tech customer could be considered a highly critical location from a lost-revenue and service-needs standpoint. Likewise, a location with multiple transformers that have yearslong lead times for replacement might be given a higher

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YOUR WORLD IN REAL TIME. RTDS.COM

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GRID SECURITY noted. “Because of my military experience and knowledge of how grid architecture and infrastructure worked, I became the subject matter expert of that standard for the company.”

Digital Twin Technology According to Ott, some of the most promising physical substation security solutions in recent years stem from 3-D modeling technology.

“Digital twin technology is a game changer for security,” Ott said. “By identifying the line of sight that bad actors might use to cause damage, you can build exactly what’s needed, where it is needed.”

A digital twin, or a 3-D virtual repA 3-D generated digital twin. A digital twin, or a 3-D virtual representation of a substation, is a highly accurate tool for finding line of sight. Graphic by POWER Engineers, Inc. resentation of a substation, is a highly ranking, or priority, than other substations and, therefore, would accurate tool for finding line of sight. have its security evaluated earlier. Ranking substations in this “We map out the substation and the surrounding terrain way enables utilities to address security concerns at all relevant using geospatial technology and reconstruct it in a virtual reallocations systematically. ity environment within a game engine,” Ott explained. “This interactive model then helps us identify the locations outside of the substation where critical assets are visible. We can then Destruction Can Inform Security Ott applied a five-tiered scale to assets at his former utility, manipulate the number, size and location of barriers or other just one tactic he employed to make the substations more mitigation tactics to test our clients’ assumptions and see exsecure. Others he developed by drawing on his 20 years of actly which changes will be the most effective and efficient in blocking line of sight before we build.” experience, which began in the military.

“My original job in the Marine Corps was to provide power generation and distribution for field expedient camps,” he recalled. “Later, I volunteered for a unit that did experimental war game exercises.

This unit brought together a variety of experts who used their expertise for mission planning in both real and theoretical cases. For each one, we had to analyze variable locations, infrastructure types and military asset availability before deciding on the most appropriate method to cripple the infrastructure. I was the expert in power distribution.”

After Ott left the military, he received an electronics engineering degree, worked as a security system design implementation contractor for many years and eventually found himself at a utility where he became immersed in the commercial utility space.

“I joined that utility shortly after the Metcalf substation attack in 2013, around the time when the CIP-014 A substation in Austria at night. Utilities should take a calculated and educated approach to mitigations to find standard was first announced,” Ott the most acceptable balance between security and cost. Photo 262839930 © Wolfgang Spitzbart | Dreamstime.com 22 T&D World | February 2024

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GRID SECURITY In addition to testing the effectiveness of solutions like barriers and landscape alterations, digital twins also can be used to place cameras in and around the perimeter of a substation. The same game engine can help to map out the line of sight of the cameras and identify potential blind spots before they are installed.

Ott describes the experience of viewing a digital twin as similar to that of playing a first-person video game. The user can explore the virtual space freely by moving to view the substation from different angles and distances, as if they were a character in a game. This feature is especially useful when it comes to greenfield substation projects, as users can view and evaluate a substation that does not exist yet through the lens of virtual reality. Brownfield substation projects can benefit from digital twin technology, too, since the technology can be used to virtually manipulate and test the environment without involving real-world materials or build time. It is a revolutionary way to identify and solve vulnerabilities.

That being said, vulnerabilities can change as bad actors find new ways to achieve their goals, which is why “you can’t forget to test your mitigations,” Ott said. “Whether it be a mock attack or a reevaluation of the property after mitigations are in place, you need to check your work, and you need to check it routinely.

Find a trusted and credentialed organization that understands power delivery and where failure points could reside. Hire them to discover your vulnerabilities before a bad actor does.”

Spend Only What’s Needed

By building only what is needed, utilities can reduce construction and engineering costs without sacrificing security.

“I worked on a pilot project that replicated and showed mitigations in this technology,” Ott recalled. “Just the pilot saved the company anywhere between $12 million and $13 million because we were able to try out various mitigations and send them to the engineering staff who were able to identify the most cost-effective solution out of the options depicted — without ever breaking ground. This is a huge and viable way to save money.”

Looking Ahead “Unfortunately, the world is not getting safer,” Ott observed.

“The grid is aging and utilities are looking for the best-cost solutions for solving this problem.”

Although CIP-014 applies to critical infrastructure, it has great value as a foundation for building resiliency plans for all substations. As substation attacks continue, utilities of all sizes are considering their options to protect the grid from malicious individuals and organizations. Using technology like digital twins is one way to stay one step ahead of the bad guys.

MEGAN HAPPEL (megan.happel@powereng.com) is a content developer, writer and editor for POWER Engineers. She specializes in transforming complex engineering projects into concise, relevant content for a wide variety of audiences and channels. She holds both a bachelor’s degree in engineering management and a bachelor’s degree in scientific and technical communication from Michigan Technological University.

Not every malicious individual with a firearm can land a successful series of rounds on a target past 500 yards (457 m). The experience and training necessary to be reliably accurate at long ranges is expensive, which limits how many people are capable of causing damage from that distance. However, this does not mean the threat is nonexistent. Substation attacks are continuing to happen, and while the cost to completely eliminate line of sight at smaller substations is not always feasible, for many, it could be the very thing that prevents a catastrophe.

“It’s better to pay for security upfront,” Ott noted, “because if you don’t pay for it now, you’ll end up paying more for it later.”

The December 2022 attack on two Duke Energy substations in North Carolina caused millions of dollars in damages and left tens of thousands of people without power for the better part of a week. Around the same time, another attack targeted four Washington substations, with two of the substations reporting a combined US$3 million in damages and an estimated 36-month period to complete repairs. There has been a disturbing rise in the number of substation attacks, and even a small substation could be the next target. Especially if they are not protected. Utilities should take a calculated and educated approach to mitigations to find the most acceptable balance between security and cost.

“Using a digital twin replication model can significantly reduce the build cost of security-related mitigation,” Ott said. “I’d go as far as to say that it would only cost fractions of a penny on the dollar to use a digital twin to test these mitigations compared to what it would cost to test them in real life. In fact, it has been proven to save significant money overall.”

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OUTAGE MANAGEMENT

The first phase of Carroll EMC’s feeder automation deployment was focused across its three-phase distribution network and included Eaton’s Form 6 reclosers (pictured at Eaton’s Experience Center in Pittsburgh, Pennsylvania). Photo by Eaton

Carroll EMC Reduces Outage Duration By 38% The Georgia electric cooperative deploys fault location, isolation and service restoration across its single- and three-phase lines.

By JAMES LAYTON, Carroll Electric Membership Cooperative, and JASMIN GIROUX-MALTAIS, Eaton

R

educing the impact of power outages is increasingly complex. Electricity demand is soaring. Energy resources are becoming more distributed. Extreme weather events are more common and less predictable. More than ever, intelligent grid automation is vital to improve grid service.

The U.S. Energy Information Administration (EIA) projects American power demand will rise to an unprecedented 4067 billion kWh in 2024 as economic growth and electrification continue. At the same time, the EIA reports climate change is causing more frequent and intense heat waves, droughts and downpours, and the average duration of a power outage in the U.S. grew from approximately 3.5 hours in 2013 to more than seven hours in 2021.

Establishing a fault location, isolation and service restoration (FLISR) system turns sustained outages into momentary ones. Using feeder automation software, utilities are leveraging real-time data to detect distribution system disturbances and

automatically reconfiguring their system for significant reliability improvements. Carroll Electric Membership Corp. (EMC) in western Georgia can attest to the benefits of feeder automation technology. Every dollar it invested in grid automation software has helped to continually reduce outage durations for the members it serves.

Following the success of its three-phase automation projects, the utility is applying the proven model to its single-phase network to set a new standard for a smarter, healthier grid.

The utility’s long-term FLISR system, including software and electronic devices, is supporting a remarkable 38% reduction in outage durations. The utility anticipates an even greater reduction over time.

A Successful Strategy Carroll EMC distributes approximately 1 billion kilowatt-hours of electricity annually across seven counties, 54,000 accounts,

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OUTAGE MANAGEMENT 5500 miles (8851 km) of distribution line and 25 distribution substations.

The utility’s electric distribution system is designed, constructed, maintained and operated to maximize reliability at a reasonable cost for customers.

However, with a quickly growing membership and expansive service area, it became a difficult and time-consuming process to manually respond to system outages.

The electric cooperative sought to deploy a FLISR system to minimize the impact of grid interruptions. One of the utility’s primary goals was to implement a feeder automaton solution that would give it complete management over control schemes, so it could easily adjust the system to grow alongside the needs of its infrastructure. To reduce complexity and costs, Carroll EMC quickly saw dramatic reliability improvements with Eaton’s feeder automation software, part of the the co-op needed the grid automation Brightlayer Utilities suite. Eaton’s Experience Centers, which provide industry education and training, show how feeder automation works during storms to reduce impact of outages. Photo by Eaton. technology to operate seamlessly with its legacy equipment from many different manufacturers. intelligent and automated approach to a portion of its singleCarroll EMC’s strategy was to focus first on its three-phase feed- phase lines located in residential areas to further reduce outages. ers, which contributed significantly to overall outage durations The project kicked off in 2012 and the first two phases foacross the utility’s network. Next, the co-op would expand this cused on the three-phase network, including the installation of

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OUTAGE MANAGEMENT Overall, the utility’s strategy is paying off, and it is minimizing the number of members impacted during an outage and preventing entire neighborhoods from going dark. Since the start of its distribution automation program, Carroll EMC has continually reduced its system average interruption duration index (SAIDI) year-over-year. The utility anticipates a 41% reduction in outage duration, including a 34% reduction from the three-phase deployment and an additional 7% reduction from the single-phase project.

In 2022 alone, Carroll EMC calculated the feeder automation solution reduced outage time by about 75 minutes for members.

Streamlined Management

Carroll EMC’s service territory within western Georgia. Graphic by Carroll EMC.

192 intelligent devices. The third phase addressing single-phase automation began in 2021 and continued into 2023, with about 60 intelligent devices installed. To date, nearly 250 intelligent electronic devices have been deployed across the utility’s network, working with the Eaton feeder automation software to automatically isolate damaged sections and restore power to as many people as possible.

In the past, the co-op required an entire crew of personnel to manually isolate an impacted circuit and restore service. With the feeder automation platform, all stages of the outage isolation process are now completed automatically from a central location, transforming Carroll EMC’s approach to managing outages and improving service for members.

Carroll EMC is realizing powerful benefits from the feeder automation platform that go far beyond advanced outage response and management. It also uses the software to do the following: • Quickly detect and isolate faults, so unaffected load sections can be restored by feeders • Automatically detect loss of voltage situations, so impacted line sections can be isolated from the feeder and unaffected sections can be restored

SEDIVER SERVICES On the field pollution assessment

West Memphis laboratory

BY YOUR SIDE THROUGHOUT YOUR LINE’S LIFECYCLE Sediver’s experts provide world-class support covering every stage of line design and operation: • Selecting best solutions, optimizing insulator configuration, providing accurate in-service diagnostics • Field and lab assessments on insulators, thanks to our worldwide network of labs • Aging and pollution assessments in all conditions • Customized insulator solutions • Dedicated quality programs

E-field simulation

• Training courses and joint research programs adressing line design or performance issues

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OUTAGE MANAGEMENT • Continuously monitor and track historical loading on the system to prevent overload events • Easily add and remove devices using a standardized interface without the need to reprogram reconfiguration algorithms.

Additionally, a simulator, communications dashboard and post-event reporting capability are built into the platform to help Carroll EMC turn distribution automation into an integrated process driven by real-time data. These robust, standardized tools empower the utility’s engineers to easily change automation settings in minutes rather than months by eliminating costly custom programming and trial-and-error debugging.

Further, the software platform maintains a complete log of each device operation and changes in device status. During any event, the steps are traced through each automation logic decision with supporting preprogrammed logic comments for actions based on available data. All entries are timeand date-stamped and can be synchronized with device sequence-of-event records.

It is vital the utility fully understands the events that occur across its electric distribution system to continually improve the quality of service. This detailed event logging enables staff to easily investigate and audit events that occur across the entire service area from one centralized location, which mitigates the need for personnel to expend valuable time and labor performing field investigations.

To avoid these issues, Carroll EMC recommends utilities prioritize distribution automation solutions that support the easy addition and removal of intelligent devices using a standardized interface without reprogramming of reconfiguration algorithms. By using these interoperable platforms, the number of sources and switching devices that can be automated is only limited by the physical load flows of the power system and communications infrastructure.

Additionally, interoperable distribution automation solutions allow for virtually any existing control, using a standard communications protocol to be integrated into automation systems, eliminating the need for additional hardware or protocol converters.

Flexibility, Scalability, Interoperability Carroll EMC values the flexible and scalable architecture of Eaton’s FLISR system, which simplifies integration and improves system performance. Additionally, the feeder automation software can operate both integrated with or completely independent from the supervisory control and data acquisition (SCADA) system, which enables Carroll EMC to upgrade its legacy SCADA system independently, without impacting its ability to reduce outage times during the transition period.

Many distribution automation solutions have limited functionality or require complex third-party engineering. Following installation, these systems are often difficult to modify because of limited configurability or the need to contract with the original engineering vendor. As a result, both vendors and utilities tend to approach feeder reconfiguration as a project rather than an integrated process.

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OUTAGE MANAGEMENT This feature, alongside compatibility with existing legacy controls and the next generation of controls, can help utilities to meet requirements today and challenges tomorrow — with the added ability to expand feeder automation programs across single- and three-phase lines seamlessly.

A More Intelligent Future

a foundation of grid intelligence.

Utilities across the U.S. are prioritizing investments in modern automation capabilities that help to balance the grid, reduce interruption frequency and duration and remotely isolate and manage faults. Working closely with utilities, industry suppliers are helping to set the stage for success by developing creative, interoperable smart grid technologies that drive operational efficiency and simplify resilience.

Today, there is an enormous opportunity to transform U.S. distribution networks to support an increasingly electrified world with far more reliable power.

As extreme weather and natural JASMIN GIROUX-MALTAIS is an electrical disasters reach new extremes, there engineer with more than a decade of experience will be more service interruptions and in delivering intelligent automation solutions safety concerns for the utility workers to customers in Canada, the U.S. and Europe. who need to repair or replace equip- Transformer. pictured at Eaton’s Experience Center in Pitts- Giroux-Maltais is a product manager at Eaton. ment. And as the world electrifies, the burgh, Pennsylvania. Interoperable distribution automation solutions allow for virtually any existing control using a standard importance of maintaining a resilient communications protocol to be integrated into automation sys- JAMES LAYTON is an electrical engineer, serving tems, eliminating the need for additional hardware or protocol as vice president of engineering and technolenergy supply only grows.

The distribution network can work converters. Photo by Eaton. ogy at Carroll Electric Membership Cooperative. harder and do more to power an electrified, resilient future. With nearly two decades of experience, he has played a pivotal role in implementing Limiting the repercussions and frequency of grid outages is a innovative technologies and solutions to enhance the reliability and sustainability of the major step in this journey that can be simplified by establishing co-op’s electric grid that powers more than 55,000 homes and businesses.

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SUSTAINABILITY

A model of an electrical substation. Net zero or real zero energy by 2050 has dramatic implications on the current planning, design, operations and maintenance of the electric transmission and distribution grid that delivers that energy. Photo 6794713 © Pavel Losevsky | Dreamstime.com.

Destination: Real Zero How the power sector can reach net zero and eventually real zero carbon content, and how the transmission and distribution grid can help deliver on these goals.

By MIKE BEEHLER, Mike Beehler & Associates

R

egulators, politicians and customers seem to be reaching a consensus. The future of electricity will have a net zero, and eventually, real zero carbon content. We could get there perhaps even by 2050.

There are many ways to measure these goals, so definitions are important. Net zero energy is defined as the generation of electricity from non-carbon generating resources like nuclear, hydro, wind and solar with allowances for government approved offsets and credits. Real zero energy does not include the offsets and credits. Net zero or real zero energy by 2050 has dramatic implications on the current planning, design, operations and maintenance of the electric transmission and distribution grid that delivers our energy.

Aiming for 2050 Real zero energy will be achieved alongside massive electrification of mobility, space conditioning and commercial and

industrial (C&I) processes. Some predict doubling or tripling the current national peak generating capacity of 1.3 million MW. Substation and telecommunications equipment must be upgraded in capacity and capability to support massive electrification. We will need underground distribution for the reliability and resilience needed for small scale distributed energy resources (DER) that support massive electrification.

Real zero energy will require new nuclear and existing big hydro to provide base load spinning mass for system stability and some degree of fast generation ramping with hydro and pumped storage where available. Otherwise, ramping will be conducted with new and existing high efficiency natural gas turbines.

This will require upgrades for existing transmission capacity to support the new nuclear, huge amounts of remote utility-scale renewables, and existing big hydro. Transmission capacity will be developed using existing rights of way with dynamic line rating (DLR), advanced composite conductors, and high voltage

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SUSTAINABILITY direct current (HVDC) conversions.

We can also leverage new “wild card” technology toward this goal. Artificial intelligence (AI) may plan and design the T&D system. Sensors on everything will provide a rich, secure data source for AI algorithms that efficiently deliver the cleanest and most affordable source of generation while enhancing safety, reliability and resiliency of the grid. Advancements in material sciences will lead to superior storage media, working fuel cells, 3D design and printing, robots and more.

Massive Electrification Electrifying the economy claims many benefits. Electrification brings communities economic development, better transportation and emerging tech- A technician plugs a network cable into a line socket. A robust, private broadband network will help electric nologies across a broad spectrum of utilities build and maintain a real zero T&D grid in the years approaching 2050. Photo 87709088 © poonsak pornnatwuttikul | Dreamstime.com. services. Electricity is safe, with design codes and best practices established. Electricity is reliable. Across U.S. has nearly 1.3 million MW of generation capacity, according the U.S., the power grid is 99.97% reliable, according to the to the American Public Power Association (APPA). The largest Galvin Electricity Initiative. Electricity is relatively inexpensive. fuel source for this capacity is natural gas (43.9%), followed by According to the U.S .Commerce Department, electricity rep- coal (17%). Wind, nuclear, and hydro together account for more resents less than 2% of annual household spending. than one-third of capacity and solar has added than 38,000 Finally, electricity is getting cleaner. As of February 2023, the MW since 2020.

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SUSTAINABILITY

An electric substation located in the FPL service terriotry. Urban open-air substations that occupy all the available real estate must be converted to gas insulated switchgear (GIS) substations. Photo courtesy of Mike Beehler.

overhead lines including reduced vulnerability to weather events like floods, lightning, hurricanes and wildfires. By eliminating the impact of future fires, storm conditions and reducing other potential outages caused by falling tree limbs or vegetation contact, car struck poles, birds and rodents, mylar balloon impacts, ground line wood rot and others, undergrounding contributes to a much more reliable and resilient electric grid.

The industry defines reliability with outage duration and frequency while resilience is defined as the ability to withstand a high impact, low probability (HILP) event with little or no customer outage. Reliability is measured in outage minutes and resilience is typically measured in days. Undergrounding provides a much more resilient system and is the level of performance that real zero energy will require.

Substations and Communications

More Power

Substations will need to be bigger and telecommunications more robust.

Data scientists, engineers and planners must prioritize and schedule the upgrade and doubling of capacity of existing and future substations and strongly consider building a private broadband telecommunications network with a dedicated utility spectrum.

Urban open-air substations that occupy all the available real estate must be converted to gas insulated switchgear (GIS) substations and suburban or rural substations with adequate real estate must have their ultimate build-out doubled in scope. Installing gates and fences, ground grids, conduit systems, control house structures and security measures for the ultimate build-out should be evaluated. Load growth due to massive electrification and data centers, high tech manufacturing, hydroponics and cryptocurrency mining occur in hard to predict parts of the service territory and require rapid deployment of reliable and redundant electric service.

The telecommunications technologies that support the substations and the ability to gather rich data sources from transmission and distribution assets and customer locations need to be built concurrently. Several major utilities have started to build out their own private 900mHz dedicated spectrum services.

Substations in a real zero grid will be part of a newly defined microgrid-like arrangement that supports critical infrastructure and customers with more onsite capacity, some storage, robust broadband connections, and dedicated underground feeders or transmission.

Our industry needs nuclear power to achieve ambitious real zero goals. The Southern Company has commissioned the 1100 MW Plant Vogtle Unit 3 and is working on commissioning Unit 4 with great expense and schedule overruns.

But they did it.

The most promise for nuclear in the U.S. is held in small modular reactors (SMR) or advanced reactors planned by PacifiCorp.

Nuclear is a key part of PacifiCorp’s 2023 Integrated Resource Plan (IRP).

Large hydroelectric generation from existing dams particularly in the West and New York State represent nearly 6% of the total generating capacity in the US and about 38% of the renewable generation. Hydropower and pumped storage resources will continue to be part of a clean energy mix for decades to come.

Going Underground

Much of the real zero power grid must be built underground.

Undergrounding offers several advantages compared with

A Grid to Match Even with abundant local DERs the real zero grid will need a robust transmission system. A megatrend in our industry is realizing capacity from existing transmission rights of way. Routing and permitting new major transmission corridors can take decades as evidenced by SunZia, TransWest Express and some of the larger lines in California. In New England, the Northern Pass Transmission Project applied to the DOE for a presidential permit to construct, operate, maintain, and connect an HVDC line in October of 2010.

Northern Pass failed to get approvals and was replaced by the yet-unfinished New England Clean Energy Connect. New long-distance transmission will likely be HVDC and will be sited in railroad and highway ROWs to expedite routing and permitting challenges. In these transportation corridors, the transmission will also likely be underground.

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SUSTAINABILITY Dynamic line rating allows realtime monitoring and assessment of line capacity based on thermal capacity during prevailing weather and environmental conditions. Unlike traditional static line ratings, which are conservative and fixed or only seasonally adjusted, DLR accounts for conductor tension and temperature, air temperature, wind speed, solar radiation and humidity to determine safe operating limits of transmission more accurately. With static line ratings, lines are often underused during most conditions to prevent potential overheating, violations of minimum ground clearances, or long-term conductor damage during weather events. DLR will maximize available transmission capacity for the short run.

Several utilities across the world are having success in expanding capacity with advanced composite core conduc- An electric vehicle home charging setup. Electrification brings communities, large and small, positive economic tors that allow more ampacity to flow development, better transportation (mobility) and innovative, emerging technologies across a broad spectrum through a same or smaller sized cross- of community infrastructure and services. Photo 240542004 © Stefania Leonardi | Dreamstime.com section when compared to steel core conductors. Retro-fitting Energy is retrofitting heavily loaded urban lines and is building existing lines to increase capacity without changing structures some new transmission lines with advanced conductors that is commonly done at American Electric Power. Likewise, NV have more capacity to accommodate potential load growth

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SUSTAINABILITY due to electrification. Advanced conductors have distribution applications as well.

AI’s Impacts There are different types of AI, ranging from simple rulebased systems to more complex machine learning algorithms that can learn and adapt over time. Like the human brain, AI functions around pattern recognition. As a child, we learn by using our five senses to communicate to our brain. Over time, our brain recognizes the look, feel, smell, sound or taste of an infinite number of people, places and things. With faster computers and sufficient data storage, a computer can do the same thing.

Ubiquitous data sensors can be used on the grid and on customer premises in several ways to maintain and improve safety, reliability and resiliency. Data sensors can monitor the system in real time, providing utilities with instant data that, once processed, can give a picture of infrastructure condition and performance. This can predict and identify issues or problems before they become serious and take proactive measures to maintain system health and reliability. Sensors spot wildfires, downed conductors, failing cables, voltage anomalies and faults in the T&D system. By leveraging the power of data, utilities can improve their operations and support the development of a real zero grid that continues to meet the needs of consumers and communities.

Wild Cards Lithium-ion battery technology will be replaced with new storage technologies in the next decade. The critical rare earth elements that make lithium-ion batteries like nickel, lithium and cobalt are not sustainable in the long run. Hydrogen storage may be part of that solution.

Bio-fueled fuel cells or hydrogen fuel cells can generate electricity, providing a clean and efficient alternative to traditional fossil-fired power generation. Hydrogen from fuel cells can power electric vehicles, homes, schools and businesses.

Bio-fueled fuel cells or hydrogen fuel cells can balance the electric grid by providing a flexible source of power that can respond quickly to changes in demand or supply. Hydrogen fuel cells can provide backup power during times of peak demand, reducing the need for fossil fuel-based peaking plants.

Finally, hydrogen fuel cells can be part of a portfolio of generation, storage and demand side management tools used to successfully operate and maintain net zero energy buildings and eventually the real zero grid.

The digital twin is a multi-dimensional model or representation of a physical asset, infrastructure system or city that provides valuable information about asset location, cost, condition and performance. The digital twins are constantly updated from multiple human, robotic and sensory data sources. They are not a static three-dimensional model and can include dimensions for schedule, cost, ESG scoring and more.

The digital twin of the overhead and underground electric transmission and distribution system is a virtual replica of the physical system. It is a computer-based model that incorporates data from various sources, such as sensors, meters, robots and

other monitoring equipment, to provide a detailed and accurate representation of the electric system. The digital twin can simulate various design scenarios such as the integration of distributed resources like renewables, storage, electric vehicles (EV) or fuel cells as data scientists, planners and engineers model and prioritize the development of the real zero grid.

The digital twin can assist operators with condition assessment and predictive analyses of asset condition as part of an asset management program or asset health center.

This can help utilities optimize their asset management strategies and extend the life of their increasingly loaded substation equipment.

Three-dimensional printing construction may impact the T&D industry in several ways. 3D printing can create durable replacement parts on the jobsite for some equipment and potentially reduce downtime and repair costs. Plastic parts, panels or enclosures in substations or in manholes will be the starting point. As print feedstock metallurgy advances this opportunity will grow significantly and improve the ability to solve some critical path supply chain issues with a printed part rather than a long lead time part from a faraway factory. The real zero grid will need a supply chain that delivers parts and components rapidly, perhaps in real time.

Material science breakthroughs will give our industry superconducting technology that will be safe, reliable and affordable in the next decade. Replacing old underground high-pressure fluid filled transmission lines in heavy urban environments will be a perfect application. ComEd in Chicago has piloted this technology with reasonable success.

Utility companies operate in a rapidly evolving industry that faces technological advancements, changing customer demands, and regulatory shifts. Real zero energy has huge implications for the electric T&D industry.

Executives, planners and technical teams constantly look for innovative solutions that embrace new technologies, ideas, and approaches to enhance and continuously improve their operations, efficiency, and services to customers. The assumptions and ideas herein are an attempt to help the industry move forward and solve for the challenges of achieving real zero energy and the T&D grid to deliver it by 2050.

MIKE BEEHLER P.E. (mebeehler@protonmail.com ) is the chief opportunity officer for Mike Beehler & Associates LLC. He started his career designing and building transmission lines and substations for Tucson Electric Power and the Hawaiian Electric Co. and then spent more than 20 years designing T&D infrastructure and consulting on emerging trends at Burns & McDonnell. He has written, presented and consulted on reliability-centered maintenance, critical infrastructure protection and program management. In addition, he is a well-known industry writer and speaker on the early definition of the smart grid, 3-D and building information modeling applications in T&D, and development plans for smart cities. Most recently, he is sought for his strategic leadership and vision on the application of emerging technologies in changing business models to include the integration of distributed energy resources, augmented/virtual reality and artificial intelligence.

He authored the book, The Science of the Sale: A New Paradigm of Thinking for Your Future. Beehler is a registered professional engineer in Arizona, Florida, Hawaii, Texas, Colorado, Kansas, Georgia and Alabama. He also is a Fellow in the American Society of Civil Engineers and a member of IEEE and CIGRE.

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SUBSTATION UPGRADE

A second 115/13.2 kV, 28 MVA transformer and three breaker feeders were added to the Farmers Substation in Amarillo, Texas. Photo by Xcel Energy.

Amarillo Substation Ready for Nature Xcel Energy upgrades its Farmers substation to handle extreme weather in the Texas Panhandle.

By PERRY FOSTER, Xcel Energy

C

lean, reliable energy and continuous improvement have been Xcel Energy’s mission for decades. The regulated utility serves approximately 3.7 million electricity and 2.1 million natural gas customers across parts of eight Midwestern and Western states. Xcel’s electric utility division has 3.26 million residential customers, 520,000 commercial customers, two transportation customers and 1262 industrial accounts.

The upgrades at Xcel Energy Texas, a Southwestern Public Service Co., one of Xcel’s four utility subsidiaries, speak for themselves. The Texas-based utility, which serves customers in New Mexico and Texas, has invested more than US$2 billion

in the regional grid since 2021. In August 2023, it completed a $7.6 million upgrade at its existing Farmers substation, located in Amarillo, Texas, U.S. A new substation transformer and three new feeder lines were added to expand the substation’s capacity to serve a growing number of customers in the southern part of Amarillo, where the Amarillo Economic Development Corp.

(EDC) has attracted several new industries. Additionally, new housing continues to be built in the area at a rapid pace.

“As our customer base grows and as businesses use more electricity, it’s vital to ensure the system keeps pace with these changes,” said Adrian J. Rodriguez, president of Xcel Energy – Texas. “Equally important is making sure the lights can stay on

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SUBSTATION UPGRADE no matter what nature throws at us, and these ongoing system investments have proved their worth during multiple extreme weather events the past two years.”

Handling The Panhandle Weather in the Texas Panhandle can be brutal, including frigid-cold temperatures, blizzards, dust storms, wildfires, flooding, tornadoes and, most recently an extended period of triple-digit temperatures. Xcel Energy’s toughest weather events in the last decade have been brought on by ice, wind and heavy snow — oftentimes experiencing all three in the same event.

According to the National Weather Service (NWS), snowfall averages 17.9 inches (45.5 cm) annually in Amarillo. “The Amarillo area is subject to extreme and rapid temperature changes, especially during the fall and winter months when cold fronts from the northern Rocky Mountain and Plains states sweep across the area,” the NWS website states. “Temperature drops of 50°F to 60°F within a 12-hour period are not uncommon. Temperature drops of 40°F have occurred within a few minutes.”

To weather harden its system and accommodate the growing population in the southern

Xcel crews installed wildlife protection on the new 115/13.2kV, 28 MVA transformer.Photo by Xcel Energy.

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SUBSTATION UPGRADE

Adding three breaker feeders to the existing substation will increase capacity and reliability to area customers throughout the Xcel Texas service area.

Photo by Xcel Energy

part of Amarillo, Xcel Energy took extra measures to make the Farmers substation more efficient and reliable, and as Rodriquez said, able to handle “whatever nature throws at it.” As part of this expansion project, a second 115/13.2-kV, 28-MVA transformer

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and three new feeder lines were added to free up capacity on existing stations and provide additional switching options to keep power flowing when extreme weather threatens reliability.

To combat extreme weather, crews installed above-grade, rigid

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SUBSTATION UPGRADE overhead conductor inside the new substation. In addition, Xcel crews installed wildlife protection on the new transformer. The utility also targeted several older neighborhoods for voltage conversions, with the goal of bringing every neighborhood in line with a standard voltage.

The Farmers substation upgrade is one of several investments in the Amarillo and Canyon, Texas, metro area designed to improve reliability. Other projects have included the new Echo substation to boost reliability in northern Amarillo, new Center Port substation to shift electric loads and free up more capacity while priming this industrial sector of Amarillo for additional growth opportunities, and a rebuilt Lawrence Park substation to improve the reliability and capacity of this power hub for west-central Amarillo neighborhoods and commercial districts.

In addition, in southwest Amarillo, Xcel completed the Preston West substation and associated distribution lines southeast of Loop 335, freeing up capacity at nearby substations while ensuring continued growth without the concern of overloading existing facilities.

Economic Impact

PERRY FOSTER is regional director of Substation O&M, Transmission Field Operations at Xcel Energy in Amarillo, Texas, where he is responsible for providing leadership, strategic direction, and daily operation direction for all activities that support substation maintenance, operations, construction and pre-commissioning. He oversees the effective and efficient use of union and nonunion resources, with an emphasis on safety, human performance, reliability, customer satisfaction and compliance. Foster’s previous roles at the utility have included relay technician, working foreman, substation electrician working foreman and meter reader. Having earned a bachelor’s degree in management from Oklahoma Panhandle State University and an associate degree in electronics from Amarillo College, he is currently pursuing an MBA degree from Wayland Baptist University.

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Kevin Carter, president and CEO of the Amarillo EDC, said, “The recent power system investments coincided with development plans for several new and expanded businesses that benefited from the Amarillo EDC’s incentive programs.”

In the South Georgia Business Park alone, the Amarillo EDC has attracted $200 million in capital investments responsible for 350 new jobs at three new facilities, including Cacique Cheese, Austin Hose and Caviness Beef.

The Farmers substation project ensures these and future businesses in the area will have the capacity they need to grow.

“Low electricity rates and high reliability are big draws for companies choosing to relocate or expand in Amarillo,” Carter said. “The investments Xcel Energy has made in substation and distribution infrastructure have been critical to our efforts to attract 3000 new jobs and over $2 billion in capital investment over the past two years.”

Additional expansions and upgrades are planned in Amarillo and outlying cities, including two new substations. They include a new Arnot substation to boost reliability and capacity in the Bushland and west Amarillo area and an Ashby substation in eastern Dalhart to serve new commercial customers and provide additional switching options.

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FACES OF THE FUTURE

BY AMY FISCHBACH, FIELD EDITOR

Joshua Dean Hohenberg, Evergy

always trying to do better work by following the idea, “If you don’t know, ask,” and realizing that there is more than one way to safely get the work done. We are always honing our pole setting skills, work practices, climbing, and situational awareness to keep ourselves and our coworkers safe.

Look Inside the Training Center We have a top-notch training crew at our Cedar Point training facility. We have a pole barn where we can climb, work on terminations, make up elbows and practice splicing. We can simulate hot work on single-phase and three-phase on 35-ft poles set within the barn. As we move outside, we have a climbing yard and a transformer area for working on and building banks and making up pots. We also have an underground area for doing switches and finding faults with the equipment.

Inside, we have a classroom set up for teachers and student learning, hands-on simulators, book work and testing.

Learning on the Job

Josh Hohenberg encourages aspiring apprentices to have pride in themselves and their work, be on time and ready to work and never be afraid to ask a question.

• Lives in Grain Valley, Missouri and trains at the Cedar Point Training Center.

• Started in the trade after being a walk-on for a Boot Camp.

• In his second year of his lineworker apprenticeship program.

• Has pride in his work, is always punctual, has a good attitude and works well with others.

• Just learned how to operate tools to find and locate underground faults.

This technology will save time locating the problem and expedite power restoration.

• Enjoys spending time with his three daughters: twin 13-year-olds and a fouryear-old “Mini Me.” They do home activities, play, take walks, ride bikes and go bow hunting and fish on the lake.

Inspiration to Work in the Trade I became interested in line work from a few buddies of mine who are lineworkers. They talked about the work they do, ethics, pride, workmanship and the community that comes with being a line brother. They also shared their experiences of giving to others by getting lights and power back on to families. After talking with them, they kept nudging me to leave my career as a superintendent carpenter and start this new career in becoming a lineworker. They believed I would make a good fit with my work ethic and would be able to provide a better life for my three daughters.

Practicing New Skills I am now learning about transformer banks, switching, covering and working in the minimum approach distance. I am

My day-to-day job at this time is loading material and poles, using digger derricks and augers to set poles and transferring three-phase or single-phase from old poles to new ones. Right now, I’m working in a small town upgrading and improving the line. Our two crews are made up of a leadman, journeyman and an apprentice. Sometimes, we team up and work together and other times, we break off and do individual crew tasks. My daily work is second nature from the training we get at Cedar Point. We familiarize ourselves with running equipment and picking, loading and unloading poles. This training makes the start to the day flow safely. Having the training and simulating hot work in the yard has given us the confidence to do the work safely and properly in the field.

Teaching Leadership Apprentices today have access to better equipment, and they can learn and grow with more types of tools and technology.

In the past, they usually had a one-way track, and now, journeymen and lead men give apprentices the opportunity to look over prints, talk about the job and even give perspective and ideas about the work at hand. By allowing us to step in and be part of a job from the beginning, it helps with confidence. It is also a way of teaching leadership and good habits to pistole in apprentices with the idea that one day, we will be journeymen and lead men teaching apprentices. By changing the training and setting forth the respect and good work ethic that apprentices are show today will maintain that and keep that for future years to come.

Working Storms Over a year ago, I had the honor of working a storm and tornado that blew through Overland Park, Kansas. Poles snapped, wire was down, power was out for blocks and many homes were damaged. We worked to safely assess the area, set new poles, and pull up primary wire. We also installed new three-phase and/or spliced new secondaries back together to get the lights back on. We coordinated with multiple crews and contractors

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to get the work completed as soon and as safely as possible for our customers. I’ll never forget when we got the lights on a little after 3 a.m. At that moment, we could hear cheering, clapping and praises of thank you in the silence of the night.

The families just needed some hope that life was going to get back to normal. It was one of the most humbling, heartfelt emotions I have ever felt, and it filled my heart with so much joy.

enjoy doing line work and I also enjoy helping others learn and grow. To reach this, I’m going to keep on my path of doing great schoolwork, hands on testing, and continue to soak up and retain the knowledge that’s being shown to me every day. I also plan to continue to show up on time and do great work in the field.

Spotlight on Safety I keep myself safe and the crew who I’m working with safe by sticking with the plan or regrouping if the plan changes. At the beginning of each job, we fill out a safety tailgate, which identifies the task at hand and what we will do to complete that set task to get the job finished safely. We also note dangerous obstacles and what to keep your eyes looking out for. You must have your head on a swivel. It is always very important to keep safety first when doing your work. There is no excuse for putting safety second. There is always a way to do your work and complete your job safely. Everyone’s goal needs to be to end his or her day the same way he or she started it: safely and at home.

Life in the Line Trade Line work is amazing. It’s awesome to see a line go up, and the feeling you get when you drive by it years later, knowing you built that. Being a lineworker is a honor. We are our own heroes, and if things go astray, we save ourselves. It’s an honor to work next to someone who believes in pride, doing good safe work, and that we always have each other’s back. My favorite part of being a lineworker is knowing that I am working with some great people, building lifelong bonds and friendship. I’m a part of something bigger than any one individual. I’m a part of a community of honest, prideful, hardworking men and women.

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ELECTRIC UTILITY OPERATIONS

BY JD NEWHAM, SALT RIVER PROJECT

Inventing Tools to Solve Field Challenges Salt River Project partnered with a product development company to improve processes for its field workforce.

By JD NEWHAM, Salt River Project

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t Salt River Project, the transmission group strives to work smarter, not harder. Lately, the team members have identified tasks in pole maintenance and construction with room for improvement.

After conducting research on these challenges, they discovered other utilities are facing similar issues. To tackle the obstacles head on, SRP began inventing specialized tools to help the line crews to improve productivity. By developing prototypes, the company aimed to make lineworkers’ jobs easier while increasing efficiency. To ensure the designs were sound and to provide quality manufacturing, SRP partnered with an integrated product design and development firm. By bringing in outside help, SRP was able to bring its visions to life.

Providing Temporary Pole Support SRP serves more than 1.1 million customers in central Arizona with an electric service area of 2,800 square miles.

To cover such a large footprint efficiently, the line crews often try to prepare today for tomorrow’s workload. This helps the field workforce to better manage work hours, adapt to changing conditions and address any challenges that arise during the project.

One of the ways SRP prepares for future needs is to do all the excavation work for pole changeouts on one day and then replace the pole and backfill the next. After digging out around a pole, a crew would typically lodge pieces of lumber into each hole to temporarily support the existing pole until it was replaced and backfilled. However, this method isn’t ideal. The poles would often lean a bit more than preferred, and removing the pieces of wood can be straining with tension on them.

Eventually, I had the idea to use jacks to support the poles instead of lumber. I modified a scissor jack with a prong end for sticking into wooden poles to help better secure them. The jack could be extended and collapsed using a cordless drill for easy installation and removal. While the prototype was successful, SRP needed help producing more of them. The com-

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pany partnered with LineWise, which took SRP’s specs and created a professional product called the Pole Sitter. Today, LineWise can manufacture the product in quantities that meet SRP’s needs and make it available to other utilities.

Conducting Field Testing SRP Transmission crews perform 200 pole change-outs annually, and the lineworkers can use the product to save time.

Depending on conditions, the workers can use three or four jacks per pole, which provides better support than the crews’ previous approach of using lumber. Then, when they come back the next day, they can simply hold the pole while collapsing the jacks to remove them, rather than fighting to get pieces of wood out.

The Pole Sitters also offers benefits when setting new poles.

When the base of a pole is placed in a hole, the jacks can be easily adjusted to make it plumb before filling the hole with rock or concrete. The fill material is poured around the jacks until the pole can stand freely, and then the jacks are collapsed and removed before completing the backfill.

The compact size of the Pole Sitters also allow them to easily be transported to the job site.

Many of SRP’s jobs are remote access with supplies flown in by helicopter, so the lineworkers need to pack as compactly as possible. Because the Pole Sitters have a manageable size and weight, they are easy to handle and move to their intended location.

Inventing Specialized Supports Another process that SRP wanted to improve was jacking together 230-kV steel pole sections with slip joint connections.

The lineworkers construct these poles vertically, and their previous method was to use a crane to pull up a jack on one side of the pole and a handline to pull up the jack on the other side.

Instead, one self-contained piece of equipment could streamline the process and allow all the lifting to be done with the crane. The prototype included an engine and hydraulic pump

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ELECTRIC UTILITY OPERATIONS Saving Time After receiving the completed product, SRP’s team put it to work on nine poles. Construction took the crew about 45 minutes per pole, compared to an hour to an hour-and-a-half.

Time savings could be further increased on three- and foursection poles.

SRP is also adding a new feature to further improve the product. Initially, the hydraulic controls had to be operated at the pump, so the crew flew up a lineworker in a bucket to operate the jacks from the hydraulic power unit at the back of the tool. Now, the company is adding a controller with an extended cord, allowing the workers connecting the jacks to operate the unit.

Following the completion of the upgrade, SRP has another eight poles to set. Then, every fall or winter, SRP usually takes on a new 230-kV project, which could range from 10 to 80 poles each. SRP is experiencing a lot of growth in its area, which means the crews are building a lot of 230-kV poles and have a lot of work ahead for the Slip Joint Pole Jack. By using their field experience to help to launch the two new products, SRP transmission crews have made their pole change-outs and construction jobs easier and more efficient. They can now do more work in less time and work smarter, not harder.

This rendering shows how the jacks push against the hole and spike into the poles to keep them in place until concrete can be poured. Lineworkers can use three of these temporary supports to brace against the wall of the hole. The top point then pushes into the pole. The adjustment bolt on the right is pointed toward the top of the hole so a lineworker can adjust the jack with a drill with an extension.

for extending and retracting the hydraulic jacks. Two arms extended from the platform contained the engine and pump.

The arms made a “V” shape to hold a jack on each side of the steel pole. The complete assembly could be lifted with a crane, eliminating the need for a separate handline or to carry anything up in a bucket. Having the engine and hydraulic pump positioned at the back of the tool helped balance out the weight of the jacks at the opposite end. It also eliminated the need to send up a hydraulic power unit with a bucket. This benefit keeps the workers in the bucket distanced from engine fumes, noise, potential hydraulic leaks and other undesirable consequences of working near the power unit.

After creating the prototype, SRP requested assistance with design and manufacturing. The engineers went to work and created the Slip Joint Pole Jack, which is now available to other utilities as well.

JD NEWHAM (Jd.Newham@srpnet.com) is a transmission group supervisor for Salt River Project. He invented the two products and worked with LineWise to bring them to market.

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PARTING SHOT

Photo by JOSEPH KEENAN, ComEd

ComEd’s graduates of its overhead basic training program in Joliet, Chicago, and Rockford, Illinois, celebrate their achievement and prepare to move on to the next phase of becoming a part of the utility’s workforce.

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Electric Utility Operations

SAVE THE DATE

October 16-19, 2024 • Overland Park Convention Center Overland Park, KS • linemansrodeokc.com 2311TDW_House_LinemansRodeo.indd 2402TDW_44_EUO-Parting Shot.indd 45 1

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FOCUS: A LINEWORKER’S VIEW

BY AMY FISCHBACH, FIELD EDITOR

Meet Jeffrey Rodriguez

• Born in Kansas City, Missouri, and has two brothers, Mike Rodriguez and Earl Holmes

Evergy

• Engaged to Becky Whitmarsh, and they have 10 children: Jacob, 33; Paige, 31; MaKenzie, 31; TJ, 26; Alexandre, 26; Garret, 24; Olivia, 23; Bailey, 21; Emaily, 17; and Briella, 6.

Jeffrey Rodriguez, a lone lead lineman for Evergy, supported the apprentice competitors from the sidelines at the 2023 International Lineman’s Rodeo.

• Enjoys playing golf and watching collegiate wrestling.

• Currently working on major infrastructure renovations in distribution and transmission. For example, the streetcar transit system in Kansas City, Missouri, is one of the major projects underway.

take one thing at a time. For example, today, I started off the day with a little time for thankfulness. After joining a morning kickoff, I checked phone messages and emails. This morning, I followed up on Friday work performed by contractors and dispatched needed assistance for a transformer replacement. I also supervised assistance on yard damage and cover jobs for customers. Later on in the day, I changed out an overhead transformer, then assisted an electrician. I concluded my work day by assisting a crew changing out a pad mount transformer and setting up crew for broken pole replacement. Knowing all our people worked a safe day without incident is a beautiful gift.

Safety Lesson Safety has and always will be a priority in this field of work.

This mindset should never fluctuate.

Memorable Storm

Early Years

Hurricane Sandy on the East Coast was a memorable time.

We were out on storm restoration duty for a month. We arrived when the storm actually hit inland. We worked in New Jersey right off the coast. The hurricane uprooted trees, and the flooding moved houses. The residents were amazing.

In 1995, I began pursuing a career in the electrical trade. After four years, I earned my master’s electrical license, which opened doors for the opportunity to serve in ways I couldn’t even imagine. Serving on a mission trip, I befriended a gentleman named Paul White. Paul encouraged me to take the next step in furthering my knowledge in this wonderful field of service. Back in 2003, I had the opportunity to test for a lineworker position at Kansas City Power & Light (now Evergy), and I started my career in the industry in June 2004.

Tools and Technology Some of the best tools a lineworker can’t live without are other lineworkers. Prayers, knowledge and humbleness are key.

Of course, Milwaukee battery tools have proven to be very valuable in our trade.

Day in the Life

Going through a lineman apprenticeship is a path I would Life in the Line Trade highly recommend to one who has a Serving others will always be my pasheart to serve. Working toward the joursion, and there is no other field I would neyman lineman certificate was hard at rather be in. This is a family who serves times, however, very fulfilling. This caothers and works in all conditions to get located in Rock Port Missouri will be reer has led me from an apprentice to a the lights on. seeking proposals to supply electric lone lineman to a lead lineman, to now distribution materials as well as a lone lead lineman.

Editor’s Note: If you are interested in being profiled

Atchison-Holt Electric Cooperative

Day in the Life My responsibilities include serving supervisors, planners, crews, dispatchers, contractors and our customers. There is never enough time in the day, but I 46 T&D World | January 2024

engineering design services as part of a FEMA approved mitigation project. For more information or to request an RFP please contact Maggie Lair at (660) 744 5344 Mlair@ahec.coop. Bid requests will remain open until COB February 29, 2024.

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in this monthly department or know of a journeyman lineworker who would be a good candidate, email T&D World Field Editor Amy Fischbach at amyfischbach@gmail.com. To thank lineworkers for their dedication to the line trade, Milwaukee Tool sends each profiled lineman a tool package.

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STRAIGHT TALK

BY DANIEL COHAN, RICE UNIVERSITY

Virtual Power Plants: Balancing Supply and Demand

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raditional power plants that generate electricity from coal, natural gas, or nuclear energy are retiring faster than new ones are being built in this country. Most new supply is coming from wind and solar farms, whose output varies with the weather. That’s left power companies seeking new ways to balance supply and demand. One option they’re turning to is virtual power plants.

These aren’t massive facilities generating electricity at a single site. Rather, they are aggregations of electricity producers, consumers and storers — collectively known as distributed energy resources — that grid managers can call on as needed Some of these sources, such as batteries, may deliver stored electric power. Others may be big electricity consumers, such as factories, whose owners have agreed to cut back their power use when demand is high, freeing up energy for other customers. Virtual power sources typically are quicker to site and build, and can be cleaner and cheaper to operate, than new power plants. Virtual power plants are more resilient against service outages than large, centralized generating stations because they distribute energy resources across large areas.

Virtual power plants aren’t new. The U.S. Department of Energy estimates that there are already 30 to 60 GW of them in operation today. A gigawatt is 1 billion watts — roughly the output of 2.5 million solar photovoltaic panels or one large nuclear reactor.

Most of these virtual power plants are industrial customers that have agreed to reduce demand when conditions are tight.

But as growing numbers of homes and small businesses add rooftop solar panels, batteries and electric cars, these energy customers can become not only consumers but also suppliers of power to the grid. For example, homeowners can charge up their batteries with rooftop solar when it’s sunny, and discharge power back to the grid in the evening when demand is high and prices sometimes spike.

As smart thermostats and water heaters, rooftop solar panels, and batteries enable more customers to participate in them, DOE estimates that virtual power plants could triple in scale by 2030. That could cover roughly half of the new capacity that the U.S. will need to cover growing demand and replace retiring older power plants. This growth would help to limit the cost of building new wind and solar farms and gas plants.

And because virtual power plants are located where electricity is consumed, they’ll ease the burden on aging transmission systems that have struggled to add new lines.

The New Roles for Customer Virtual power plants scramble the roles of electricity producers and consumers. Traditional power plants generate electricity at central locations and transmit it along power lines to consumers. For the grid to function, supply and demand

must be precisely balanced at all times.

Customer demand is typically assumed to be a given that fluctuates with the weather but follows a fairly predictable pattern over the course of a day. To satisfy it, grid operators dispatch a mix of baseload sources that operate continuously, such as coal and nuclear plants, and more flexible sources such as gas and hydropower that can modulate their output quickly as needed. Output from wind and solar farms rises and falls during the day, so other sources must operate more flexibly to keep supply and demand balanced. Still, the basic idea is that massive facilities produce power for millions of passive consumers.

Virtual power plants upend this model by embracing the fact that consumers can control their electricity demand.

Industrial consumers have long found ways to flex their operations, limiting demand when power supplies are tight in return for incentives or discounted rates. Now, thermostats and water heaters that communicate with the grid can let households modulate their demand too.

In Texas, where I live, deadly blackouts in 2021 highlighted the importance of bolstering our isolated power grid. Now, utilities including CenterPoint Energy and Oncor Electric Delivery are using Tesla Powerwalls to help turn homes into virtual power sources. South Australia aims to connect 50,000 homes with solar and batteries to build that country’s largest virtual power plant. In Vermont, Green Mountain Power is offering its customers incentives to install batteries that will provide power back to the grid when it’s needed most.

Virtual Power, Real Challenges Virtual power plants aren’t a panacea. Many customers are reluctant to give up even temporary control of their thermostats, or have a delay when charging their electric car. Some consumers are also concerned about the security and privacy of smart meters. It remains to be seen how many customers will sign up for these emerging programs and how effectively their operators will modulate supply and demand.

There also are challenges at the business end. It’s a lot harder to manage millions of consumers than dozens of power plants. Virtual power plant operators can overcome that challenge by rewarding customers for allowing them to flex their supply and demand in a coordinated fashion.

As electricity demand rises to meet the needs of growing economies and replace fossil fuel-burning cars and furnaces, and reliance on renewable resources increases, grid managers will need all the flexibility they can get to balance the variable output of wind and solar generation. Virtual power plants could help reshape electric power into an industry that’s more nimble, efficient, and responsive to changing conditions and customers’ needs.

DANIEL COHAN is an associate professor of civil and environmental engineering at Rice University.

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