AT ASPLUNDH, WE PROVIDE SAFE, RELIABLE, AND INNOVATIVE SERVICES FOR OUR PARTNERS, CUSTOMERS AND COMMUNITIES IN THE VEGETATION MANAGEMENT AND INFRASTRUCTURE INDUSTRIES. SUSTAINABILITY, INTEGRITY, AND RESPECT FOR THE ENVIRONMENT REMAIN AT THE HEART OF OUR EFFORTS TO LEAVE A POSITIVE LEGACY FOR MANY GENERATIONS TO COME.
No burn-through eliminates elbow repairs
Lower materials and installation costs
Fault resistance makes repairing cables easy
Durable and corrosion-resistant for lower total cost of ownership
As severe weather events intensify around the world, electric power grids are increasingly tested by hurricanes, ice storms and wildfires. In the face of these challenges, more than ever before, we need to stay connected – to the electrical grid and to each other. Resilient Structures composite poles have demonstrated near perfect performance by reliably standing strong in nature’s harshest conditions. Engineered to be resilient, safe and environmentally sound they are the new standard in grid reliability.
Group Editorial Director Nikki Chandler nchandler@endeavorb2b.com
Managing Editor Jeff Postelwait jpostelwait@endeavorb2b.com
Senior Editor Christina Marsh cmarsh@endeavorb2b.com
Business: AEP Bumps Five-Year Capital Plan By 25%+
The company’s commercial load growth topped 10% during the third quarter and that growth rate is expected to double next year. https:// tdworld.com/55240960
Regulatory: Chris Wright, Trump’s Pick for Energy, to Focus on Reliability, Affordability
Wright is a frequent Republican donor and will serve on Trump’s newly formed Council of National Energy. https://tdworld.com/55245413
Generation: Entergy Mississippi Breaks Ground on Advanced Power Station
The project will provide a cleaner, more efficient power source for generations ahead. https://tdworld.com/55241535
Associate Editor Ryan Baker rbaker@endeavorb2b.com
Art Director Susan Lakin slakin@endeavorb2b.com
Field Editor Amy Fischbach EOUeditor@endeavorb2b.com
Technical Writer Gene Wolf GW_Engr@msn.com
Community Editor Rich Maxwell tdwmediapartners@gmail.com
Senior Editor-at-Large Geert de Lombaerde gdelombaerde@endeavorb2b.com
VP, Market Leader, Energy Diana Smith dsmith@endeavorb2b.com
Director, Business Development Steve Lach slach@endeavorb2b.com
VP, Customer Marketing Angie Gates agates@endeavorb2b.com
Senior Production Operations Manager Greg Araujo garaujo@endeavorb2b.com
Ad Services Manager Shirley Gamboa sgamboa@endeavorb2b.com
Audience Marketing Manager Sonja Trent strent@endeavorb2b.com
Audience Development Manager James Marinaccio jmarinaccio@endeavorb2b.com
Endeavor Business Media, LLC
CEO: Chris Ferrell
COO: Patrick Rains
CRO: Paul Andrews
Chief Digital Officer: Jacquie Niemiec
Chief Administrative and Legal Officer: Tracy Kane
Chief Marketing Officer: Amanda Landsaw
EVP Endeavor Business Intelligence: Paul Mattioli
EVP Building, Energy and Water Group: Mike Christian
T&D World (USPS Permit 795-660, ISSN 1087-0849 print, ISSN 2771-6651 online) is published monthly by Endeavor Business Media, LLC. 201 N Main St 5th Floor, Fort Atkinson, WI 53538. Periodicals postage paid at Fort Atkinson, WI, and additional mailing offices. Canadian GST #R126431964.
POSTMASTER: Send address changes to T&D World, PO Box 3257, Northbrook, IL 60065-3257.
SUBSCRIPTIONS: Publisher reserves the right to reject non-qualified subscriptions. Subscription prices: U.S. ($137.50); Canada/Mexico ($170.00); All other countries ($210.00). All subscriptions are payable in U.S. funds.
Send subscription inquiries to T&DWorld, PO Box 3257, Northbrook, IL 60065-3257. Customer service can be reached toll-free at 877-382-9187 or at tdworld@omeda. com for magazine subscription assistance or questions.
REPRINTS: To purchase custom reprints or e-prints of articles appearing in this publication, contact Reprints@endeavorb2b.com
PHOTOCOPIES: Authorization to photocopy articles for internal corporate, personal or instructional use may be obtained from the Copyright Clearance Center (CCC) at 978-750-8400. Obtain further information at copyright.com
PRIVACY POLICY: Your privacy is a priority to us. For a detailed policy statement about privacy and information dissemination practices related to Endeavor products, please visit our website at www.endeavorbusinessmedia.com
CORPORATE OFFICE: Endeavor Business Media, LLC, 30 Burton Hills Blvd, Ste. 185., Nashville, TN 37215, U.S.; www.endeavorbusinessmedia.com.
© Copyright 2025 Endeavor Business Media, LLC. All rights reserved. Printed in the USA.
NIKKI CHANDLER
Following in my predecessor’s footsteps, I am presenting my top three predictions for trending topics for the upcoming year. Teresa Hansen, our former VP of content, retired this past January, and I looked back at her predictions for 2024.
1. AI, particularly GenAI, will continue to be adopted by utilities for several applications. Teresa predicted that AI adoption by electric utilities would grow, and a recent report from Itron that summarized findings from 600 global utility executives announced that 82% of utilities were in the process of adopting AI/ML. The Resourcefulness Insight Report also found that enhancing safety was the top use case for AI/ML in the utility sector (49%), followed by cyberthreat detection (34%), and low-voltage distribution network management (20%).
We are picking this prediction again for this year, based on what our more popular and engaged articles were from this past year. AES’ article on its acceleration with AI was regularly on our most-read list. The utility outlined how it is using AI in vegetation management, asset optimization, dynamic line rating, digitalization and virtual power plants.
As demand for electricity continues to grow — which utility executives indicate is driven by data centers for cloud computing and AI (40%), new construction (32%) and sustainability initiatives like solar and electric vehicles (31%), according to the Itron report — utilities are facing unprecedented challenges in maintaining reliable and resilient grid operations. AI and ML will be crucial in addressing these challenges.
Technology Editor Gene Wolf also addresses how AI and its subsets are changing everything about the power delivery system in his “Charging Ahead” article on page 10. He contends that GenAI, a kind of AI that uses algorithms that are somewhat different from typical AI, shows great promise for forecasting energy consumption, anticipating how loads might vary throughout the day, and envisioning congestion spots on the power grid, to name a few potential applications.
Aspen Technology’s Sally Jacquemin, vice president, Power and Utilities, also included the increased adoption of AI by utilities in her 2025 predictions: “The perfect storm of power generation and grid infrastructure growth with new technologies and consumer-engagement will drive an exponential growth in data to be sorted, managed, and acted upon within the utility. Gone are the days of paper maps, whiteboard job orders, and limited field crew communication. As veteran utility workforces are set to retire, a new generation of utility operators require AI technology to sort through the noise of complex grid data to ensure safe, efficient, and resilient utility service.”
2. Utilities will get creative in addressing the burgeoning growth of data centers.
As I attended a few electric utility events this year, the main topic of conversations steered from the supply chain problems (which the industry is taking steps to address) to what are we going to do about load growth from data centers?
We also had several articles about data centers in our top 20 articles of the year. Gene Wolf asked in September if data centers were the next grid crisis. According to the 2025 Power and Utilities Industry Outlook, about 75% of the top 35 electric utilities in the U.S. have reported a rise in electricity demand from data centers. I have heard anecdotal reports from utilities that they have been approached by developers who sometimes want to build data centers that the utility does not have the current capacity for, so the projects are in limbo.
Deloitte, like Gene, offered several solutions that utilities are considering including grid-enhancing technologies, diversification of generation, new rate structures that would charge more to large energy users, and on-site generation such as microgrids (or co-location with power generation).
3. Utilities will continue to pursue intelligent undergrounding. Other industry analysts are predicting more distributed energy resources integration, carbon management development, and even more focus on cybersecurity. But based on our observations, we see that investment in underground distribution will pick up.
PG&E is probably the most recent leader in undergrounding lines after battling devastating wildfires and the continued threat of more as climates change. The utility announced this past November that it had constructed and energized more than 800 miles of underground lines since 2021.
Regular T&D World contributor Mike Beehler has been evangelizing for underground distribution for the past few years, with his message picking up momentum with even more wildfires and recent reliability failures. Having worked in the utility industry for more than 40 years, he knows the reality and approaches the topic with fairness. He believes that we can achieve 50% underground distribution by 2040 to address the energy transition and ensure resiliency.
Based on the popularity of the topic with our readers and on some projects in the works, we think this will be an important trend for our audience this next year. For example, NextEra is embarking on a $1 billion per year, 20-year plan to underground overhead laterals. Eversource Energy is planning an underground 345-kV substation below street level in downtown Boston. These are all projects that Mike follows, and you will hear more from him in an upcoming Straight Talk.
We live in exciting times, and I know 2025 will prove to be just as interesting and dynamic to watch as in the past 75 years. T&D World will be here for it.
Are we ready for the challenges 2025 will bring? As last year closed, there was a long list of topics and issues lined up to keep us busy in this new year. I’m equally sure there are more new wrinkles developing, there always are. If my mail is any indication, there’s no shortage of subjects vying for our attention. The array consists of press releases, media news stories, and in-depth reports along with stacks of whitepapers from the research laboratories.
Rather than trying to make a bunch of wild guesses, I’d prefer discussing some of more interesting viewpoints that keep popping up in my cyber mailbox. I guess that’s what keeps this job so fascinating, because many of them are really stimulating. They cover a multitude of issues, but I’m going with a couple of topics that I wrote about last year that continue trending.
Recently there has been a flurry of news stories about the pending crisis of increasing power demand from the hypergrowth in hyperscale data centers. A typical hyperscale data center consumes more than 50 megawatts of power and usually exceeds 10,000 sq ft (929 sq m) in size. We discussed these hyperscale data centers in September 2024, but that already needs updating.
As 2024 ended, the experts were thinking they may had been too conservative with their earlier data center load growth predictions. The latest forecasts now estimate that data centers will consume around 12% of the U.S. electricity generation by 2030. Also predictions indicate that the number of hyperscale data centers will double every four years. That’s not good news for utilities or grid operators. They need to be able to serve the growing numbers of these new hyperscale data centers along with their existing customers.
Since each new hyperscale data center represents at least 50 plus megawatts hitting the power delivery system, that eats up capacity at an astounding rate. But extra capacity is in short
supply. “Charging Ahead” has reported on several technologies that can help with this condition, but there’s one that’s more pertinent to these circumstances. Do you remember we discussed nuclear microreactors powering microgrids back in the December 2023 “Charging Ahead” editorial? Well, there’s a recent update!
In 2020 Idaho National Laboratory (INL) started work on the MARVEL (Microreactor Applications Research Validation and Evaluation) project. INL revised their accomplishments recently. An INL report said the MARVEL team began fabricating microreactor components in 2024. It’s expected fuel will ship in 2025 with loading estimated in 2026. If all proceeds according to plans, the 85 kilowatt microreactor is expected to be online in 2027, but how does this tie to hyperscale data centers?
The operators of these hyperscale data centers are well aware of the challenges utilities face building new facilities to meet the needs of their customers. As a result, they’re investigating their own power sources. Small modular reactor (SMR) technology combined with grid-scale microgrids have caught their collective eye. Amazon signed three agreements with X-Energy to develop SMRs totaling about 600 megawatts for SMR projects in Virginia and Washington. Google announced 500 megawatts of SMR projects with Kairos Power, but it’s not just SMRs that have gotten the attention of data center operators.
These operators have discovered that co-locating their data centers with existing nuclear power plants is advantageous. Last fall, Constellation Energy announced an 835 megawatt purchase power agreement with Microsoft for their data centers. That will require restarting Three Mile Island’s unit 1. In addition, Amazon has purchased a data center that uses power directly from the Susquehanna nuclear power plant’s bus.
That’s only a sampling of the plans being made by the tech giants regarding co-locating hyperscale data centers at existing nuclear power plants. Experts point out this doesn’t require new transmission, which speeds up the interconnection process for these new multi-gigawatt loads. The practice, however, is not without controversy in the form of reducing generation capacity to the power grid. There are also issues of unfairly shifting transmission costs onto ratepayers.
The Federal Energy Regulatory Commission has raised numerous concerns and is taking a closer look at the potential impacts. Distribution companies, transmission grid operators and regulatory agencies are also apprehensive over the potential of avoiding grid maintenance and other fees. It’s a complicated issue that’s not going away soon. It will probably be a topic of discussion throughout this year, and I can’t wait to see what else happens!
AI and its subsets are changing everything about the power delivery system.
Last November T&D World celebrated its 75th anniversary by looking at where the power grid has been and anticipating where it’s going. “Charging Ahead” was focused on how smart grid technology is reshaping the power grid and its operations. It has become an interconnected ecosystem of intelligent devices that is synonymous with modernization and optimization. Unfortunately, this modernization has increased the power grid’s complexity, but that’s not unexpected. Newer smart grid adaptations are addressing that problem with user-friendly interfaces.
Making smart grid technologies more user-friendly keeps the its usage increasing. A recent report from MarketsandMarkets said the global smart grid’s market is expected to expand to an estimated USD 161.1 billion by 2029. This is up from a projected USD 73.8 billion spending in 2024. Those figures represent how valuable digital technologies have become to utilities and operators, but there are adaptations that combine smart grid with other advanced technologies that are wanting more discussion.
The “Charging Ahead” article touched on several of these advanced technologies, but wasn’t able to go far enough into their cutting-edge applications or how those schemes are advancing the power grid. One of those mentioned was artificial intelligent (AI) and several of the applications associated with AI. Integrating AI into the smart grid requires care to details. Processing big-data into real-time awareness of the power grid can be tricky, as can AI’s pattern recognition capability. Combining these two for forecasting and anticipating fluctuations is only one aspect of the challenge, but as data big-grows in size it gets harder.
Smart grid data analytics are helping sort through this explosion of big-data, but how much is really coming from the power grid? It’s hard to nail down the specific amounts of big-data attributed directly to the smart grid itself, but the numbers are significant. It’s been said the daily big-data production rates range from terabytes to petabytes, but with numbers of this magnitude, size doesn’t matter. It’s sufficient to say the amount of big-data is beyond the ability of a human to manage, so big-data analysis is needed.
There have been many processes developed for handling big-data, but our interest lies within an application reported on by Dimension Market Research. They published a study
that said, “the smart grid data analytics market was expanding.” The study projected the market would reach USD 8.2 billion by the end of 2024. The publication went on to say that the smart grid data analytics market was anticipated to reach USD 24.2 billion by 2033, which brings up a question. What is smart grid analytics?
Essentially, smart grid data analytics is a shorter way of saying, turning the big-data into actionable information using AI. It’s a complicated subject, but there are many websites that go into great detail about AI if you are interested. For our discussion, keep it simple and look at how AI is being utilized by utilities and grid operators. Still, it’s important to know a few basics concerning AI.
It should be recognized that what is being called AI is really machine learning designed to automate manual tasks. Sentient AI systems seen in works of science fiction does not exist yet. Machine learning analyzes big-data using algorithms and powerful cloud-based computing. These algorithms vary in sophistication based on the performance expected from the AI application, with the more complex reserved for the most complicated tasks.
The accepted labeling practice places all the various forms of machine learning together under the common name AI. Keeping with convention, AI is ideal for classifying, assembling, and managing big-data. It uses algorithms to organize data into well-defined categories. In addition, AI uses sophisticated sets of conditional algorithms to make predictions based on the categories and conditional probabilities.
Last year, Siemens Energy launched its Gridscale X platform, which is part of its Xcelerator portfolio. This AI augmented platform is paving the way toward the vision of autonomous grid management according to Siemens Energy. Siemens went on, saying it will accelerate the digital transformation in the planning, operations, and maintenance areas. Moreover it will support utilities tackling their most pressing challenges related to the energy transition and keep their grid stable and reliable.
Breaking with the above labeling practice, there is another form of AI that has been placed in its own grouping called generative AI or GenAI for short. GenAI has established itself as a separate application due to its exceptional ability. GenAI uses algorithms that are somewhat different from typical AI.
They take advantage of probabilistic techniques to generate what-if scenarios, which gives it the ability for extrapolation of its big-data.
To do this, GenAI analyzes the big-data to understand its underlying patterns and it creates entirely new content from the big-data it studied. This makes GenAI a bit controversial, but a very powerful tool. GenAI shows great promise for forecasting energy consumption, anticipating how loads might vary throughout the day, and envisioning congestion spots on the power grid to name a few undertakings.
In November 2024, PG&E initiated the first commercial deployment of a GenAI application for a nuclear power plant at their Diablo Canyon nuclear generating plant. The application, Neutron Enterprise Program, is a search engine developed by Atomic Canyon and the Department of Energy’s (DOE) Oak Ridge National Laboratory (ORNL). Neutron runs on the NVIDIA AI platform. It uses Atomic Canyon’s FERMI family of AI models developed in collaboration with ORNL.
identify the fire while it is small enough to extinguish. Utilities like PG&E, Portland General Electric, Xcel Energy, Southern California Edison, Hawaiian Electric are using the AI technology effectively and reducing wildfires in their territories.
PG&E said that “federal and state regulations require utilities operating nuclear power plants to manage billions of pages of technical documentation spread across multiple systems.” Finding a specific record can be a slow process consuming time and resources. Neutron uses advanced optical character recognition, and the GenAI search engine has been taught to understand the terminology used in nuclear projects, which speeds up searches from hours to seconds. Being open source software, it will be available to the industry.
Speaking of DOE, last April DOE announced a big step for AI grid applications with their VoltAIc Initiative. They said it’s designed to use AI to help streamline siting and permitting at the Federal, state, and local levels. DOE is investing US$13 million to develop AI-powered tools for improving the process for new grid sites. It will also aid in permitting new clean energy infrastructure. While that was taking place, DOE published its first major report on AI titled “AI for Energy,” which was followed by several others.
The publications make interesting reading and are available online at DOE’s website. They emphasize the growing interest in the advantages of advancements in AI capabilities across the energy industry. They also point out that various forms of AI are already in use worldwide and technological advances are driving the rapid expansion of these AI tools.
A quick search on the web for utilities using AI applications on their electric grid brings back a slew of hits. One described using powerful high-resolution cameras teamed with AI applications as a formidable tool for fighting wildfires. The idea is to
Another one talked about labor intensive time consuming power line inspections. By using autonomous drones equipped with high-resolution cameras and integrated with AI and GIS for vegetation assessments, maintenance patrols, etc. utilities are seeing savings while efficiently meeting regulatory requirements. Utilities such as New York Power Authority. Dominion Energy, ComEd, American Electric Power, Southern Company, and others are utilizing these advanced technologies successfully.
These are only a small percentage of what’s happening on the power delivery system as a result of AI and GenAI being integrated into the power grid. So far AI has been doing the heavy lifting, but GenAI is beginning to pick up the slack when it comes to things like load balancing with real-time grid awareness.
Others see AI’s predictive analytics making the power grid more resilient by foretelling asset health and points of failures. If the DOE initiative for using AI to streamlining siting and permitting, delays for both will be lessen. It’s all about modernization when you remove the distractions of rapidly emerging technologies and consumer demands.
Granted, there are going to be bumps in the road as this all plays out. But it’s a positive step in dealing with the challenges the 21st century power grid is placing on the utilities and operators of the grid. There’s no option of doing nothing despite people ignoring events.
The industry is just starting to begin the adoption of AI and its subsets. We can expect these advancing technologies to redefine the industry in ways we haven’t anticipated. No matter how bizarre an AI application seems someone will turn the idea into reality!
The U.S. Department of Energy’s (DOE) Office of Electricity (OE) has released a report for distribution transformers in the electrical power grid.
The report, prepared by researchers at the National Renewable Energy Laboratory (NREL) for OE, focuses at the number of U.S. distribution transformer units, the number and capacity of the assets, the units’ current age profile, and demand for distribution transformers, which may increase in the future.
Researchers found three factors driving demand for distribution transformers:
• how many fail and require replacement,
• how many reach their end-of-life, and
• how the increasing number of new customers are driving demand on an annual basis.
The study also highlighted the major drivers of demand including data centers, electric vehicles and charging stations, and renewable energy generation requiring step up transformers with similar characteristics to distribution transformers. There are different types of transformers, which are either mounted on the power pole or on the ground.
“This report will help us understand the differences in
transformers used by power companies and how they will need to function to advance the 21st century grid,” said Michael Pesin, Deputy Assistant Secretary for Grid Systems and Components in OE. “Working with our labs and industry will help OE develop better strategies to manage demand now and in the future.”
According to estimates, about 55 percent of in-service distribution transformers are older than 33 years and increases in electricity demand on these older transformers is expected to fasten the rate of in-service units failure.
J.D. Power’s 2024 Electric Utility Business Customer Satisfaction StudySM indicates a significant rise in satisfaction among U.S. business customers of electric utilities. After several years of declines, overall satisfaction has increased by 30 points on a 1,000-point scale, reaching 784 in 2024.
The study highlights notable gains in satisfaction regarding pricing, corporate citizenship, and communication. Price satisfaction increased by 47 points year over year, driven by utilities stabilizing rates and working directly with business customers to lower costs. In total, 49% of business customers reported that their electric utility collaborated with them to reduce rates, often through enhanced proactive and digital communication. Of those surveyed, 56% indicated that they had received digital outreach from their utility.
The study also reflects a slight improvement in business financial outlook, with 5% more customers indicating they
are better off financially than a year ago, while the number of those reporting worse financial conditions declined.
The top-performing utilities in each U.S. region include:
• East Region: Con Edison (Large); Pepco (Midsize)
• Midwest Region: MidAmerican Energy (Large); Kentucky Utilities and NIPSCO (Midsize, tied)
• South Region: Georgia Power (Large); Entergy Texas (Midsize)
• West Region: Idaho Power (Large); Seattle City Light (Midsize)
The study, now in its 26th year, examines satisfaction across six areas—power quality and reliability, price, billing and payment, corporate citizenship, customer contact, and communications. It is based on over 20,000 responses from business customers in decision-making roles at companies served by utilities with 50,000 or more business customers, collected from March to October 2024.
Hawaiian Electric has improved its Wildfire Safety Strategy to reduce the wildfire risk from its equipment.
The actions include a Public Safety Power Shutoff (PSPS) program, replacing and testing utility poles, upgrading overhead power lines, clearing intrusive vegetation near electrical equipment, and installing weather stations and AI-assisted high definition video cameras. The upgrades are part of Hawaiian Electric’s multi-year grid resilience program to harden against wildfires, hurricanes, tsunami and flooding, and to adapt to impacts of climate change.
Hawaiian Electric is working with Filsinger Energy Partners, an energy advisory firm specializing in wildfire mitigation strategies and risk modeling. According to Filsinger, the various wildfire risk mitigation actions and programs implemented by Hawaiian Electric have reduced the risk of wildfire from the utility’s equipment by approximately 60%.
In 2024, Hawaiian Electric is spending about $120 million to make wildfire safety improvements in four key areas:
Foundational Work:
• Developed wildfire risk maps based on the potential of ignition by utility equipment.
• Conducted inspections of circuits in high-risk areas to prioritize hardening work.
• Continued ongoing vegetation management efforts in areas adjacent to power lines on all islands, spending $100 million in the last four years.
• Installing 3,534 fire-safe fuses to reduce the risk of ignition.
• Installing 1,071 new lightning arrestors to further protect equipment from lightning strikes.
Operational Changes:
• Launched a Public Safety Power Shutoff program, under which Hawaiian Electric may preemptively shut off power in areas at high risk of wildfires during periods of forecast high winds and dry conditions.
• Started deployment of spotters in risk areas during hazardous weather conditions.
• Set circuit breakers to automatically shut off power in risk areas when a disturbance is detected on a circuit.
Situational Awareness:
• Installed a network of 53 weather stations in wildfire-prone areas on four islands to provide information about wind, temperature and humidity to help the company better predict and respond to fire weather conditions. The weather stations, mounted on utility poles, provide meteorological data to help the company decide whether to activate and deactivate a PSPS.
• Started installation of a network of 78 artificial intelligence-assisted high-definition video cameras to help quickly detect wildfires.
Grid Hardening:
• Replaced and upgraded 2,202 utility poles.
• Replaced more than 16 miles of older overhead lines with new, more resilient lines.
• Installed 4,514 single-phase fault current indicators, which allow crews to more quickly locate disturbances on lines in high-risk areas.
Hawaiian Electric is also working with community partners on wildfire safety projects, such as the construction of a firebreak at Leihoku Elementary in Waianae. The project helped remove more than 1,000 feet of kiawe trees and grasses on Department of Hawaiian Home Lands property.
Hawaiian Electric is not only seeking grants and federal funding for safety and resilience programs but is also developing a longer-term wildfire safety plan to be filed with the Public Utilities Commission in January 2025.
Avangrid applies a mobile transformer along with a turnkey service from the provider to house and deploy the transformer whenever and wherever needed.
In the world of renewable energy, every second counts. When outages strike or key equipment fails, it can take months or even years to replace traditional power transformers, halting energy production and putting pressure on the grid. Recognizing the need for fast, reliable solutions, Avangrid, a member of the Iberdrola Group, has taken a major step to ensure the continuous flow of clean energy across its U.S. wind and solar operations.
Avangrid is using mobile transformers, however, rather than being parked and taking up valuable footprint at one of its facilities, the mobile transformer remains securely housed at a Hitachi Energy facility. When the need arises, the vendor will manage the transportation and logistics of delivering the mobile transformer to the affected site and immediately begin its connection to the grid, offering a seamless turnkey service that ensures the contingency transformer is ready to be deployed wherever needed.
When the need arises, the vendor will manage the transportation and logistics of delivering the mobile transformer to the affected site and immediately begin its connection to the grid.
With 168-MVA capacity, the mobile transformer is built to be compact and durable, making it ideal for rapid transport and installation.
This strategic approach enables Avangrid to focus on what it does best — generating clean, renewable energy — while the vendor provides the crucial infrastructure support. When a transformer outage occurs, rather than rushing to find and transport replacement equipment, Avangrid can call it in. In response, the company’s service experts spring into action, orchestrating the movement of the mobile transformer from the Crystal Springs, Mississippi, facility to the necessary location, managing the logistics every step of the way.
“This mobile transformer is an exciting new addition to our tool kit,” said Avangrid CEO Pedro Azagra, highlighting the importance of this relationship. “The service provided by Hitachi Energy means we can deploy it wherever and whenever it’s needed without delay. This collaboration is vital for driving innovation and continuous improvement within our clean energy fleet, making it more resilient and reliable.”
In an era where climate change is increasing the frequency and severity of extreme weather events, this partnership is especially valuable. Hurricanes, winter storms and other natural disasters can knock out essential equipment, but with the mobile transformer, Avangrid can quickly restart power generation at its renewable energy sites, minimizing downtime and ensuring clean, emissions-free energy continues to reach the grid.
This ability to recover rapidly after a major event is vital as Avangrid expands its renewable energy portfolio across the U.S. This approach also can be valuable in more mundane situations, such as an extended, planned outage for maintenance or an upgrade.
Custom engineered by Hitachi Energy for Avangrid, the mobile transformer is designed for rapid deployment and features multivoltage capabilities, the transformer can be installed within a matter of weeks — a steep reduction compared to the typical lead time for replacement power transformers, which can take more than two years. Once Avangrid notifies the company of the need, the transformer is quickly configured to the correct voltage and transported to any of the utility’s onshore wind or solar sites to bring power back online while more permanent solutions are pursued.
With 168-MVA capacity, the mobile transformer is built to be
compact and durable, making it ideal for rapid transport and installation. The logistics team is well-versed in coordinating the movement of this highly specialized equipment. Using specialized semitrucks and trailers, the transformer is hauled across highways and back roads, navigating any terrain necessary to reach Avangrid’s facilities. The transformer’s low-profile, lightweight design and ability to withstand higher G-forces enables it to endure the rigors of travel, from sharp turns to steep inclines, ensuring it arrives in good condition and ready to be installed.
The mobile transformer’s unique design, which features Hitachi Energy’s shell-type technology, enhances its reliability and durability. This configuration of the transformer’s active components allows for an ultra-compact solution, making it easier to transport, while also ensuring it can handle the demands of a variety of energy environments. It also is built for versatility, capable of being deployed at any of Avangrid’s facilities, whether wind or solar, and no matter the site’s installed capacity, ensuring that wherever energy generation needs to be restored, the mobile transformer is up to the task.
As more renewable energy projects come online and the demand for clean energy continues to grow, services like this will play a key role in maintaining grid reliability.
What makes this service particularly valuable to Avangrid is the peace of mind that comes with it. Knowing that the service provider handles the storage, transportation and logistics means Avangrid does not have to undertake the complexities of planning, securing permits or dealing with the challenge of moving large industrial equipment across the U.S. Instead, the service provider’s expert team takes care of everything, from coordinating with local authorities to navigating difficult terrains, ensuring the transformer arrives at the site as quickly as possible. This level of service allows Avangrid to maintain focus on operating its wind and solar farms, confident that when outages do occur, they can be addressed swiftly and efficiently.
Senior Vice President and Head of Hitachi Energy’s transformer business in North America, Steve McKinney emphasized the importance of this collaboration. “The clean energy transition depends on innovative solutions and strong partnerships,” he noted. “By working closely with Avangrid, we’ve created a service that ensures their operations are resilient, even in the face of transformer failures or equipment damage. We manage the logistics, so they don’t have to. It’s a service that reduces downtime and helps keep clean energy flowing to where it’s needed the most.”
Hitachi Energy’s service to Avangrid extends beyond transportation. Once the mobile transformer arrives at its destination, the transformer services team supports installation and commissioning, ensuring it is up and running as quickly as possible. This hands-on support is critical in an industry facing longer-than-usual lead times for new equipment. With supply chain delays becoming more common, having a transformer that can be deployed rapidly is essential to minimizing disruptions to energy transmission and distribution.
Looking to the future, the relationship between Avangrid and Hitachi Energy signals a broader trend in the clean energy industry: the increasing need for flexible, mobile solutions that can be deployed rapidly in the face of unforeseen events. By keeping the mobile transformer action ready at the service provider’s facility and relying on that team’s logistical expertise, Avangrid can ensure its ability to respond to outages without the burden of handling the complex transportation process themselves.
As more renewable energy projects come online and the demand for clean energy continues to grow, services like this will play a key role in maintaining grid reliability. For Avangrid, this mobile transformer is not just a piece of equipment; it is a strategic asset, made more valuable by the full-service agreement with Hitachi Energy.
As clean energy infrastructure becomes increasingly critical to the country’s energy future, collaborations like this will ensure, no matter the challenges, the power generated by wind and solar farms will keep flowing. Avangrid is free to focus on its mission of working together to deliver a more accessible clean energy model that promotes healthier, more sustainable communities every day.
KEATON THOMAS is Communications Manager for Avangrid’s onshore renewable energy business. Previously, Keaton held a marketing and communications position at TTEC. Before moving into corporate communications, Keaton was a news reporter and investigative reporter for television stations in Michigan, Arizona, and Oregon where he covered a variety of topics for local audiences. Keaton holds a B.S. in Journalism from Northwestern University.
MIKE LEVESQUE is Marketing Communications Manager for Transformers in North America for Hitachi Energy. Previously, Mike has held Communications and Marketing Management positions in Alstom, GE, and ABB. Mike is also a former Sergeant in the United States Marine Corps (USMC) where he served honorably as a Rifleman, Squad Leader, and USMC Marksmanship Instructor. Mike has a degree in Communications from Eastern Connecticut State University (ECSU).
An improved network and smart grid technology helped revitalize the community served by this municipally owned utility.
By J. ED. MARSTON, EPB, and DON LORENTE, Hexagon
In the early 1980s, Chattanooga, Tennessee, U.S., found itself at a crossroads. Once a thriving manufacturing town, the mid-sized city was grappling with economic uncertainty as businesses closed or offshored operations. The city’s downtown was still home to several major employers, but it became a ghost town after 5 p.m. when workers headed home. And, although the city sits on the Tennessee River, it had become cut off from its river roots.
Rather than allowing the community to slip into decline, Chattanoogans came together on a public visioning process that culminated with a commitment to making Chattanooga the best mid-sized city in America. They embraced a portfolio of projects, including the establishment of the Tennessee Aquarium on Chattanooga’s downtown riverfront. Although the earliest projects were focused on redevelopment, community leaders and organizations took up the vision as a question in addressing a range of issues.
Over the next three decades, a wave of revitalization projects took off across the community. In the early 2000s, the city’s
municipal electric utility, EPB of Chattanooga, engaged Hexagon AB, a global technology company, to launch a project that has become key to Chattanooga’s continuing transformation. With their technology along with several other solutions, EPB built an advanced, fiber-optic-based smart grid and offered 1-GBper-second internet service to every home and business in its 600-sq-mile (1554-sq-km) service territory. The project was part of Chattanooga’s goal of becoming “Gig City” by reinventing itself through innovation and technology.
The city is now launching 25-GB community-wide internet service and establishing a commercially available quantum network, EPB Quantum Network, powered by Qubitekk Inc.
In the late 1990s, EPB began exploring the possibility of enhancing the resilience and reliability of Chattanooga’s electric grid by deploying automated switches and other connected devices across the local system. Unfortunately, the communications technologies typically used in the electric industry at that time
delivering more reliable electricity and high-speed fiber-optic internet services to every corner of its service area.
were only adequate for smaller-scale projects and tended to become obsolete quickly. EPB’s plan called for deploying well over 1,000 automated switches across 600 sq miles. The solution? A smart grid built on a fiber-optic network, capable of
EPB launched its ambitious construction project in 2009, as the U.S. headed into the Great Recession. The original plan was to complete 90% of the network over 10 years. However, with the help of a US $111.5 million grant from the Department of Energy, EPB was able to accelerate its timeline, finishing the fiber deployment to make the network accessible to all customers
after just two years. Once online, the fiber-optic network that underlaid the electrical system served as the communications backbone for the most advanced and highly automated smart grid in the U.S., while also providing EPB with the connectivity necessary to launch the world’s fastest community-wide internet.
The fiber network was not just built for the city’s needs at the time; it was future-proofed from the start. Once the fiber-optic network was in place, EPB layered in the additional components necessary to complete the smart grid, including advanced meters and automated IntelliRupter switches from S&C Electric Co., which reduced power outage times and made the system more resilient. EPB’s approach ensured all areas — urban, suburban and rural — were included in this technological leap forward, demonstrating its commitment to serving the entire community.
Geospatial asset management software that made it possible for EPB to integrate its electric grid with its new fiber network. This hybrid model, which enabled EPB to co-locate fiber infrastructure within existing electricity infrastructure, minimized construction costs and streamlined the entire deployment
The Hexagon technology was able to support both immediate and long-term needs, allowing EPB to upgrade network electronics, such as optical network terminals, without needing to overhaul the entire fiber infrastructure. This flexibility meant EPB could continually enhance internet speeds — from 1 GB in 2010, to 10 GB in 2015, to 25 GB in 2022 — all while keeping costs manageable.
Proprietary integration tools also made it easier for EPB to monitor and manage the grid, ensuring both power and fiber infrastructure were optimized for maximum efficiency. This approach not only supported the smart grid’s immediate needs but also prepared the system for future upgrades and expansions.
Building Chattanooga’s smart grid was no small feat. EPB faced technical and operational challenges in bringing the project to life. One of the biggest obstacles was ensuring the system
would support not only the initial construction but also longterm operations. EPB needed to develop new systems and adapt existing ones to ensure its ambitious infrastructure plans could be sustained.
Another challenge involved navigating the complexities of deploying fiber and smart grid technology across a diverse geographic area. EPB’s service territory includes urban centers, suburban developments and remote rural communities, each with its own demands. As part of EPB’s mission to enhance quality of life for the whole community, ensuring rural areas could access the network was always a nonnegotiable part of the plan. Thanks to its model of using the fiber-optic connectivity to deliver both internet services and support smart grid communications, EPB’s deployment has proven to be successful even though margins are lower in areas where customers are more distant from each other.
EPB’s smart grid project was able to help close the digital divide. The symmetrical high-speed network provides the same speeds to urban and rural communities, ensuring even the most remote areas of its 600-sq-mile service area have access to the same high-speed internet as its urban core. These same capabilities extended the benefits of broadband to economically disadvantaged families through HCS EdConnect, powered by EPB, which supplies high-speed home internet at no charge to Hamilton County Schools students who qualify for free and reduced lunch. Started as a pandemic-era program to connect students for home-based learning, HCS EdConnect continues today, serving more than 16,000 students, who with their families represent nearly 28,000 Chattanooga area residents.
The smart grid and fast reliable internet access brought economic and social benefits to Chattanooga. In the first decade of operation, the grid generated $2.7 billion in community value, according to a study conducted by The University of Tennessee in Chattanooga. That value included the creation of nearly 10,000 jobs and a 55% reduction in power outages. By reducing outage minutes by more than one-half, EPB saves its customers $55 million annually, helping them avoid food spoilage, lost productivity and other negative impacts.
In addition, Chattanooga’s fiber network has attracted tech companies and high-paying jobs, making the city a hub for innovation. EPB’s role in bringing innovative infrastructure to the city even earned it recognition as a “living laboratory” and more than $110 million in Smart City research by the U.S. Department of Energy.
EPB’s commitment to innovation did not end with the deployment of the smart grid. Over the past decade, the utility has continued to push the boundaries of what is possible. In 2022, it became the first provider in the nation to offer communitywide 25-GB internet service. This was possible because EPB had undertaken a five-year, $70 million upgrade to the system, which included increasing the core capacity of its fiber network to 100 GB
In addition to boosting internet speeds, EPB also is exploring new ways to enhance grid resilience. The utility has launched several energy storage facilities and microgrid installations at
critical facilities like the Chattanooga airport as well as the Chattanooga Police Services Center and Fire Department administrative headquarters. These microgrids allow EPB to island portions of the grid during outages, ensuring power remains available even when the main grid is offline. It also is investing in energy storage in more rural parts of its grid that can only be served by a single line to ensure those customers also experience fewer outages and increased reliability.
In addition, EPB collaborates with a range of national and local research partners. In fact, its partnership with Oak Ridge National Laboratory has only further cemented Chattanooga’s reputation as a hub for advanced research as the pair works together on emerging technologies and applications, including quantum technology networks and deploying drones to identify issues in hard-to-access locations of the grid.
EPB’s success in Chattanooga offers valuable insights for other utilities and telecommunications providers looking to modernize. One of the key lessons is the importance of pairing energy and connectivity services. By integrating the smart grid with fiber-optic broadband, EPB realized operational savings and created a more resilient system that better serves its customers.
Another lesson is the value of strategic partnerships. Hexagon’s utility geospatial asset management technology allowed EPB to optimize the deployment of both fiber and electric infrastructure, reducing costs and improving efficiency. This partnership enabled EPB to offer the fastest community-wide internet speeds in the country while also maintaining a world-class power grid.
Finally, EPB’s approach to grants and funding also provides a model. Rather than relying on federal and state grants to drive its strategy, EPB develops a long-term plan and then seeks grants to accelerate projects already in the works. This ensures projects are both financially sustainable and aligned with its broader, community-focused mission.
The partnership between EPB and Hexagon has transformed
Chattanooga into a national leader in smart grid technology and high-speed internet access. By building a fiber network to serve multiple use cases, EPB has improved reliability and reduced outages while helping more people benefit from broadband access. For other electric utilities and telecommunications companies, EPB’s experience offers a road map for success through strategic planning, innovative technology partnerships and a commitment to serving the entire community.
As cities and towns across the U.S. look to modernize infrastructure, EPB’s smart grid serves as a beacon of what is possible — a model where energy and connectivity converge to create sustainable, resilient communities. Utilities and telecommunications providers can find inspiration in Chattanooga’s journey, learning that with vision, collaboration and the right technology, they too can power their communities toward a smarter, more connected future.
DON LORENTE is technical director at Hexagon’s safety, infrastructure and geospatial division. Lorente has more than 35 years’ experience in the telecommunications, gas and electric industries. He has been with Hexagon for 30 of these 35 years. During his tenure, he has architected and led the implementation of networks systems for utilities and telecommunications customers across Canada, as well as consulted on a North American level.
J. ED. MARSTON leads EPB’s Strategic Communication efforts which include public relations, community engagement and corporate communications. Since joining EPB in 2014, he has played a key role in promoting EPB and Chattanooga with a particular focus on community benefit, economic development and sustainability. Prior to joining EPB, he served as Vice President of Marketing and Communications at the Chattanooga Area Chamber of Commerce for twelve years. Marston holds a Bachelor of Arts in English and Writing from Spring Hill College in Mobile. He is also a graduate of the U.S. Chamber’s Institute of Organizational Management.
For More Information
Qubitekk | www.qubitekk.com
S&C Electric | www.sandc.com
Why upgrading the grid doesn’t mean replacing everything old.
By PANKAJ DESHMUKH, ASEC Engineers.
Would you be surprised to learn that early lattice steel structures were not designed according to national standards? In the early days, each engineering firm followed its own unique design methodology, similar to how phone manufacturers once used different charging ports—until the USB-C emerged as universal standard. This lack of consistency resulted in structures built under varied criteria, creating significant challenges in their analysis that we continue to confront today.
The majority of the transmission infrastructure in the U.S. was built before 1960s and continues to support the electrical grid today. As electrical demand continues to rise, the grid must be modernized. This typically involves installing larger conductors or tightening conductor tensions to improve electrical clearances, leading to higher structural loads, sometimes exceeding the capacities the original structures were designed to handle.
The primary challenge in assessing aging structures is determining whether they still meet current code regulated strength requirements. Let’s explore the challenges of analyzing older transmission structures and summarize the various methods used for the analysis of these historical structures.
To understand how these aging structures were originally built, it is important to look back at the design practices used over the last century. There are several approaches that are interesting and illustrate the progress made over the years. Beginning in the early 1900s there were no standards for designing lattice towers. During this time, the American Bridge Company was the leading provider of lattice towers and you might say they did it their way.
Several of their structures including tall river crossing towers are still in service. Their design approach is documented in their year 1925 publication “Transmission Towers” and is referenced for the study that will be discussed shortly. Materials science and engineering technologies continued to grow and advance. By the 1960s, the practice of structural design had evolved and one approach was documented in the “Design Standards No. 10.” This publication came from the United States Department of the Interior, Bureau of Reclamation. It was one of the design methodologies used for design of lattice towers and hence is also referenced for this study, but structural design advancements did not stop there.
The American Society of Civil Engineers (ASCE) publishes standards for design of different structures. The publication of “Guide for Design of Steel Transmission Towers” in 1971, was the first attempt by ASCE towards formalized design standard. The majority of the design requirements we find in the current standard “Design of Latticed Steel Transmission Structures” (ASCE 10-15) have come from this 1971 publication. This ASCE 10-15 standard is used to represent the current design approach in this article.
With the introduction of modern standards, discrepancies in capacity calculations started to emerge. The ability of an angle section to withstand tension forces, calculated using the current ASCE 10-15 standard is observed to be less than the capacity provided in the year 1925 ‘Transmission Towers’
publication. This is because ASCE 10-15 standard reduces the tension capacity of an angle connected on one leg by 10%. This was not the case in the historical structures. As a result, a historical structure when analyzed under current codes, may indicate that the member strength exceeds their design capacity.
Many historical structures often fail to meet connection rupture capacity requirements introduced by the ASCE 10 standard in the year 1990, since the older structures were not designed for this requirement. To comply with the current code, the structures will need to meet the current rupture capacity requirements.
Another key area where design methods have evolved significantly is in the calculation of compressive strength. Due to developments in research, the formulas for calculating compressive strength of structural members have evolved over the last century. When the compressive stresses for different unbraced lengths (slenderness ratios) obtained from the formulas from 1960s and those from early 1900s were compared with current standard, the results indicate that the current standard yields in higher member capacities. In the adjoining figure you can see that the leg members from the early 1900s were designed to only 79% of their maximum capacity.
Older transmission structures were designed using hand calculations, without the aid of calculators or computers. In contrast to today’s rigorous analysis, where hundreds of load combinations are considered, older structures were checked for only a few — usually just three load combinations. Despite being designed under less stringent criteria, many historical structures have endured over time, largely because their designs did not push the structures to their full capacity. These older structures also relied heavily on full-scale testing to verify their ability to withstand the design loads.
The compression formulas from ASCE 10-15 are designed for connections with a normal framing eccentricity. This means the bolt pattern’s center should be between the angle’s heel and the centerline of the connected leg. However, many historic structures don’t meet this criterion and have eccentric connections. For these cases additional analysis is needed to assess bending stresses typically outside typical tower analysis software.
The challenges in the analysis of historical structures do not end with understanding the older design standards and codes. Another major challenge lies in the availability or accuracy of structural drawings. For older structures these records are often missing, incomplete, or difficult to interpret. When this happens, engineers rely on on-site inspections to gather necessary data, such as structure dimensions, member sizes, and
the number of bolts. Modern technologies like drone photography and Light Detection and Ranging (LiDAR) make this process easier and safer.
LiDAR is particularly useful for capturing the overall dimensions of a tower. In some cases, it reveals differences between the existing structure and the original drawings. High-resolution drone images can also provide close-up views of complex connections or damaged areas without needing to physically climb the structure. Despite the advantages of these technologies, certain issues like connection failure from bolt bearing can only be identified through boots on the structure inspection.
The strength of bolts and steel has evolved with the development in material science. For example, the shear capacity of a 5/8” diameter bolt through the threaded portion increased
found in the AISC’s historic member databases or can be calculated using a software program. When the custom section properties listed in the 1925 version of ‘Transmission Towers’ were compared with those derived from software calculations, the differences were negligible.
In addition to the design and material properties, the physical condition of the structures after years of service is another critical factor. All the structural analyses assume that the structure is intact, and the structural capacity is same as the time it was first installed. While it is generally true, structure could deteriorate over the service life due to corrosion.
For old structures, corrosion is the most common issue leading to a reduction in its capacity. Corrosion reduces the cross-sectional area of the members and weakens its strength. If the tower members are damaged due to corrosion, the members need to be analyzed using the reduced cross-section area to account for the loss of material and strength. Corroded surfaces are bright red and have pitted surfaces.
However, members that appear to be corroded could have weathered galvanizing that is more of a reddish-brown staining. The reddish-brown staining is created when the iron in the zinc-iron alloy layers oxidizes.
from around 4 kips in the early 1900s to 15 kips today. However, in older structures, the grade and strength of steel members or bolts used may not always have been documented. In these situations, engineers can estimate the strength based on the era in which the structure was built. Alternatively, a member or bolt may be removed from the structure in question to test its strength in a laboratory. If a piece is proposed to be removed for testing, care should be taken by engineers to ensure that the tower remains stable without the member by utilizing specialized computer analysis and by replacing the missing parts on the structure.
Consider something like ASTM A394 grade bolts. They were introduced in 1955 specifically for transmission towers. These bolts had smaller heads and allowed for tighter connections. The next major change in bolt shear strength occurred when the 1984 version of A394 standard introduced four types of bolt grades (Type 0 and Type 1, 2, and 3).
The tensile capacity of these new bolts exceeds the tensile capacity of the member steel, and the bearing capacity of the bolt material does not govern in the design of connections. For older bolts, bearing of bolt material should be considered during analysis.
Several structural shapes used in historical structures have been discontinued. The historic member properties can be
Actual rust will only form if there is no zinc present where the defect is located. If only reddish-brown stains are present, the base steel is not rusted. When the member surface is sanded off, remaining galvanizing can be seen. It is important for an inspector of old structures to understand the differences between rust and weathered galvanizing and utilize best practices during analysis so that a structure’s capacity is not incorrectly reduced.
Given these shifts in design criteria and material standards, it’s no surprise that many historical structures might not meet all the requirements of the current code. While analyzing the old designs, it is important to understand the differences between the original design methodology and current standards before the structure’s existing capacity is determined. By combining lessons from the past with today’s engineering tools and technologies, we can ensure these structures continue to serve reliably while meeting the demands of modern infrastructure.
PANKAJ DESHMUKH, PE ( pankaj.deshmukh@hotmail.com) has 15 years of experience in transmission tower designs. He has designed the first double circuit guyed Y tower and the tallest transmission tower in North America. As Director of International Operations at ASEC Engineers, he oversees a team of 50 engineers. Pankaj holds a master’s degree in structural engineering from Texas A&M University and is recognized for leading innovative projects and enhancing team performance.
With harsh weather often resulting in lost or delayed mail, AVEC’s digital payment system has transformed how its Alaskan members access and pay bills.
By STACEY SMITH, Alaska Village Electric Cooperative Inc.
Alaska may not be the first place that comes to mind when people think about the bleeding edge of digital transformation — and that is with good reason. The state historically has struggled to keep up with the Lower 48 when it comes to technological innovations, largely due to Alaska’s unique geography, vast size and low population density. These factors pose significant challenges to building out the infrastructure needed for mass digitization. This lack of basic infrastructure extends to all forms of digital services, from basic cell phone coverage and online education to telehealth and digital billing and payments, for example.
However, these challenges are not insurmountable. With the right strategic planning and implementation, Alaskan service providers can overcome these obstacles and propel themselves
into the digital age, offering their communities the daily conveniences of technology and solutions to challenges that are unique to their lifestyle.
Addressing this lack of connectivity is a primary objective for Alaska Village Electric Cooperative (AVEC), providing service to 59 Alaskan villages and spanning the largest area of any electric power cooperative in the world. Only one of the 59 villages is connected by the road system, while the other 58 are so remote they can only be reached by boat or plane.
Given the challenging environment — which varies between mountainous regions, sprawling forests and icy tundras — one might think an electric utility upgrade would involve installing new cables or circuit boards. While AVEC is constantly problem solving for its physical infrastructure, the biggest game changer
for the utility’s member services team has been overhauling the digital payments system and providing customers new options to access invoices and pay bills online.
Prior to June 2021, AVEC had seven customers enrolled in its automatic payment option, and it did not offer any options for paperless billing. These inadequacies would be a frustration in any environment, but for the remote villages AVEC serves, they amounted to much more than a simple inconvenience. Many people in these communities live subsistence lifestyles, meaning they depend on fishing, hunting and gathering to feed their families. That means they rely heavily on freezers to store enough meat and fish to last several months. While most people would be annoyed by a suspension in service due to a missed utility payment, for these Alaskans, the risk of having their electricity turned off is enormously consequential.
This challenge is further compounded by the fact that delinquent payments are incredibly common among AVEC customers — and not always through any fault of their own. Mail delivery to these remote villages is unpredictable at best: Harsh weather can prevent planes from landing for weeks at a time, and logistical challenges mean lost or delayed mail and parcels are common. AVEC customers in the remote villages report receiving bills late and payments getting lost in the mail. When a delinquent payment leads to an electricity shutoff, the consequences of such unreliability are severe. Families relying on subsistence hunting and fishing risk having months’ worth of food go bad. Something had to change. For AVEC, finding a digital solution to the billing issues was not just about convenience. It was about safeguarding the stability and well-being of its member communities and ensuring their way of life continues to be possible. It also was clear the member needs were as unique as they were considerable. To be successful, the digital payments solution had to be both robust and flexible, not to mention easy to use for a variety of comfort levels with technology.
To address these challenges, AVEC took a multipronged approach: The utility invested in upgrading communications to satellite coverage for reliability and then focused on its billing system by forging partnerships with financial institutions and technology providers. Simultaneously, it conducted a comprehensive community outreach and education campaign to encourage adoption. The utility expected to have to invest considerable time and resources encouraging adoption of the new system, but word spread fast because its benefit was so self-evident. Nearly as soon as AVEC
went live with its billing partner, InvoiceCloud, its customers enrolled in paperless billing in droves. Today, it has more than 6,500 paperless bill payers. As for automatic payment, the utility increased from seven people participating in the program to 1,755 — a massive leap forward, specifically a 24,971% leap forward.
One factor AVEC’s member services team believes contributed to the utility’s success with InvoiceCloud was how it communicated about it. The team did not just communicate it was a new billing system but also a way to protect member interests and the community’s wellbeing. For residents who were accustomed to receiving bills late or worrying about lost payments, the ability to pay bills online or automatically was not just a matter of convenience but a crucial way to ensure their families’ safety and stability.
The difference has been nothing short of transformational. AVEC is saving more than US $20,000 per month on invoicing alone since going live with its digital billing upgrade. However, the real reward has been the impact on the community. AVEC members who had been at the mercy of the postal system — which itself is at the mercy of the weather — were no longer burdened with the anxiety of not knowing whether their power would be shut off due to a delinquent payment they knew they had made.
The psychological and emotional relief for the members cannot be understated. The adoption of digital payments provided them with peace of mind and a sense of control over their essential utilities. This transformation also helped AVEC to build stronger relationships with its customers, who now see the utility not as a service provider but as a partner in their daily lives, actively working to improve their quality of life.
Alaska is not unique in facing these challenges. Across the world, remote communities struggle with similar issues — a lack of infrastructure, challenging environments and a need for
reliable services. AVEC’s experience shows digital transformation can be a powerful tool for these communities. It is not just about keeping up with the times or adopting the latest technology trends; it is about creating meaningful impact and ensuring customers can continue living their lives the way they choose.
Advancements in technology are appealing to every business. No matter the industry, seamless, straightforward tools that contribute to the bottom line are valuable assets and worth investing in. AVEC found thoughtful technology implementation can actually help to preserve heritage by supporting traditional ways of life. Ironically, by embracing digital innovation, the utility has helped Alaskans to embrace their heritage and not only survive but thrive.
Many of AVEC’s customers live lifestyles that have been handed down for generations — hunting, fishing and foraging for their food. The ability to keep their freezers running reliably and their homes warm is crucial to maintaining these traditional ways of life. The utility’s digital payment solution helps to protect this heritage by eliminating some of the risks that come with unpredictable billing cycles and unreliable postal services.
AVEC’s digital payment revolution is more than just a statistical success; it is an investment in Alaska — both its future and its history. The utility has demonstrated digital transformation can be a game changer even in the most remote and logistically challenging environments.
For other rural communities facing similar barriers, AVEC’s story can serve as an example that sometimes technology is more than a nice to have. By prioritizing digital bill payment solutions, the utility did more than modernize its technology tools. It contributed to safeguarding the way of life of its members, supporting their well-being, and enhancing their overall quality of life.
AVEC’s member services team encourages other utilities and service providers to take a page from AVEC’s book and harness the power of technology to create meaningful, lasting impact. Invest in digital upgrades, collaborate with local communities and transform challenges into opportunities for growth and resilience. The future is digital, and it is time for all rural communities to seize it.
As AVEC looks to the future, it remains committed to finding new ways to leverage technology to benefit its members. The digital payment platform is just the beginning. The utility
is exploring other avenues of innovation that could further enhance service reliability, reduce costs and improve the quality of life for those it serves. From smart grid technologies to renewable energy solutions, the possibilities are extensive. With its vast landscapes and resilient communities, Alaska might not have been the first place one would think of for digital innovation. But perhaps, in this land of extremes, it is precisely where innovation matters most.
STACEY SMITH has served as manager of member services at AVEC since May 2017, after 13 years providing fuel and logistics services via other partners. Her current duties include leading the member services team and overseeing all billing, collections and management of capital credits. She also is responsible for annual meeting coordination, responding to consumer concerns and managing the complex software and metering programs that generate the cooperative’s revenue.
Duke uses a mobile, interactive display to educate customers about how to own, use, charge and benefit from electric vehicles in their own homes
By LOGAN STEWART, Duke Energy
From the outside, it looks like an inviting residential home complete with potted plants and front porch rocking chairs. But visitors who step inside Duke Energy’s Electric Vehicle (EV) Garage discover a setup designed to not only delight but also to better explain why the future of four wheels is electric.
First launched in 2021, the EV Garage is an experiential marketing asset that encourages face-to-face interaction between customers and Duke Energy representatives — an idea meant to foster education about what the company is doing to further electric transportation, while also helping demystify electrification. Duke Energy originally sought an interactive way to engage with customers in person around EVs and had considered a tradeshow-style setup. Ultimately, the company opted for something that was easy to transport and created an experience with a flow of information and helpful content.
“Utilities are central to the development and expansion of electric
transportation growth. Even as we prepare the grid for a future with more EVs, it’s important to make sure our customers have opportunities to go electric if that fits their lifestyle,” said Meghan Dewey, vice president of products and services for Duke Energy. “Addressing primary barriers to adoption like
cost and home charging are important. And sometimes it’s just helpful to get in front of customers to have an open and honest conversation, reduce confusion and share more about the options they have.
Designed as a walk-through interactive experience that unfolds from a 20x40 foot trailer, the EV Garage mimics a typical residential home on the outside and a home garage on the interior. Inside, several types of EV chargers help visitors
OUR WUNPEECE TRANSMISSION SPACERS REDEFINE THE INDUSTRY STANDARD FOR UNDERGROUND POWER TRANSMISSION INSTALLATIONS. WITH PRECISION ENGINEERING AND UNMATCHED QUALITY,
better understand home charging, sparking conversation with Duke Energy team members about the company’s EV programs. A digital EV savings calculator, EV selector tool and a charging map offer a vision for how an electric vehicle can fit a variety of lifestyles.
The EV Garage is mobile and frequently goes on the road — it attaches to the back of a truck to move from place to place. It has been to events across the company’s service area, including in North and South Carolina, Florida and Indiana. It has visited venues ranging from home and garden shows
and auto shows, to outdoor festivals and music events, to golf tournaments and more. These locations tend to attract visitors who are generally more relaxed and focused on enjoying the day and often attract Duke Energy customers who are likely to or interested in purchasing an EV or are decision makers in the home.
Part of the draw of the EV Garage is the laid-back, engaging nature of its setup. Adirondack chairs and a photo op that are set up on an event-by-event basis beckon passersby, while miniature golf games, a prize wheel and cornhole further immerse visitors in a fun and memorable experience. At various stops where feasible, the company may work with event coordinators or auto manufacturers to park an EV onsite.
- Allows for independent control of 2 units with 1 remote
- Multiple users can operate lights in close proximity
- Quick and simple pairing without dipswitches
- On-Command return to 0° home
- Simultaneous Pan + Tilt
- Fluorescent Remote Buttons
Duke Energy has seen some of its best EV Garage engagement at the annual Charlotte Auto Show, an annual showcase of new cars by a span of auto manufacturers. The company debuted the EV Garage at the event several years ago — 2024 marked the EV Garage’s fourth year in attendance — and has seen increased interest there as customers continue to explore EVs and seek information about how charging works.
As more drivers are switching to electric cars, Duke Energy has worked to support the states it serves — and where its customers live and drive — as they plan for more EVs on the road. In North Carolina, where the company is headquartered, Executive Order No. 246 addressed the state’s commitment to climate change and a cleaner energy economy and set a goal of 1.25 million registered EVs in the state and 50% of all vehicle sales being zero-emission by 2030.
Duke Energy has worked to support the deployment of EVs across its states by developing a comprehensive suite of EV customer programs that offer incentives and rebates while also promoting managed charging programs to help the utility manage the need for electricity throughout the day.
Duke Energy has forecasted energy consumption to grow at an average annual rate of nearly 2% over the next 26 years, with about 35% of that growth coming from greater EV adoption. That means by 2050, energy use could be about 50% greater than what it is today.
Duke Energy takes a customer-focused approach to serve customers’ individual needs and lifestyles through its offerings,
providing a menu of options and a seamless experience for customers from the grid to their garage. Programs facilitate education and advisory programs for customers interested in going electric and offering incentives for the purchase of EVs. The company continues to file for regulatory approval of similar suites of programs across all its jurisdictions.
One of the company’s most successful initiatives to date is its off-peak charging pilot program in Florida, which gives enrolled customers a credit for charging their EV during off-peak times with a Level 2 charger. The pilot met its goal of 2,000 participants in 2023 and is on track to reach its program allotment of 3,000 active customers prior to the end of 2024, with more than 1,300 customers on a waitlist. The off-peak charging program will launch as a full program without capacity limits in early 2025 in Florida.
In North Carolina, the company’s Charger Prep Credit program has also proven highly successful, providing incentives to customers to upgrade the existing electrical infrastructure in their garage to prepare for an EV charger. The program, which has served more than 12,000 North Carolinians since launch in 2022, has also launched in South Carolina and is approved in Florida, launching in 2025.
According to Duke Energy, in 2023 the EV Garage saw nearly 300,000 impressions and had more than 16,000 engagements with customers who visited the setup. Duke Energy also collects email addresses through a survey as customers complete their EV Garage experience, offering a chance to win premium prizes. Results from the survey have shown that that attendees leave the EV Garage experience feeling more knowledgeable, excited about and having a much higher interest in EVs — and a more favorable view of the company.
When interacting with customers at the EV Garage, the Duke Energy team often starts with basic electrification information. Customers are also frequently surprised to learn that many EV drivers only use a public charger for travel, and that charging an EV at home typically will not increase a residential electric bill by more than $50 a month for an average driver. Visitors also show interest around the fact that additional equipment such as a Level 2 charger isn’t required — the car can be plugged into a regular wall outlet at home.
“The EV Garage has been a great investment for us,” said Dewey. “When customers walk away with a smile on their face, saying they learned something new and had fun, you know you’ve built something valuable.”
LOGAN STEWART is a lead communications manager for Duke Energy, one of America’s largest energy holding companies whose electric utilities serve 8.4 million customers in North Carolina, South Carolina, Florida, Indiana, Ohio and Kentucky. Her current focus is power delivery, storm communications, distributed energy resources, grid edge technologies, electric vehicles and economic development. She graduated from the University of North Carolina at Chapel Hill with a degree in political science.
HUGHESBROS.COM
BY JOHN HAYTER, WEST
The energy transition and emerging technologies are transforming grid reliability and power infrastructure to meet the demands of a sustainable future.
In the rapidly evolving landscape of power infrastructure, grid reliability remains a pivotal concern, but faces complicated challenges of a new industrial revolution with increased demand, multiple power generation sources and the desire for distributed energy resources. As T&D World delves into this crucial topic, the spotlight on how the energy transition is reshaping power grids becomes even more pertinent. Now more than ever, utilities are embracing new technologies and actively seeking ways to engage with partners across the energy sector to seamlessly and sustainably manage the dynamic shift from fossil fuels to electrification and renewables.
ABB, a global leader in electrification and automation technologies, is at the forefront of addressing these challenges. By offering a deep dive into how the energy transition is impacting the power sector, ABB provides valuable perspectives on grid reliability, the impact of environmental factors and the broader implications for the future of power grids.
The transition from fossil fuels to renewable energy sources is a cornerstone of modern energy policy. This shift is already in progress with transmission lines having reduced their dependence
on coal from 68 percent down to 30 percent. While this aims to mitigate climate change and reduce environmental impacts, it also introduces a new set of challenges for grid reliability. Unlike traditional power plants that provide a steady output, renewable sources can fluctuate based on weather conditions and time of day. This poses a challenge for the utility as the adoption of renewable energy sources, such as wind and solar power, continues. To solve for this, utilities are engaging partners with expertise in grid management technologies. Advanced solutions in grid automation and control systems help manage the productivity of renewable energy sources, ensuring a stable and reliable power supply. In addition, technology is becoming a tool for better asset management as demand continues to increase from across industries.
The environmental impacts of energy production are a driving force behind the transition to cleaner energy sources and a way to help fight climate change. However, this shift is not without its economic challenges. The costs associated with upgrading grid infrastructure to accommodate renewable energy sources are substantial. Investments in new technologies, such as
energy storage systems and advanced grid management tools, are helpful for overall grid reliability and to support the integration of renewables.
Grid management systems’ role in this transformation extends beyond just new technology; it also involves offering solutions that are economically viable. Innovations in energy storage and demand response systems help to offset the costs associated with renewable investment and integration. By optimizing energy usage and enhancing grid efficiency, utility companies benefit from a more cost-effective transition to sustainable energy. Utilities are working to develop financial structures that allow for continued investment in more energy efficient power plants and transmission and distribution infrastructure without raising rates for everyone.
Looking ahead, the future of power grids is poised for significant transformation. The Infrastructure Investment & Jobs Act (IIJA) has accelerated utility investment by providing $65 billion in funding for utilities to support grid resiliency. That, combined with the continued growth of renewable energy and advancements in grid technologies, will drive changes in how power is generated, distributed and consumed. Key trends shaping the future of power grids include:
• Decentralization: The traditional model of centralized power generation is giving way to a more decentralized approach. Distributed energy resources such as solar and wind are becoming increasingly common but not without complexities such as two-way power flow, intermittency and the siting of solar fields and wind farms. However, the Department of Energy and state public utility commissions (PUC) are streamlining the siting and permitting process which will help speed up the implementation of new transmission sites.
ABB technology is used in substations, data center management, and solar fields.
• Digitalization: The integration of digital technologies into grid infrastructure is transforming how power systems are monitored and controlled. Smart grids, equipped with
advanced sensors and communication systems enable real-time data collection and analysis. This, coupled with Artificial Intelligence (AI), improves operational efficiencies and facilitates predictive maintenance and response strategies.
• Resilience: As extreme weather events and other disruptions become more frequent, grid resilience is a growing concern. Building a grid that can withstand and quickly recover from such events is essential for ensuring continuous power supply. Grid resilience solutions focus on enhancing the robustness of power systems and improving their ability to respond to and recover from disturbances.
• Electrification: The “electrification of everything” is driving increased energy demand. Data centers, electric vehicles, smart homes and the like, will necessitate a reevaluation of grid capacity and infrastructure to accommodate higher electricity consumption. Advancements in grid technologies will support the scalability of power systems to meet the growing demands of electrification.
The integration of digital technologies into grid infrastructure is transforming how power systems are monitored and controlled.
Today’s contributions to grid reliability and resiliency are multifaceted, encompassing a range of technologies and solutions designed to enhance grid stability and resilience. Some of today’s impactful, forward-thinking advancements include:
• Advanced Grid Automation: Grid automation solutions provide real-time monitoring and control of power systems. These technologies enable grid operators to detect and respond to potential issues before they escalate, ensuring a more reliable power supply.
• Energy Storage Solutions: Energy storage systems play a critical role in managing the output of renewable energy. These solutions help balance supply and demand, storing excess energy when production is high and distributing it when needed.
• Cybersecurity Measures: As power grids become more digitalized, cybersecurity is an increasingly important concern. Roughly 81% of information security officers in the energy sector have seen a clear rise in attacks over the past 12 months. Today, cybersecurity solutions protect grid infrastructure from cyber threats, safeguarding the integrity and reliability of power systems.
• Demand Response Technologies: Demand response solutions enable grid operators to manage electricity consumption more effectively. By incentivizing consumers to adjust their usage during peak periods, these technologies help to balance supply and demand and reduce grid stress.
A new era of power and energy is upon us. There has never been more momentum, more resources or more technology available to the industry that can enable the energy transition. Utility leaders today are bringing an open mind to innovation and want to partner with technology companies to deliver a smarter, faster, future-proof power grid. This new industrial revolution will drive unprecedented productivity gains and deliver safe and reliable electricity to meet the demands for power today as well as the needs of tomorrow’s grid.
JOHN HAYTER ( john.hayter@us.abb.com) is Vice President, West Region, Utility Market at ABB, a global leader in electrification and automation technologies. He holds a degree in Manufacturing Engineering from East Tennessee State University and has over 30 years of experience working in energy, industrial and commercial market segments. In his current role he brings extensive knowledge, vision, policy and strategy to enable ABB to be the electrifying force for a brighter grid future.His recent work focuses on the evolving challenges and solutions in power grid management amid environmental and economic pressures.
The line foreman competed on a Midwest Energy journeyman team at the 40th International Lineman’s Rodeo. To learn more about him and his career in the line trade, look for a future Line Life Podcast episode to air at linelife.podbean.com.
• Born in Hays, Kansas, as the youngest child of five.
• Married to Amber. They have two sons, 12-year-old Michael and eight-year-old Collin.
• Enjoys coaching his kids’ activities, especially baseball and football. He also loves deer archery hunting, bird hunting and fishing.
• Honored as the champion of the annual PLP Armor Rod Install Challenge at the 2024 International Lineman’s Expo.
• He is the second lineworker from Midwest Energy to win this competition. Theron Tucker, a previous employee, won the PLP Armor Rod Install Challenge in 2023.
When I was young, a neighbor inspired me to one day join the line trade. I didn’t realize I really wanted to do it until I graduated from high school.
In 2005, I started with Midwest Energy, and I’m currently a line foreman. The greatest thing about our job is the variety of work that we get to do from transmission to overhead distribution to underground. The main reward of our job is stepping back, taking pride in your work, teaching the apprentices, and of course, keeping everybody’s lights on.
There have been several instances throughout that years that have definitely opened my eyes to safety and the reasons we work in the first place — which is our family. I think the way we all react to situations is all different. If we can take one thing to help someone else from doing the same thing and preventing the same accident, we did our job in the process even though we are the ones that made the mistake.
Most memorable storm would’ve been the May 2006-2007 ice storm in Western Kansas. I believe we worked for 27 restoration days before our first day off. The worst part about the ice storm was that the wind took down the ice-covered wire. We repeatedly had snow over the top freezing and thawing every day. This made getting the wire back in the air very difficult.
Right now, we are working on FEMA projects from previous year’s storms and new connects near our town of Hays,
Kansas. I hopefully plan on being a foreman at Midwest Energy for a long time and to remain doing the same type of work that I do now.
Cordless tools from compression tools to impacts have absolutely changed every aspect of our job. There’s no way we could be as efficient without them as we are. Also, the means of the cordless technology from digger trucks to cut off tools being able to run machinery and equipment from remotes definitely helps with safety and also eliminate added stress on our bodies.
I would not trade what I do for anything, and I am so glad I joined this industry. I hopefully we’ll be able to retire from the company that I work for and keep working diligently until then.
Twitter.com/@tdworldmag
We recently hosted the inaugural Midwest Policy Summit for the American Association of Blacks in Energy (AABE), focusing on topics like the energy transition. It also included an expo for St. Louis high school students to learn about careers in energy.
Whether it’s a birthday, baby shower, graduation or a holiday party, make sure Mylar balloons stay grounded. Stray balloons can damage electrical equipment and knock out power when they float into overhead lines. Stay safe! Puncture and deflate to dispose of them properly.
Follow our staff on Social Media...
Nikki Chandler @powereditor
Jeff Postelwait in/jeff-postelwait-477387a
Christina Marsh in/christina-marsh-basken
Amy Fischbach @amyfischbach
The Watts Bar Nuclear Plant team is beginning to wrap up the scheduled maintenance and refueling outage for Unit 1. Part of the work included installing two HUGE steam rotors, each weighing over 320,000 pounds! ��The new rotors will help Watts Bar provide carbon-free, reliable #NuclearEnergy to our region for at least the next 30 years!
❄When a heavy snowstorm caused an outage for some residents in Silverton, Colo. last month, crews from Tri-State snowshoed to a pole at 11,900 feet, climbed the structure, and repaired the broken static wire during the blizzard.
��We are so thankful for the bravery and skill of this crew, as well as the response from San Miguel Power Association, that allowed us to restore power quickly and safely.
Vice
Over the weekend, LUMA Energy made significant progress in our efforts to modernize Puerto Rico’s electrical system. Our dedicated team successfully installed and energized a new transformer that now serves the financial district, the Coliseo de Puerto Rico, and nearby businesses and customers. We are committed to improving the electrical grid, and we are already seeing positive results. Thank you to the multidisciplinary team that worked hard to make this happen!
Susan
Gray
President
and
CEO
at Tucson Electric Power/UNS Energy Corporation
Santa might have a sleigh, but we’ve got the bucket trucks. I was so honored to join the crews this morning as they brought the sparkle and dazzle to the tallest trees for the annual Winterhaven Festival of Lights. This year marks the 75th anniversary of this Tucson tradition and we’re so proud to partner with the neighbors to bring the spirit of the season to our community.
#ThisIsTucson #SeasonOfGiving
Director, Business Development
Stephen M. Lach
Phone: 708-542-5648
Email: slach@endeavorb2b.com
Account Manager
Brent Eklund
Phone: 303-888-8492
Email: beklund@endeavorb2b.com
Account Manager
Steve Rooney
Phone: 781-686-2024
Email: srooney@endeavorb2b.com
Account Director
Bailey Rice
Phone: 630-310-2598
Email: brice@endeavorb2b.com
Account Manager
John Blackwell
Phone: 518-339-4511
Email: jblackwell@endeavorb2b.com
Account Manager
Denne Johnson
Phone: 607-644-2050
Email: djohnson@endeavorb2b.com
Sales Director, Energy
Jeff Moriarty
Phone: 518-339-4511
Email: jmoriarty@endeavorb2b.com
International Linemen’s Rodeo, and Events
Sam Posa
Phone: 913-515-6604
Email: sposa@endeavorb2b.com
Utility Analytics Institute Memberships
James Wingate
Membership Development Manager
Phone: 404-226-3756
Email: jwingate@endeavorb2b.com
Utility Analytics Institute, Smart Utility Summit and Smart Water Summit
The 2024 elections have ushered in a seismic shift in Washington, with a new president and Republican majorities in both the House and Senate. As the dust settles, questions remain about what this means for the future of energy policy.
Few areas stand to be impacted as profoundly as the electric grid and the urgent need for expanded transmission. Traditionally, Republicans and Demo crats have supported additions to our energy infra structure, including transmission. More recently, however, debate over policies designed to facilitate transmission investments have become entangled with discussions about the generation resource mix and the clean energy transition.
Certainly, some of the best wind and solar resources in this country are located in remote areas and require a robust transmission system. But if we simply characterize transmission as a facilitator of clean energy policies, we are missing the fact that more transmission is desperately needed to ensure electric affordability and reliability.
For nearly two decades, electricity demand in the U.S. was flat, or growing minimally. That era is over. Demand is expected to increase five percent annually, with some regions experiencing even faster growth primarily due to:
• surging U.S.-based manufacturing.
with available transmission capacity were able to import power from less affected areas, mitigating widespread outages. The ERCOT portion of Texas, in comparison, was not similarly connected and experienced days-long blackouts. A recent NERC study on interregional transmission underscores this point – better connections between regions enhance grid reliability and resilience in the face of growing threats.
The new Administration and Congress should make transmission infrastructure a top priority. FERC is already leading the way through its landmark Order No. 1920, which requires regions to produce 20-year transmission plans that identify the projects that will be most needed.
Order No. 1920 also grants states an unprecedented role in cost allocation for regional transmission projects. Utilities must engage in a process for state input on the ex-ante cost allocation method as well as a process that allows states to customize cost allocation for specific projects or portfolios of projects after they are identified.
• expanded data center and Artificial Intelligence operations.
• electrification.
This will require substantial additions of new electric generation capacity. However, this growth depends on an electric grid that is already too congested to efficiently move power when and where it is needed. Moreover, these new generators face lengthy delays connecting to the grid in large part because there is insufficient transmission capacity to accommodate them. Despite numerous efforts to reform the generator interconnection process, these delays will persist unless more transmission is built.
Transmission is not only a solution to congestion, it is also a cornerstone of grid resilience. More frequent and intense extreme weather events are impacting utilities’ abilities to keep the lights on. Smoke from catastrophic wildfires in the West threatens transmission lines, category five hurricanes batter poles and wires, and extreme heat and cold are pushing the grid to the brink.
Expanding transmission capacity enhances redundancy, enabling operators to keep the lights on even when parts of the system fail. As we witnessed during Winter Storm Uri, regions
Permitting reform is equally critical. FERC already has backstop siting authority to approve certain transmission projects when states fail to act or reject projects, but this process should be streamlined to allow FERC to act more quickly on critical projects. Additionally, permitting reforms must expedite the siting of transmission projects that traverse federal land and establish interregional planning requirements with fair and reasonable cost allocation frameworks, such as those proposed in the Manchin-Barrasso permitting bill.
While substantial investment in new transmission infrastructure is essential, it takes time to add new capacity. To address immediate reliability challenges, Congress, FERC and the Department of Energy need to implement programs that encourage and require transmission owners to invest in grid-enhancing technologies, such as dynamic line ratings and reconductoring. These innovations can squeeze more out of existing transmission lines and deliver much needed near-term relief.
We depend on electricity for every aspect of modern life, from daily conveniences to a robust economy and national security. The new Administration and Congress must prioritize creating a transmission grid capable of meeting these demands. A reliable, affordable, and resilient grid is not just an energy issue – it is a national imperative.
RICH GLICK is principal at GQS New Energy Strategies and former FERC chairman. This perspective first appeared in the WIRES Fall 2024 Newsletter.
