Energy industry expert and author, Peter Kelly-Detwiler, Dennis Elsenbeck, head of the energy practice at Phillips, Lytle LLP and former VP at National Grid, and Brett Willitt, head of product at ikeGPS and grid structural analysis expert, continue their discussion on how electric utility leaders can tackle some of the most pressing challenges facing the industry. In this episode, they explore how the electric system planning model is changing and how adopting a proactive, data-driven overhead asset management strategy reduces reactive maintenance, strengthens rate case filings, and improves cost recovery.

Meet Our Speakers

• Peter Kelly-Detwiler has over 35 years of experience in the energy industry. Former leader of Constellation Energy’s Demand response team, he’s currently a leading consultant, researcher, speaker and trainer in the electric industry. He provides strategic advice to clients and investors, helping them to navigate the rapid evolution and complexities of the electric power grid. His book on the transformation of electric power markets – The Energy Switch: How Companies and Customers Are Transforming the Electrical Grid and the Future of Power – was published in June 2021.
• Dennis Elsenbeck is Head of Energy and Sustainability at Phillips, Lytle LLP Energy Consulting Services. Dennis spent 29 years at National Grid in Western New York where he was a former Regional ​Director. In his current role, he provides legal services to energy service providers, helping them understand the requirements of New York’s Climate Leadership & Community Protection Act. Dennis has a deep understanding of the challenges facing a growing distribution grid that must also cope with the impacts of a changing climate.
• Brett Willitt is Senior Vice President of Product for ikeGPS. Brett has more than 25 years of grid asset management experience and is widely considered one of the leading structural analysis and structure management experts in the US. He holds a BS in Civil Engineering from Clarkson University.

See the latest insights on data acquisition and structural analysis from the ikeGPS experts.

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Video Transcript

Peter Kelly-Detwiler: Hello, I’m Peter Kelly Detweiler, principal of Northridge Energy Partners. In this video chat, we’ll continue our discussion of challenges and opportunities facing power delivery leaders at electric distribution utilities.

I’d like to welcome back Dennis Elsenbeck, head of Energy and Sustainability, Phillips Lytle LLP, and longtime leader at National Grid, and Brett Willitt, senior vice president of product at ikeGPS. Brett is one of the leading structural analysis and grid asset management experts in the US. Thanks for being here, and I look forward to hearing more from each of you.

In our last web chat, we discussed how change and its disruption are forcing electric utilities to rethink electric models and processes, especially in the power delivery and T&D function.

Dennis, if I can start with you, how do you see the traditional model of grid planning changing as a result of pressures and disruptions such as climate change, load growth, and aging infrastructure?

Dennis Elsenbeck: Thanks, Peter. It’s a great observation. Modeling is changing. When we look back, the traditional model of electric system planning related a great deal to age of the system, number of outages, outage duration, storm hardening processes, and how we can control quality of power from a utility point of view.

Utilities also included known economic activity, and they designed to an adjusted peak demand, which in the distribution system occurs between, let’s say 2 and 5 o’clock, which then of course, impacts everything upstream through area substations, transmission, and supply balancing.

Lately, priority has shifted modeling to respond to climate policy, mainly to achieve climate change objectives, renewable energy, and the shift from a fossil to an electric economy, which by some accounts would increase electric demand by 50% or more across many distribution feeders already constrained by capacity and thermal limitations.

To stress the impact of climate policy, New York is a good example because New York’s line items that the utilities charge for the recovery of climate-related programs in the electric bill is now approximately 60% of the bottom-line utility delivery charge. This doesn’t even address disadvantaged community revitalization nor demands on the electric system due to market interest in AI data centers, semiconductors, and advanced manufacturing.

The typical utility has miles of distribution lines, thousands of distribution poles. They’re either owned or or shared, thousands of substations or pole-top transformers. When climate consultants indicate such an aggressive demand, this places every piece of electric distribution equipment at risk. Without sound data, where does the utility start? What community or neighborhood gets the upgrades in a timely manner? And how do you value potential non-wire alternatives like battery or thermal storage at the point of use? How about microgrids, utility system replacement based on traditional age condition versus the gradual unplanned demand increases due to electrifications of the market.

Data needs to be the driver if we are to respond to these new conditions while protecting true system-related costs passed on to the consumer, the ratepayer.

PKD: Thanks for painting a picture of some astounding complexity.

Brett, how does this impact The issue of overhead distribution asset management, in what ways can data affect how utilities manage their physical assets?

Brett Willitt: To some of Dennis’s points, we’re seeing a myriad of challenges when it comes to the physical grid. Dennis spoke a lot about some of the impacts on the electrical side. It’s a two-sided coin. There’s the electrical elements of our grid, and then there’s actually the physical components that are supporting it.

While many utilities – most utilities, you could argue – have really rich data points about the electrical grid and electrical performance of the grid, they have surprisingly little structural intelligence about the physical assets holding up and supporting the grid.

We’re talking about millions of poles representing a really significant portion of their physical assets. The challenge in my mind isn’t just about the data, it’s that the engineering, operation, and asset management planning teams are often working within different siloed systems and using a different set of assumptions.

At IKE, we’re unifying and providing a unified structural mechanism and means so everyone can act in a unified way in making decisions about where to invest in the grid. Instead of replacing assets, making assumptions, we’re able to provide line of sight that ultimately is allowing them to invest in proactive maintenance and investments in the grid. That’s the difference, I think, between planned maintenance and emergency response. At the end of the day, we can bring this down to both public and worker safety, and it’s about helping utilities avoid the liability, service disruptions, outages, and the regulatory scrutiny that can come as a result of preventable accidents related to the physical grid.

PKD: Well, thanks. There’s certainly a ton here to unpack, and we could easily do an hour, 1.5 hour webinar on this, but we’re trying to keep this short. So I’m just gonna ask you each one final question here for both of you.

How does adopting a proactive data-driven approach to processes like managing overhead assets impact cost recovery, that rate base, and how the utilities actually go out there and get their investments reimbursed? Let’s start with you, Dennis.

DE: The key phrase of your question, in my humble opinion, is proactive.

Now, there’s a number of lessons to be learned from the results of past utility when we all were doing integrated resource planning and then energy policies in the more aggressive climate-focused or, let’s say, high growth states. It is inevitable that we start seeing utilities calling for more demand response, so that they can methodically upgrade the electric system.

We need to be mindful that announcements to delay charging electric vehicles, shutting down businesses during certain demand periods, shutting down air conditionings, these are warning signs that we lost sight of the resiliency of the electric system. A fossil-to-electric transition is overwhelming the electric distribution system along with related cost structures.

This is where we need more data as utilities cannot redo the entire distribution system overnight. They need to know where their hot spots are and prioritize their planning to maintain some control of demand profiles, short and long-term integrated resource planning, rate structure, and cost recovery.

Additionally, utilities are constantly under prudency reviews via their regulator, and in part the legislature, with respect to the way they are investing ratepayer dollars. Good and prudent reviews result in a seamless recovery of the dollars invested to ensure shareholder value with a close eye on the unit cost of energy for the consumer.

A sound data collection structure, in support of a rate filing or regulatory order, protects the utility while also providing the most optimum infrastructure plan that balances cost to the ratepayer, maintenance of the shareholder value, and system resiliency, despite the externalities of changes in energy policy.

Data – as close to real time – must be the root framework that dictates T&D planning going forward, or we are all traveling blind.

PKD: Thank you. Brett, additional color you’d like to add to those comments from Dennis?

BW: I agree with Dennis. From an overhead infrastructure standpoint, poles just aren’t infrastructure. They’re a core component of that rate base. The utility pole market alone is valued at almost $60 billion. That just shows the scale of this critical infrastructure.

When utilities can demonstrate understanding about the useful life or the state of these assets, it strengthens every rate case filing.

As Dennis said, regulators are increasingly expecting utilities to be able to demonstrate why specific investments are needed now versus later. Having the structural insight and structural intelligence transforms that conversation from “we think” to “we know.” That includes analytical assessment of these assets, So by knowing exactly which poles are at risk or where in their system areas are at risk, they can now bundle investments strategically, maybe at a geographic level or coordinating with other CapEx investment work and avoiding that really premium OpEx reactive maintenance work that we all want to avoid.

PKD: Well, thank you. Once again, you’ve both given us a lot to think about, especially as it relates to the unsung hero of the industry, that humble utility pole we all drive by and don’t even see.

With the right data and intelligent approaches, we now have new tools to help utilities manage and optimize those costs in the midst of this challenging, ongoing energy transition.

Thank you both very much for providing your insights on this really important matter.

Peter Kelly-Detwiler has over 35 years of experience in the energy industry. Former leader of Constellation Energy’s Demand response team, he’s currently a leading consultant, researcher, speaker and trainer in the electric industry. He provides strategic advice to clients and investors, helping them to navigate the rapid evolution and complexities of the electric power grid. His book on the transformation of electric power markets – “The Energy Switch: How Companies and Customers Are Transforming the Electrical Grid and the Future of Power” – was published in June 2021.

The post Video Chat: Challenges and Opportunities for Power Delivery Leaders (Part 2) appeared first on ikeGPS.

Energy industry expert and author, Peter Kelly-Detwiler, moderates a discussion with Dennis Elsenbeck, head of the energy practice at Phillips, Lytle LLP and former VP at National Grid, and Brett Willitt, grid structural analysis expert and head of product at ikeGPS, on the key drivers of change in the energy industry and how electric utilities can adopt more creative approaches to managing T&D assets. In this video chat, they explore how harmonizing grid technology investments can help utilities get the most out of their CapEx programs while increasing safety and improving service reliability.

Meet Our Speakers

• Peter Kelly-Detwiler has over 35 years of experience in the energy industry. Former leader of Constellation Energy’s Demand response team, he’s currently a leading consultant, researcher, speaker and trainer in the electric industry. He provides strategic advice to clients and investors, helping them to navigate the rapid evolution and complexities of the electric power grid. His book on the transformation of electric power markets – The Energy Switch: How Companies and Customers Are Transforming the Electrical Grid and the Future of Power – was published in June 2021.
• Dennis Elsenbeck is Head of Energy and Sustainability at Phillips, Lytle LLP Energy Consulting Services. Dennis spent 29 years at National Grid in Western New York where he was a former Regional ​Director. In his current role, he provides legal services to energy service providers, helping them understand the requirements of New York’s Climate Leadership & Community Protection Act. Dennis has a deep understanding of the challenges facing a growing distribution grid that must also cope with the impacts of a changing climate.
• Brett Willitt is Senior Vice President of Product for ikeGPS. Brett has more than 25 years of grid asset management experience and is widely considered one of the leading structural analysis and structure management experts in the US. He holds a BS in Civil Engineering from Clarkson University.

See the latest insights on data acquisition and structural analysis from the ikeGPS experts.

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Video Transcript

Peter Kelly-Detwiler: Hello, I’m Peter Kelly-Detwiler, Principal of Northbridge Energy Partners, and in this video chat, we’ll be discussing the challenges and opportunities facing power delivery leaders and electric distribution utilities.

To help us sort through this important topic, we have Dennis Elsenbeck, Head of Energy and Sustainability at Philips Lytle LLP Energy Consulting Services. Dennis spent 29 years at National Grid in Western New York, where he was a former VP. For the past eight years, Dennis has headed the energy practice for Philips Lytle, providing legal services to energy service providers and helping them to understand the requirements of New York’s Climate Leadership and Community Protection Act. Dennis has a deep understanding of the challenges facing a growing distribution grid that must also cope with the impacts of a changing climate.

Joining us as well, we have Brett Willitt, a Senior Vice President of Product for ikeGPS. Brett has held multiple positions of leadership during his more than 25 years of grid asset management experience. His electric utility and communications industry experience was a springboard for a shift into the software and technology space, working on utility sector-focused solutions, including SPIDA software, which was acquired by Bentley Systems, and Osmose Utility Services. He’s widely considered one of the leading structural analysis and structural management experts in the United States.

So for our first question, we’ve all heard that the energy industry is experiencing disruption and change on many fronts. And Dennis, I’d like to start with you and hear your thoughts on the broad challenges the industry is facing, particularly with respect to the power delivery function and how those challenges are shifting priorities and processes in the utility industry.

Dennis Elsenbeck: Thank you, Peter. The traditional manner in which utilities perform T&D is based predominantly on the age of the system, the deterioration of the system, outages, expected load projections, and so on. But what we’re witnessing lately is this unprecedented intrusion that is policy-based on the T&D planning process, one of which certainly is climate change, which looks at a transition from a fossil to an electric economy with little regard to capacity or resiliency of the actual system itself.

Then there’s economic development policies that are prompted by the market demand of AI, data centers, chips, semiconductors, et cetera. That is represented by high demand, high load factor, and high power quality needs. They’re an opportunity for growth if we can capture them. But in a lot of ways, that type of attribute for that type of industry goes against some of the climate policies and attributes, mainly the intermittency of renewable energy.

So that has to be considered as we go forward or we could actually disrupt the stability of the system itself. We’re going to need higher level of real-time data, not just static data, from the point of supply to the point of delivery. This is not a time for guessing.

The utilities will rely on creativity, the innovation of their engineering team, data collection, and must view planning from a 24/7 perspective. Via the delivery system based on load factors is no longer suitable. It has to look at a 24/7 operation. And as we introduce more and more distributed energy resources into the system, balancing will become more and more complex, leading to the need for AI at the utility and the independent system operator level.

PKD: Thank you. And Brett, coming from your unique perspective, how do you see this unfolding and how do these shifting priorities that utilities are facing impact that physical grid that Dennis talked about?

Brett Willitt: Thanks, Peter. I think it’s really interesting. As Dennis touched on, we’re witnessing a lot of things converging all at once. We’ve got aging infrastructure that’s really now tasked with supporting the interconnection of renewables, increased load demand on the grid, as well as all these climate challenges. So we’re seeing utilities put together these really comprehensive CapEx programs that are at the tipping point of really, truly transforming the grid.

As they’re formulating these programs, I would strongly recommend that the utilities look for ways to invest and optimize their technology choices, since really that’s going to be the foundation and underpin the entire execution. So making that kind of a front and center conscientious choice and decision about the tools and the technology that they’re investing in as part of that program execution.

PKD: If we can just follow up on that thread a little bit, Brett, what’s an example of how utilities can better connect and harmonize their technology investments, and how might this help them improve their return on investment?

BW: One thing that we do really well here at IKE is helping utilities manage overhead distribution networks and assets.

What people tend to forget is that today 70 and I’ve heard upwards of 80 percent of our grid infrastructure is still overhead and aerial. When I look at the various programs that utilities are executing around those assets, they tend to be very siloed and functionally run and driven. So we’re putting many people, both contractors and internal resources, into the field in their own bespoke ways to capture and execute on their programs.

Ultimately, what that’s creating is a somewhat volatile situation where we have different qualities of information and data coming in about the grid. Here at IKE, we do really well with this field-to-finish mentality, where we empower our customers to get to the field for safe data collection and capture the data and the imagery necessary to help them make intelligent decisions. We’re aggregating all that back into a single pane of glass where now all parties can collaborate around that data and then ultimately deliver the data downstream to its respective home – be it into a construction work print, if it’s a contractor, or potentially back into GIS, if there’s some type of asset correction that needs to take place.

By leveraging data, ultimately what we’re doing is creating efficiency in the ecosystem that’s really a foundational component for our utility partners, for them to be able to execute all of these respective programs.

PKD: It sounds like connecting the data and technology in that end-to-end manner or field to finish, as you call it, can have a tangible impact on efficiency. Thank you.

Dennis, I know you’re out there all the time talking to utilities. What points do you want to add with respect to technology and ROI and how to think about that?

DE: As I mentioned a little earlier, between climate change, economic development load growth opportunities, and AI data center and chips, the traditional CapEx model is under a great deal of pressure as utilities seek to balance these policy-based priorities with some of their major tenets, and that is obligation to serve – the delivery of safe, reliable service. All of this has to be performed under an affordable energy umbrella.

The challenge is real. And if you look at internal utility structures, their organizations, they could be comprised of a multitude of different silos that now need to be melded together going forward. Whether it be public relations, government relations, engineering, and even account management, they need to be responsible for more integration of market-based data.

It needs to actually be formalized within the T&D planning process, not just a good to know, because the engineers are designing these systems based on a much more progressive economy than we’re facing. Data points need to be integrated in real-time delivery systems with manageable load profiles in a format that like utility engineers are designing those systems of the future to ensure that energy policy embraces a much more efficient, resilient energy market system driven by market demand, not simple policies.

So melding real-time data with projected load growth, climate-based resources, the rise of distributed energy resources, we need to think about how to stabilize the electric system because that’s going to be key going forward, or we all risk looking at brownouts and unstable electric systems. Also we’ll actually miss the opportunity to drive down unit costs as we bring in these larger loads combined with the climate so that they all contribute to the fixed cost of the T&D process.

As a society, we need to accept the challenge of how we manage our electric system. To do that, I think policymakers must turn to utilities, allow them to lead this conversation and get away from having them follow or chase policy trends.

PKD: Brett, you mentioned before so much of this is overhead, I’d love to cycle back to that space where you’re looking at what’s happening specifically at the pole level. Certainly, climate is one of those pieces there, but what are the value-added benefits you see when you focus on that particular space?

BW: What I heard Dennis talking about is that there’s a lot of stakeholders invested in these assets, both internal and external.

Again, I think the value is in the data. By placing data into an environment where it can be orchestrated and then used for collaboration between all these stakeholders is really the foundation for business execution and velocity, because ultimately it’s about sustaining and improving the grid. We’re all here for different reasons and drivers. There’s a lot of noise respectively right now that comes from both internal organizations and external. That creates friction and slowdown. If we can optimize and leverage the data, it’s kind of almost like a baseline and a benchmark for decision making and program execution. That’s going to be key.

As an example, we can talk about joint use, which is the collaboration between pole owner and pole attacher. There’s an opportunity there, because when you have an attacher that’s looking to execute their program, if there’s a disconnect between the quality of the asset information – such as “where are my poles located” or “what’s the state of those assets” – obviously, that’s friction for both parties and a challenge. There’s an opportunity to marry around the data for collaborative execution and velocity.

I can look at a utility’s groundline pole inspection program, which is looking at a conditional assessment, making a determination on whether a utility pole needs to be replaced. Too often, we’re seeing utilities simply take the output of those pole inspection programs and go out for a like-for-like replacement. There’s an opportunity by leveraging the data to effectively run that through additional structural analysis and using purpose-built AI to look for trends and patterns across the data.

Ultimately, it’s leveraging the data to better enhance various programs in a common place.

PKD: It strikes me in this very brief conversation that this is not your grandfather’s utility anymore, nor even your father’s utility at this point.

We’re talking about cyber-physical entities, where we need accurate data that we turn into actionable, useful information that gives us the situational awareness we need moving forward. You’ve both given us a great deal to think about in this short conversation, and how utilities across North America need to rethink their approaches to a lot of these critical issues at a time when electricity has never been more vitally important in driving our economy. Thank you for your insights today.

Peter Kelly-Detwiler has over 35 years of experience in the energy industry. Former leader of Constellation Energy’s Demand response team, he’s currently a leading consultant, researcher, speaker and trainer in the electric industry. He provides strategic advice to clients and investors, helping them to navigate the rapid evolution and complexities of the electric power grid. His book on the transformation of electric power markets – “The Energy Switch: How Companies and Customers Are Transforming the Electrical Grid and the Future of Power” – was published in June 2021.

The post Video Chat: Challenges and Opportunities for Power Delivery Leaders (Part 1) appeared first on ikeGPS.

DISTRIBUTECH is one of the events I look forward to the most each year. It’s the best opportunity to engage with electric utility leaders in one place and showcase the industry’s latest advancements.

The IKE Team had a lot to showcase in that regard. We continue to innovate to deliver solutions that empower utilities to revolutionize their overhead asset management and ultimately support a safe, reliable, intelligent grid. In case you missed the conference, I thought I would recap our latest developments and capabilities:

IKE PoleForeman

This past year, 8 of the 10 largest utilities migrated to our latest and greatest version of our pole loading analysis software. We shared what’s coming in our next quarter release, supported the migration of the remaining few customers, and had numerous new potential customers learn why now is the time to make the migration to our easy-to-use software.

IKE Office Pro

The leader in field data collection that delivers safety, lower total cost with one-person operation, and countless back office and workflow automations continues to add new functionality and capabilities, including:

Make-Ready Engineering Clearance Check with Vertical Separation

Our new vertical separation feature provides a quick visual confirmation to ensure the separation between two attachments meets your requirements. Admins can set new or adjust existing clearance thresholds in the form builder, allowing users to easily verify that their as-built or proposed pole attachment measurements comply (green check) or do not comply (red X) with the requirements.

From Field to Structural Analysis with the IKE Office Pro and IKE PoleForeman Integration

Collecting accurate field data with the IKE Device and analyzing structures with IKE PoleForeman is streamlined with our integration between IKE Office Pro and IKE PoleForeman. Forms are presented intuitively, matching the field workflow and naming conventions from the IKE PoleForeman library. Instead of manually building structures in IKE PoleForeman, you can import detailed as-built pole lines, including framings, span connectivity, and elevations for poles and anchors. The 3D models within IKE PoleForeman provide visual QC, ensuring accurate structure modeling. Staying within the ecosystem also offers advantages in product support and training.

Workflow Tracking with Configurable Map Statuses

Configure the map display of your pole locations in IKE Office Pro and bulk update their status to track where they are in your workflow. This provides instant visibility and broad support for project and work monitoring and tracking.

Import Existing Data and Bulk Edit with Excel Import

Getting data into IKE Office Pro, including all pole and equipment details, or making bulk edits has never been easier. A wire size was input incorrectly on 300 poles? No problem. Make the changes quickly in the importable spreadsheet. New imports and bulk edits to existing data can all be done from the familiar Excel interface.

Pole Revision History

Need to revisit a past collection for another project or to perform internal QC? With IKE Office pole revision history, you can easily revisit pole collections without losing track of any edits and revert as needed. Quickly move between versions confidently and know your changes are never lost.

Customizable Dashboards for Project Management

Custom-built dashboards can create intelligence out of any piece of data from IKE to allow you to make better decisions and manage teams like never before.

We hope to see you at next year’s DISTRIBUTECH in San Diego!

Schedule a demo to see how IKE’s technology empowers utilities to revolutionize their overhead asset management.

Request a Demo

Chris DeJohn, Senior Vice President of Sales at ikeGPS, has a wealth of experience in enterprise, communications, and utility markets. Throughout his career, he led teams in the emergence and technology transformation of some of the world’s largest network and utility infrastructures. Chris leads IKE’s customer-facing teams in applying our industry-leading technologies to guide customers in navigating this evolution.

The post In case we missed you at DISTRIBUTECH… appeared first on ikeGPS.

Top-performing utilities are taking a comprehensive approach to resilience, including proactive strategies, data-driven decision-making, and tapping into new technologies. Overhead distribution asset management plays a vital role in this approach.

We identified three best practices in managing overhead infrastructure that are key to successful resilience programs:

1) Conduct a Vulnerability Assessment

The first step towards a resilient grid is understanding its weaknesses. A thorough vulnerability study is crucial for identifying and prioritizing risks. This involves:

• Understanding asset health and prioritizing vulnerabilities: Assessing pole load utilization is good way to get a baseline for structural health – either system-wide or in targeted areas. Advanced structural analysis tools like IKE PoleForeman provide a simple way to complete load calculations in various scenarios and ensure your overhead distribution assets comply with safety codes like the National Electrical Safety Code (NESC). Identifying at-risk assets with high consequence ratings, such as those involving critical infrastructure, can help with prioritizing resilience improvements.
• Accounting for emerging weather patterns from changing climate conditions: It’s important to also consider the impact of emergent models on climate conditions such as extreme wind and ice, wildfire and flood zones, and changing energy demands.
• Analyzing historical storm data: Understand historical weather events and asset impacts as they can identify discrete geographic areas prone to extreme weather events or underperforming asset classes. Conduct targeted structural assessments in those areas.

By understanding asset integrity and specific risks to infrastructure, utilities can prioritize preparedness initiatives and allocate resources more effectively.

2) Use Advanced Data Collection and Analysis Tools in Inspection Programs

Regular inspections are essential for maintaining grid health, and advanced data collection and analysis tools are transforming these programs. Utilities can gain a comprehensive view of network conditions by:

• Carrying out routine inspections.
• Shifting toward predictive maintenance.
• Making infrastructure upgrades that are planned, purposeful, and prioritized.

Tools like IKE Office Pro enhance data accuracy and consistency, creating a digital record of grid infrastructure. Structural analysis software like IKE PoleForeman enables utilities to quickly assess load case requirements and ensure consistent application of design standards, leading to faster decision-making. This data-driven approach supports strategic decisions like reinforcing power lines in high-wind areas, replacing aging poles, and upgrading equipment in flood-prone zones.

3) Tap into Emerging Data-Driven Technologies

Modern technologies offer significant opportunities to enhance grid resilience. For example, AI and machine learning can help identify patterns in asset data and historical events to produce predictions that help inform utility programs and spend.

Advanced pole data acquisition and analysis tools provide the precise, structured data needed for accurate machine learning models. Detailed measurements and imagery of utility poles, structures, and surrounding environments are crucial inputs for AI models. Standardizing field-collected data ensures consistency across datasets, which is critical for training AI models and integrating with other data sources.

By embracing these data-centric technologies, utilities can proactively address vulnerabilities and build a more resilient grid.

Learn how IKE can help support grid resilience with advanced pole data and structural analysis

Brett Willitt is a Senior Vice President of Product for ikeGPS. Brett has more than 25 years of grid asset management experience and is widely considered one of the leading structural analysis and structure management experts in the US. He holds a BS in Civil Engineering from Clarkson University.

The post Three overhead asset management best practices that support grid resilience appeared first on ikeGPS.

Pole loading analysis (PLA) software was designed to help reduce the tedious, error-prone, manual effort involved and help ensure accuracy and consistency. There are a number of software options designed with these goals in mind, but they are not all created equal.

There are three important factors electric utilities should consider when selecting a PLA solution to help maintain the integrity of the grid:

1) Built on a foundation of line design and utility standards

Line design concepts and standards are the foundation of structural analysis. They have been developed over time to serve a critical purpose: Ensuring safe and reliable operation of the electrical grid.

Selecting PLA software that has this strong foundation in line design helps drive adherence to standards, simplify change management, and streamline collaboration with third parties (e.g. engineering firms and joint-use attachers). A common pain point for electric utilities when it comes to using PLA software is preventing outdated or unapproved versions of material libraries and analysis settings from circulating.

IKE PoleForeman was created by Malcolm Young, a structural analysis expert and former power delivery distribution design engineer, who knew these pain points well. He designed the software with an intense focus on the concepts of line design and a goal to minimize the change management burden on utilities while driving compliance to the NESC and organizational standards. IKE PoleForeman boasts easy-to-use templates and framings, based on utility standards, to help achieve these goals. Coupled with a user-friendly web portal to manage and distribute material libraries (conductors, equipment, etc.) and engineering standards, IKE PoleForeman makes it seamless to standardize PLA operations across your organization and drive consistency with third parties.

2) Advanced modeling and visualization

3D visualization is becoming the standard for modeling overhead infrastructure. PLA solutions with advanced visualization capabilities enable your team to design new infrastructure efficiently, including constructing detailed as-built and make-ready models. Having a detailed view of pole structures and their surroundings streamlines clearance checks, aids in quality control, and helps ensure you maintain reliable structural models.

IKE PoleForeman features advanced 3D modeling, presenting users with both single-pole and full-span views. With seamless navigation, users can identify potential clearance issues at the pole, along the span, or in reference to foreign structures. Users can quickly alter attachment heights, line angles, and model new equipment additions that are reflected in the real-time 3D model, giving users confidence that their model is constructed correctly.

3) User-friendly interface

PLA software that is intuitive and consistent creates a seamless user experience and promotes efficient use for both new and experienced users. Choosing a user-friendly solution will allow your team to focus on design and structural analysis rather than struggling with complex interfaces.

IKE PoleForeman requires minimal training and provides easy-to-use templates and framings based on your organization’s standards. It is also designed to optimize workflows – enabling data to be used by other departments, stored, and disseminated seamlessly.

Conclusion

When selecting a PLA solution, electric utilities should consider not only the capabilities and ease of use but also whether it helps you conform to internal standards and comply with safety codes, while reducing the impact of change management across your organization. Top-performing utilities recognize these factors, which is why IKE PoleForeman is the PLA standard for eight out of the 10 largest IOU’s.

Learn why IKE PoleForeman is the most trusted pole loading analysis software

Matt Cain is a Director of Product Management for ikeGPS. Matt has spent more than 17 years in the utility and software industries with experience in field data collection, training, software implementation, and product management. He holds a BA in Integrated Social Studies from The Ohio State University.

The post Three things electric utilities should consider when selecting pole loading analysis software appeared first on ikeGPS.

The abandoned poles present safety risks, such as being more prone to falling due to age/integrity, as well as create a nuisance for property owners and eyesore for the general public. Because these double poles require extra precautions, they may also cause delays in maintenance or repair work and contribute to inefficient utility management practices.

Utility pole change-outs occur for several reasons:

1. Aging and deterioration: Over time, poles made from wood or other materials degrade due to weather exposure, insects, or rot.
2. Damage: Poles may be damaged by car accidents, storms, or other incidents that compromise their structural integrity.
3. Infrastructure upgrades: Newer, taller, or stronger poles may be required to support additional equipment or higher power loads due to increasing energy demand or new fiber or other communication technology like 5G.
4. Regulatory compliance: Utilities must ensure poles meet safety standards such as those set by the National Electrical Safety Code (NESC).
5. Rearrangement of utilities: If multiple utilities share a pole, one company’s changes may necessitate replacing the entire pole to support additional weight or reposition equipment.

Coordination between utilities is often needed to fully remove these poles. When a utility company replaces a pole, it is required to notify all third parties with attachments on the pole, such as telecom providers, to transfer their equipment to the new pole. However, this process can drag on indefinitely if any of the companies fail to act, or contacting the appropriate individuals becomes difficult, leaving the old poles still in place.

The issue of double wood has become a growing concern across various communities across the country. They can linger for years without being removed, leading to safety hazards, communication issues between utility companies, and significant public frustration. Local officials, utility companies, and residents have expressed concerns about the impacts of these poles, with efforts being made to address the problem through both legislative and logistical means.

In Warren, Ohio*, the city is dealing with more than 300 double utility poles. Communication breakdowns among utility companies have been cited as a major reason for the delays in removing old poles. Justin Wooden, senior manager of engineering and construction at Brightspeed, explained to the Tribune Chronicle, that while electronic systems are in place to notify all relevant companies, they are not always effective: “Everything tries to be electronic but doesn’t do it very well.” Different companies often use different systems, creating confusion and inefficiency. This problem is further exacerbated by frequent changes in utility company ownership, as Brightspeed itself has changed names multiple times in the past decade, leading to alerts being sent to defunct email addresses.

The widespread issue of double wood across these regions underscores the need for better coordination, clearer regulation, and technological improvements. With these elements, utilities can begin to obtain accurate double wood records. Recently, tools utilizing artificial intelligence (AI) image analysis have come on the market to assist. IKE’s Double Wood Detective module from IKE Insight offers a powerful solution for managing double wood inspection workflows. IKE Insights’s tool helps utilities efficiently detect and validate instances of double wood, allowing for swift action with minimal field inspections. The tool ensures accurate double wood records, uncovering previously undetected instances and updating pole removal statuses. By leveraging IKE Insight’s pole-specific AI capabilities, utilities can pinpoint double wood across their entire network using street-level imagery, significantly reducing the need for time-consuming in-field assessments.

This not only enhances public and worker safety but also mitigates insurance risks and liabilities. By automating the detection, validation, and change tracking processes, IKE Insight’s Double Wood Detective helps keep utility projects on track while improving operational efficiency.

The proper management of the double wood population enhances the safety of the public as well as utility workers. Prompt identification and corrective action reduces the risk of pole failure, accidents, and injury due to weakness or damage to the pole. Slow corrective action can lead to legal and insurance liabilities. IKE Insight can help mitigate those risks posed by costly lawsuits, claims and insurance premiums due to accidents or property damage.

Maintaining accurate records of pole infrastructure, including double wood, is critical to keep the grid stable and reliable. Improvements in the overall integrity of the electrical grid result from the timely transfer of assets from one pole to the next. Proactively managing double wood instances can help utilities stay compliant with regulatory requirements for removal or replacements. Documentation of this transfer of assets can give the utility the evidence they need in reducing liability.

*“Warren Pushes for Utility Pole Fix”, Tribune Chronicle, June 5, 2024.

Learn more about IKE Insight’s intelligent automation for double wood detection.

John J. Simmins is the Director of the Advanced Power Grid Laboratory at Alfred University. His responsibilities include using the unique facilities to research renewable energy integration research, study on the impact of DERs on grid stability and performance, and research the optimization of energy storage and distributed generation systems . Alfred provides undergraduate and graduate degrees in Renewable Energy Engineering, Mechanical Engineering, as well as Glass and Ceramic Engineering. Dr. Simmins spent ten years at EPRI as a Technical Executive before going to Alfred. At EPRI he studied the intersection of augmented reality, artificial intelligence, and geospatial information systems. He holds a B.S. and Ph.D. in Ceramic Engineering from Alfred University.

The post Double trouble: The lingering problem of ghost poles on America’s power grid appeared first on ikeGPS.

Pole loading analysis (PLA) is a measure of pole condition. It involves understanding, analyzing, and accounting for the forces that affect utility poles—such as equipment weight, the size, strength, and material of the pole, and environmental conditions. PLA prevents overloading, which can lead to failure.

Initial pole loading guidelines established by the electric utility engineering team ensures that a pole, when initially put into service, has sufficient strength to support the applied load. Over time, more load is often applied to the structure as third-parties request to attach to the pole – for example, a communication company adding new fiber or a wireless company adding small cell antennas.

PLA also ensures that poles comply with the National Electric Safety Code (NESC) requirements. The Code sets the bar for mitigating environmental factors and provides the baseline for safety. Performing PLA using NESC load cases will provide an idea about the percent loading on the pole. Poles with utilization percentages at or above 100% do not meet NESC minimum requirements. Therefore, these poles should be replaced, re-enforced, or re-engineered. For example, if a pole is loaded to 110% capacity, the pole may not withstand extreme climatic conditions and could fail.

Why is Pole Loading Analysis Important?

Pole Loading Analysis is a critical component in determining a network’s resiliency and combating the damaging effects of nature. PLA can prevent the failure of poles while also saving pole owners a potential lawsuit.

How to Conduct Pole Loading Analysis:

1) Data Collection

Pole owners or their certified contractors visit the pole to collect data physically. The data includes information about pole properties, type and size of equipment, line angle for the wires, attachment heights, and pole condition.

• The IKE Device is among the most efficient tools for capturing accurate pole data.

2) Analysis

Once the information is collected in the field, a back-office engineer performs PLA to evaluate the pole’s loading to capacity ratio. The first step is calculating the vertical and horizontal loads on the pole caused by the weight of transformers, conductors, and other equipment. This data is then used to understand stresses on the pole, such as the shear force and bending moment. Next, the engineer factors in natural forces acting on the pole, such as wind, ice, and temperature changes and calculates loading capacity. A traditional loading capacity is the ratio of the applied load to the pole strength for a given load case (specific wind speed, ice, and temperature). This ratio gives an idea of any excess strength capacity on the pole and determines if it complies with NESC requirements.

There are a number of PLA software options available designed to reduce the human effort involved by enabling users to quickly build a model of poles as they exist in the field and determining if NESC standards are met. In addition, users can quickly alter attachment heights, line angles, model new equipment additions or changes in weather patterns, and re-analyze loading for a high number of poles in a short period.

• IKE PoleForeman is the most trusted PLA software used by electric utilities.

3) Mitigation

PLA results surface issues and help prioritize system improvements, such as replacing or retrofitting an existing pole. Knowledge of weak points on the grid allows utilities to identify the possible failure points in an outage event and allocate resources to mitigate the hazard.

• The IKE Device is among the most efficient tools for capturing accurate pole data.

How IKE Can Help

Used by some of the largest electric utilities in the country, IKE PoleForeman has been a trusted partner in creating system resilience for more than 20 years. It fully integrates with IKE Office Pro, enabling high volumes of poles to be imported for fast PLA. Additionally, users can export PLA data into the formats and systems most commonly used across the industry.

Request a Demo

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Utility professionals serve as a guiding compass for storm hardening and risk mitigation efforts, using their experience to identify vulnerabilities within the system. Valuable as it may be, experience can only carry us so far – particularly in light of the challenges of an aging workforce. As we face the future of increasingly unpredictable weather patterns and intensifying storms, the future looks daunting.

Fortunately, the industry is moving towards more data-driven decision-making. This is especially important when it comes to managing overhead assets, which are highly vulnerable to storms. There is a massive amount of information that can paint a comprehensive picture of vulnerabilities threatening the grid and assist in prioritizing actions to mitigate them. Top-performing utilities are at the forefront of this shift, having recognized the potential of harnessing data to reach greater levels of understanding structural resilience.

Using disparate data sources such as historical storm data, asset imagery, pole loading analysis, and geographical location, machine learning algorithms can classify levels of risk and identify areas prone to weather-related outages. Informed by insights into network conditions, utilities can proactively implement targeted inspections and, ultimately, predictive maintenance and infrastructure upgrades. Data analytics can drive strategic investments such as pole replacements, power line reinforcement in high-wind zones, or equipment upgrades in flood-prone areas.

Extending the benefits of data-driven resilience to operational efficiency and customer satisfaction affords utilities with additional benefits. Preemptively shoring up vulnerable points in the network reduces the frequency or duration of outages as well as infuses customers with a sense of confidence, underscoring the utility’s commitment to deliver uninterrupted power despite adversity.

This journey towards increased resilience is not without its challenges. The efficacy of predictive analytics hinges on the availability of high-quality data. Investments in technology are essential to ensure the continuous flow of actionable insights.

It also necessitates robust data governance frameworks to ensure the integrity and security of sensitive information. Adherence to stringent privacy regulations and cybersecurity protocols is critical to safeguarding against potential breaches as utilities navigate the complexities of data collection and analysis. Informed decision-making depends on fostering a culture of data literacy and maximizing the use of analytical tools by utility personnel.

Despite the challenges, the industry’s momentum towards greater resilience through data-driven decision-making continues to accelerate. As storms grow in frequency and intensity, the ability to quickly and accurately anticipate, mitigate, and recover from their impact becomes more crucial. As capabilities such as advanced data analysis and machine learning become part of the fabric of the industry, utilities can assess network resilience, identify weak points, and fortify infrastructure before the storms hit. With storm season looming, the imperative to embrace data to improve resilience has never been clearer, propelling the industry towards a future of preparedness and resilience.

Tools like IKE’s suite of pole data and analysis solutions can help utilities develop comprehensive storm-hardening strategies, prioritize projects, ensure NESC compliance, and restore power faster. Learn more.

IKE for Electric Utilities

John J. Simmins is the Executive Director of the NYS Center for Advanced Ceramic Technology (CACT) at Alfred University. In this position, he supports sponsored research for approximately 50 engineering faculty and 50 graduate students. Alfred provides undergraduate and graduate degrees in Renewable Energy Engineering, Mechanical Engineering, as well as Glass and Ceramic Engineering. Dr. Simmins spent ten years at EPRI as a Technical Executive before going to Alfred. At EPRI he studied the intersection of augmented reality, artificial intelligence, and geospatial information systems. He holds a B.S. and Ph.D. in Ceramic Engineering from Alfred University.

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GIS data informs and impacts many different business processes. Electric utilities rely on extensive networks of infrastructure, such as power lines, and telecommunication cables. Geospatial data provides accurate and up-to-date information about the location, condition, and attributes of this infrastructure. With this information, utilities can effectively plan, operate, and maintain their systems, reducing downtime, improving efficiency, and extending the lifespan of assets. 

Geographic Information System (GIS) Data: The Foundation of Modern Utility Work

GIS data serves as the bedrock upon which modern utility work is built. It merges geographical information with data from various sources, providing utility companies with the tools needed to visualize, analyze, and manage their infrastructure effectively. By creating a digital representation (or digital twin) of the physical world, GIS systems enable utility workers to access vital information in real time. 

Using Geographic Information Systems (GIS) as a digital twin is a powerful and innovative approach that allows utilities to create a virtual representation of their physical infrastructure and assets. This digital twin leverages geospatial data and technology to enhance the management, operation, and decision-making processes within the utility sector. 

GIS combines various types of geospatial data, such as maps, satellite imagery, topography, and infrastructure information compiled from field surveys into a unified digital platform. Comprehensive data integration is essential for creating an accurate and detailed digital representation of the utility’s assets. 

While GIS data already plays a crucial role in utility work, its integration with certain emerging technologies promises to usher in even more significant advancements for the industry. This article explores how GIS data, integrated with four groundbreaking technologies, is set to transform the work of utility professionals, making their tasks more efficient, safer, and more responsive to the ever-evolving demands of modern infrastructure.

Augmented Reality (AR): Transforming Field Operations

Augmented Reality (AR) is on the cusp of revolutionizing how utility workers conduct field operations. AR superimposes computer-generated information onto the real-world environment, providing workers with valuable data and instructions (via images and video, for example) directly within their line of sight. AR can also include information provided to the field in the form of tactual signals (called “haptics”) or audio information and signals. These types of AR can improve the safety of the worker when they are in areas where their situational awareness is impaired by intense concentration on a task or in noisy areas where hazards might not be noticed.

When combined with GIS data, AR can significantly enhance the efficiency and safety of utility work:

Enhanced Training and Onboarding:  AR can assist in training new utility workers by providing step-by-step instructions and visual aids. AR can also be used to create immersive and interactive training modules that help bridge the skills gap and reduce the learning curve for newcomers. New utility workers can use AR headsets to learn about equipment, safety procedures, and troubleshooting techniques in a hands-on virtual environment. This not only accelerates the onboarding process but also improves retention and comprehension of critical information. 

AR and Asset Management: GIS data empowers utility companies to maintain comprehensive records of their assets, including pipelines, cables, transformers, and distribution points. Utility workers equipped with AR devices can conduct visual inspections of assets while receiving real-time data on their condition. GIS data aids in pinpointing the asset’s location and history, facilitating quicker and more informed decisions. These digital records enhance asset management by enabling predictive maintenance, reducing downtime, and optimizing resource allocation. 

In complex, unfamiliar situations, or emergencies, field workers can connect with experts remotely who can provide guidance and assistance in real time through AR. By streaming their field of view, workers can receive expert advice, which can be crucial for making quick and informed decisions. Experts can view the worker’s perspective and guide them through troubleshooting or repairs, reducing the need for additional on-site personnel.

Safety Enhancements: AR can overlay safety information and warnings, such as hazard zones and evacuation routes, directly onto the worker’s field of view. This ensures that utility workers are constantly aware of potential risks and can take appropriate precautions.

Internet of Things (IoT): Enabling Smart Infrastructure Monitoring

The Internet of Things (IoT) refers to the network of interconnected devices and sensors that collect and exchange data over the Internet and has begun to reshape utility infrastructure into smart grids and networks. IoT devices and sensors are being deployed throughout utility grids to collect real-time data on asset performance, consumption patterns, and environmental conditions. For utility workers, IoT technologies can be harnessed to transform infrastructure monitoring and maintenance. Utility workers often need access to near real-time data while performing tasks. AR can provide them with a heads-up display that overlays vital, near real-time information onto their field of vision. For example, when repairing a power line, an AR headset can display the voltage, current, and load data, ensuring that workers have accurate information at all times. When integrated with GIS data, IoT offers several key advantages for utility workers:

Smart Sensors: IoT-enabled smart sensors can be installed on utility infrastructure, such as transformers. Often, these smart sensors are just more intelligent and more connected versions of traditional utility field devices. These sensors continuously monitor various parameters like temperature, pressure, and humidity, transmitting real-time data to a central control system. This allows utility companies to detect anomalies and potential issues before they escalate into major problems.

Predictive Maintenance: IoT sensors embedded in utility assets continuously monitor their performance. When combined with GIS data, this information can accurately predict maintenance needs, reducing downtime and costly emergency repairs. With the help of IoT data analytics and machine learning algorithms, utility companies can implement predictive maintenance strategies. By analyzing the data from sensors, the system can predict when equipment is likely to fail, enabling utility workers to schedule maintenance proactively. This approach minimizes downtime and reduces the risk of catastrophic failures.

Near Real-time Monitoring and Control: Utility workers can access real-time data on asset conditions and grid performance through their GIS interfaces. This data enables proactive decision-making, such as rerouting resources in response to emerging issues. IoT technology enables remote monitoring and control of utility infrastructure. Utility workers can access real-time data and control equipment from a centralized location. This capability is particularly valuable for managing assets in remote or hazardous locations, reducing the need for workers to physically visit these sites.

Fault Detection: IoT sensors can identify faults or anomalies in the infrastructure immediately. When integrated with GIS, this information provides precise location data, expediting response times and minimizing service disruptions. GIS data can also enhance customer service by providing accurate information about service areas, outage updates, and estimated restoration times. This transparency fosters customer satisfaction and trust

Resource Optimization: IoT-driven data allows utility companies to optimize resource allocation, ensuring that crews and equipment are deployed where they are needed most, reducing costs, and enhancing service quality. IoT technologies can help utility companies optimize energy consumption by providing insights into usage patterns and identifying areas where energy can be saved. This not only reduces operational costs but also contributes to sustainability efforts.

Environmental Monitoring: IoT sensors can also monitor environmental factors, such as air and water quality. Utility workers can use this data to ensure compliance with environmental regulations and respond quickly to any pollution or contamination incidents.

Drones: Aerial Insights for Utility Workers

Another emerging technology that is revolutionizing utility operations is drones, or Unmanned Aerial Vehicles (UAVs). Drones have rapidly gained prominence in the utility sector, enhancing, and sometimes replacing field crews. These flying devices equipped with cameras and sensors provide utility workers with a unique vantage point for inspecting and maintaining infrastructure. When coupled with GIS data, drones offer a range of benefits:

Infrastructure Inspection: Drones equipped with high-resolution cameras and sensors can capture detailed images and data about utility assets and their surroundings. GIS data integration enables precise location tagging and analysis of this information. Terrestrial field crews often do not have the perspective necessary to inspect the top aspects of utility assets. 

Remote Monitoring: Drones can be deployed to monitor remote and challenging-to-reach locations regularly. As expensive as deploying utility field works is, the drone is a low-cost alternative to reach assets in challenging or dangerous terrain. They can detect issues such as wear and tear, vegetation interference, or structural damage, allowing utility workers to address these problems proactively.

Environmental Impact Assessment: GIS data paired with drone imagery can aid utility companies in assessing the environmental impact of their operations. This information can be crucial for compliance and sustainability initiatives.

Emergency Response: During natural disasters or emergencies, drones can quickly survey affected areas, providing utility companies with critical information to plan and execute emergency response efforts effectively. Dynamic emergencies such as wildfires can quickly turn deadly. Drones can report on the location of the fires and changes in wind patterns caused by the fires that can threaten crews. Drones are being deployed to act as message repeaters where line-of-sight communications technologies are negated by terrain or smoke. 

The Synergy of Technologies: Leveraging GIS Data

While each of these technologies has the potential to revolutionize utility work independently, their true power lies in their synergy with GIS data. GIS serves as the connective tissue, allowing utility workers to harness the full potential of these innovations seamlessly. For instance:

• AR devices can access GIS data to provide real-time information about asset locations and historical data during inspections.
• IoT sensors can transmit data directly into GIS systems, providing utility workers with instant insights into asset performance and conditions.
• Drones can integrate GIS data to create detailed maps and 3D models of infrastructure, aiding in precise planning and maintenance.
• GIS systems can centralize data from all these technologies, offering a comprehensive view of the utility network for efficient decision-making.

IKE Office Pro pole record software can serve as a permanent home for pole data (acting as a GIS) or it can easily integrate data into a central GIS.

Challenges and Considerations

GIS acts as an asset tracking system, a model for planning and operations, an essential work management tool, a situational awareness center, and a single source of truth for many data-dependent systems and subsystems. While the convergence of GIS data and these emerging technologies promises immense benefits for utility workers, several challenges and considerations must be addressed:

Data Accuracy and Completeness According to the EPRI Guidebook on Geospatial Information System (GIS)Data Quality, GIS quality issues are primarily related to:

• Information gaps, such as the omission of key data.
• Redundancies with other systems, such as when data is captured in many systems, and the data is inconsistent or requires duplicate data entry to update.
• Lack of currency with an “as-built” system, such as untimely work order completion, creating a backlog.
• Inaccurately representing an actual system in the field.
• Inaccurate or unavailable land-based data.
• A GIS model that accommodates “bad” data.

Data Security: Utility companies must ensure the security and privacy of sensitive data, particularly when integrating IoT and GIS systems. Robust cybersecurity measures are critical to protect against potential breaches.

Workforce Training: The adoption of these technologies necessitates adequate training for utility workers to maximize their potential. Training programs should be designed to accommodate both existing staff and new recruits.

Regulatory Compliance: Utility companies must navigate complex regulatory environments, which may vary from region to region. Compliance with safety, environmental, and data privacy regulations is paramount.

Initial Investment: Implementing these technologies and integrating them with GIS systems may require a significant upfront investment. Companies need to assess the long-term benefits to justify these costs.

Conclusion

The future of utility work is undergoing a profound transformation driven by Geographic Information System (GIS) data and the integration of emerging technologies. Augmented Reality (AR), the Internet of Things (IoT), Unmanned Aerial Vehicles (UAV), and GIS are converging to enhance the efficiency, safety, and responsiveness of utility operations. By leveraging GIS data, utility workers gain a comprehensive and real-time understanding of their infrastructure, enabling proactive decision-making and streamlined operations.

As utility companies continue to invest in these technologies, they are poised to meet the evolving demands of an increasingly complex and interconnected world. The result will be more reliable, efficient, and sustainable utility services, ultimately benefiting both workers and the communities they serve.

The post Transforming utility work: Three technologies and the power of GIS data appeared first on ikeGPS.

Here are my “Hateful Eight” pain points that I’m sure many electric utilities, engineering firms, and communications companies have experienced:

Pain Point 1: Time-consuming data acquisition

So when you’re using older style methods of fielding that involve the Hasting stick and/ or pencil and paper or even if you’re using a laser rangefinder, the process can be time-consuming.

Fielders strive to be efficient and conventional fielding methods can lead to a fielder spending up to 30 or even 45 minutes at some of these complicated poles just trying to collect the data properly and write it all down.

Pain Point 2: Delay in data upload and analysis

Time is money, especially for communications companies trying to expand broadband reach. Delays between when the fielding data is collected and analyzed in the back office can be detrimental to productivity and profitability.

On some projects I’ve worked on, fielders collected pole data all week and drove to the home office every Friday to upload data.

Driving the data to the office translated to a lot of time wasted between when the data was physically fielded and when it was available to be analyzed.

Pain Point 3: Potential for Mistakes

Using older, more conventional methods of collecting pole data introduces an increased potential for mistakes by way of good old-fashioned human error.

If a fielder has poor handwriting or is in a rush, a two (2) can look a lot like a five (5) which complicates things by introducing inaccuracies that can lead to a safety risk.

Pain Point 4: Data Management

When large amounts of data have been collected, electric utilities can have a difficult time managing it, especially if the data is not stored properly and/or it’s not in any easily searchable format.

Unstructured or improperly stored data creates havoc when it comes time to analyze specific data and prepare it for a project.

Pain Point 5: Outdated data

Outdated data can come into play when it takes a prolonged time for the data to make it from the field to the back office.

And by the time the data is actually analyzed and processed, it could be weeks or months before you know where there’s a lag between the fielding and the back office,

Over that time, things can change in the field.  New attachments can be added to poles, for example. Without proper analysis, and analyzing data that does NOT reflect what’s actually in the field is improper analysis, potential safety issues can creep into play.

Pain Point 6: Lack of Data Verification

If what’s actually in the field isn’t properly reflected in the data, then we also have a lack of data verification.

So without a reliable, single source of digital truth, it can be very confusing for the electric utilities, communication companies, and engineering firms to agree on what is actually in the field and what the conditions are.

Pain Point 7: Compatibility Issues

When data exists in different formats, it can be really hard for individual analysis systems to communicate with each other.

If different companies are using different systems–as is often the case during the joint-use process–a lack of compatibility can make it difficult for these companies to communicate effectively with one another.

Effective communication and collaboration, as we’ve discussed in previous IKE Wire articles, is critical for an efficient joint-use process.

Pain Point 8: Inefficient Workflows

Whether derived from different systems trying to process incompatible data, long spells for data to reach the back office from the field or any other pain point we’ve discussed, inefficient workflows can drastically slow joint-use projects and lead to missed opportunities for broadband expansion.

So what’s the best way to avoid these pain points and streamline the process to ensure efficient workflows?

Take a look at this IKE Quick Cast Webinar to find out

Spencer Hankin is a Senior GIS Manager for ikeGPS.  He has worked in every aspect of OSP aerial engineering including fielding poles in remote areas, building PLAs, managing field teams, and overseeing fiber design projects from start to finish as a lead OSP engineer.  He holds an undergraduate degree in Geology from the University of Colorado and an MBA from the University of Redlands with a concentration in Location Analytics.

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