With ‘Twosday’ upon us (2-2-22), we anticipate a social media frenzy over the novelty of palindrome dates, as well as the next pair of (cleverly-selected) filing deadlines for regional grid operators’ plans for compliance with FERC Order No. 2222 (O. 2222). Here, we use Twosday to refer not only to February 2, but also – more broadly – to a time (likely, years from now) when the concept of O. 2222 is actualized and when its intentions are realized.
FERC Order No. 2222- Where Are We Now
FERC Order No. 2222, issued in September 2020, aims to facilitate distributed energy resources (DERs) participation in regional wholesale markets. The order requires regional grid operators to revise their tariffs, allowing qualified market participants to aggregate DERs and offer their capacity, energy, and ancillary services through participation models that accommodate their unique characteristics. DERs, including electric storage, distributed generation, and demand response, can enhance grid flexibility, resilience, and decarbonization.
To achieve these goals while accounting for DERs’ unique characteristics, FERC directed regional grid operators (shown below*) to revise their tariffs which govern participation in these competitive wholesale markets. Specifically, the operators must enable qualified market participants to aggregate (or bundle) these smaller DERs and offer their capacity, energy, and ancillary services into wholesale markets through ‘participation models’ that accommodate their unique physical and operational characteristics. A ‘participation model’ refers to a set of rules and procedures that provide a path for a given market participant to offer their resources’ services in the market. Presently, many distributed resources including flexible/dispatchable loads, energy storage, and distributed generation, are able to participate in certain wholesale markets, primarily through demand response participation models, which do not adequately account for the range of services that these DERs are technically capable of providing (including, in some cases, injecting energy onto the grid). O.2222 is meant to ensure that market rules enable DERs to provide all services that they are technically capable of providing through aggregation.
*Note: These grid operators are referred to as independent system operators (ISOs) or regional transmission organizations (RTOs). Only FERC-jurisdictional ISOs/RTOs are subject to O. 2222 (this excludes the Canadian territories and ERCOT in Texas).
Originally, RTO/ISOs’ compliance plans (including proposed tariff revisions) were to be filed with FERC by July 19, 2021. CAISO and NYISO – the two ISOs which, at the time of O. 2222’s issuance, already had FERC-approved participation models for DER aggregations – filed timely compliance plans, which are working their way through regulatory review processes (CAISO (Docket No. ER21-2455-000)), NYISO (Docket No. ER21-2460-000)). The four remaining RTOs whose market rules require a greater overhaul to reach compliance requested and have been granted extensions to the original deadline through the Spring of 2022. Details on their progress to date can be found in their stakeholder groups here: PJM, ISO-NE, MISO, SPP. Compliance plans for PJM and ISO-NE are expected to be filed Tuesday, February 1st and Twosday (really, Wednesday) February 2nd (2-2-22), respectively.
To prepare for Twosday today, we need to revisit the idea of value stacking that lies at the core of O. 2222’s expected impacts and understand what electric utilities and other industry actors can do now to promote a smooth and informed transition to compliance.
A Deeper Dive: Podcast Discussion
TRC’s Experts Discuss FERC Order No. 2222
To hear a deeper dive into O. 2222 and its implications for our industry, you may be interested in listening to our recent “TRC Talks Energy” Podcast, where we discuss “the Good, the Bad, and the Ugly” of this historic final rule – including our Senior Policy Advisor’s theory that O. 2222 can be conceptualized as “Uber for Electrons.”
Value Stacking
DERs can be capable of providing various services to their owners and operators, as well as to other market participants and to the grid as a whole. Today, while it is common for resources’ behind-the-meter (BTM) and retail services to be valued in those markets, wholesale market compensation is less accessible, resulting in the under-utilization of services that DERs do or could perform for the bulk power system. Some of these additional services can be extracted from existing resources, maximizing the benefits from investments made to date; in other cases, the prospect of new revenue streams may change the business case dynamics and motivate investment in additional DERs.
Take, for example, my Ecobee smart thermostat. I admit that the primary value of this technology to me is the convenience of adjusting the temperature of my home from the comfort of my own bed by using the Ecobee app on my smart phone. However, this thermostat provides a secondary value to me in managing my retail energy bills. The scheduling and setback functionalities that optimize the operation of my home’s HVAC system save me roughly 10% on my heating and cooling costs each year.
In St. Louis, Missouri, the value stack does not end there. The local electric utility, Ameren Missouri, aggregates these thermostats from thousands of other residential customers, and operates them as a DR resource to reduce load when energy costs are high (putting downward pressure on rates for all of their customers). In exchange for the ability to operate my home’s HVAC system as a DR resource, Ameren Missouri provides me with a one-time payment for enrollment in their retail DR program, as well as an annual performance bonus. While these payments are less substantial than my annual bill savings, they make the economic case for purchasing a smart thermostat even more attractive for residents in my area (Note: There are other opportunities for me to capture value in the retail market, including an optional time-of-use rate, but we’ll set those aside for the sake of this example).
Presently, Ameren Missouri calls on my device for DR events a handful of times per year by increasing my thermostat setpoint by a few degrees for short periods of time. Depending on the compensation they may offer, I might be willing to allow more frequent and/or more significant adjustments, which could benefit the grid (and myself) while continuing to drive down costs for other ratepayers.
Under O. 2222 (depending on yet-to-be finalized compliance plans), distribution utilities like Ameren Missouri as well as possible third-party aggregators could design a program to offer the aggregated capabilities of residential smart thermostats into wholesale energy, capacity, or ancillary services markets, and pass along a portion of the revenue from these bulk system services back to DER owners like me – adding to the value stack for this technology, maximizing the grid benefits derived from existing resources, and strengthening the case for investments in additional DERs.
The Utility POV
This smart thermostat example may have raised red flags for those thinking from the perspective of an electric distribution utility. These utilities are required to maintain distribution grid reliability and make informed, cost-effective plans about necessary system investments. How can this be done effectively when third parties are able to enroll BTM or distribution system-connected resources and operate them at the direction of bulk power system operators, according to wholesale market signals, which may conflict with local system needs?
For certain utilities (both traditionally integrated monopoly utilities and in deregulated jurisdictions, utilities that serve as providers of last resort), there is an additional layer of complication with O.2222. Again, if third parties bring BTM resources directly to wholesale markets (outside of utility retail programs), how can the utilities ensure that this does not create “missing load” in their load forecasts and system-level generation plans, jeopardizing their abilities to ensure all customers can be reliably served?
These are the strongest concerns that we have heard TRC clients express, in response to O. 2222.
Fortunately, we have time to prepare.
First, we need pilots – new ones and syntheses of the findings of projects conducted to date. Surely, the pilots solicited to inform NYISO’s DER Roadmap will have useful lessons to offer to other jurisdictions currently considering topics like the effectiveness of certain metering and telemetry technologies and baseline methodologies for accurately capturing aggregated resource performance. In terms of innovative program designs, the Michigan Public Service Commission has called on the states’ investor-owned utilities to propose tariffs that provide retail and pass-through wholesale values to participants for energy storage resources (Note: this recommendation was made more directly in response to FERC Order No. 841 than O. 2222). The pursuit of attractive program designs like this one will be an important strategy for utilities seeking to retain maximum control of the resources on their distribution grids, at a time when states’ restrictions on the activity of unaffiliated third-party aggregators are in question.
Secondly, as expectations, rules, and requirements guiding market operations evolve in different regions, it will be important to stay on top of the details, including:
- Opt-in provisions for small utilities, and opt-out rights for states to restrict the participation of DR aggregators in those jurisdictions;
- Criteria and processes for utility review of DER interconnection/enrollment and for utility override of ISO/RTO dispatch of distribution system-connected resources;
- Processes for defining and mitigating double counting of services (identifying overlap between retail programs and wholesale market services);
- Expectations for data sharing between aggregators, utilities, and ISO/RTOs for settlement;
And more.
How TRC Can Help
TRC’s Advanced Energy Practice offers advisory and consulting services across the spectrum of O. 2222 compliance topics, from impact/gap assessments, to software architecture review and planning, to DER program planning, design, and implementation for utilities, agencies, and businesses. To learn more, contact advancedenergy@trccompanies.com.
Angela Gordon, Andrea Thompson, and Derek Kirchner also contributed to this article.
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Related Materials
NYISO Pilot Program Guide
NYISO Pilot Program Guide Published October 2, 2017
FERC Order No. 2222
Published February 2, 2022
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Advancing Telecommunication Projects: A Guide for High Level Design
June 6, 2023
TRC has developed utility network Master Plans and designed and architected utility-wide networks
NERC Files Report on Effectiveness on CIP-014 Physical Security Standard
May 25, 2023
On behalf of the North American Electric Reliability Corporation (NERC), its President and CEO Jim Robb, recently presented to the Federal Energy Regulatory Commission (FERC) a summary of NERC’s report on the effectiveness of NERC’s CIP-014 Physical Security Standard. There were almost 1,700 physical security incidents reported to the Electricity-Information Security Analysis Center (E-ISAC) in 2022, an increase of 10.5% from 2021.
FERC Issues Order on Cold Weather Reliability Standards
April 27, 2023
FERC has approved two NERC proposed cold weather-related reliability standards.
Modeling Power System Hosting Capacity
March 31, 2023
As renewable energy development booms, and distributed energy resources (DERs) proliferate across the grid, the demand for a more efficient and timely interconnection process is at an all-time high. To meet regulatory deadlines and satisfy the needs of both developers and customers, utilities must tackle an increasingly complex array of system impact studies, analyses and reports, under ever shrinking timelines.
FERC Orders Internal Network Security Monitoring Rule to be Finalized
March 14, 2023
FERC directed NERC to develop Reliability Standards to implement INSM within trusted CIP environments.
TRC Companies Assisting LS Power Grid Maine with New Transmission Project in Maine
March 2, 2023
TRC Companies announces its role as a consultant in supporting the new transmission project by LS Power Grid Maine.
Insights from the Odessa II Power System Disturbance
February 22, 2023
NERC and TRE release the Odessa II Power System Disturbance Report
Carrots and Sticks for Building Decarbonization: Incentive Programs and Codes & Standards
January 11, 2023
Decarbonization of the U.S. building stock presents an enormous opportunity to enhance the quality of our built environment and combat climate change, given that commercial and residential buildings account for over 30% of GHG emissions in the U.S. This critical transition – long underway – has recently been catalyzed by the enactment of the Infrastructure Investment and Jobs Act (IIJA) and Inflation Reduction Act (IRA), which promise to bolster the entire clean energy supply chain, including support for the development and enforcement of building energy codes, as well as the introduction of new consumer incentive programs for electric and high-efficiency equipment. As energy utilities and governmental agencies accelerate energy efficiency and decarbonization initiatives for the communities they serve, they are successfully leveraging two important tool sets: 1) Building efficiency and electrification incentive programs 2) Building energy codes, reach codes and appliance standards. Respectively, these are the carrots and sticks of market transformation toward building decarbonization. Presently, governmental initiatives and organizational commitments to decarbonization are motivating industry practitioners to apply these toolsets more aggressively, to accelerate this transition; as a result, the legacy market interactions between these carrots and sticks are increasingly complex and at times, contested. However, our teams and partners who expertly apply both toolsets – designing and implementing incentive programs and supporting local jurisdictions in advancing their energy codes – believe that they can work together. Contact Us
New FERC Orders Will Change Regulatory Process for Inverter Based Resources
January 9, 2023
The Federal Energy Regulatory Commission (FERC) recently proposed actions to keep the regulatory process and requirements ahead of reliability risks resulting from the accelerated deployment of Inverter Based Resources (IBR) based solar, wind and battery storage projects.
NERC Releases Facilities Ratings Best Practices Report
December 19, 2022
NERC report on best practices for utilities that have encountered facility ratings program challenges.
NERC Files Comments in the FERC Generator Interconnection Notice of Proposed Rulemaking
November 21, 2022
The rulemaking addresses improvements needed to reliably facilitate the power industry’s transition to renewable and distributed generating resources utilizing inverter-based technologies.
NERC Releases Inverter-Based Resource Strategy Plan
October 25, 2022
The North American Electric Reliability Corporation (NERC) recently released an Inverter-Based Resource (IBR) Strategy, which details the steps needed to successfully integrate IBR facilities into the planning and operation of the power system. The strategy was put in place due to the rapid interconnection of IBR systems, which are extensively used for solar and wind generating facilities, including new battery-based energy storage systems and are one of the most significant drivers of power grid transformation. Because of control system inconsistencies, IBR facilities pose well-documented risks to power system reliability when this strategy’s practices are not adhered to. NERC’s plan calls attention to the need for thoughtful integration of IBRs and identifies current and future work required to mitigate reliability risks resulting from the deployment of this technology.
NERC Releases 2022 State of Reliability Report
September 16, 2022
The North American Electric Reliability Corporation (NERC) recently released its 2022 State of Reliability report, which examines power system performance in calendar year 2021 and evaluates reliability performance trends. The 2022 report identified six key findings regarding power system performance that are summarized as follows:
NERC Proposes Implementation Guidance for PRC-019-2
August 22, 2022
NERC has proposed implementation guidance for PRC-019-2, the standard that verifies coordination of generating unit facility or synchronous condenser voltage regulating controls, limit functions, equipment capabilities and protection system settings.
The Use Case Benefits of GIS Modernization for Utilities
August 10, 2022
In 2022, utilities face strong market forces impacting businesses of every size across the country and around the world. Producing and supplying clean energy, ensuring safety, reliability, and resiliency, and delivering exceptional experiences in a digital economy continue to reshape the industry. Prospering in a sustainable, affordable, and competitive energy future requires a data-driven enterprise, which may be why more than 88% of utility executives believe that their organization’s ability to generate business value depends on their technology. Yet the greatest technology challenge today isn’t the ability to generate data. It’s siloed systems. Many utilities maintain multiple enterprise systems, from enterprise resource management (ERP) to enterprise asset management (EAM), work management (WM), advanced distribution management systems (ADMS), supervisory control and data acquisition (SCADA), and building information modeling (BIM). These disparate databases result in redundancy and inaccuracies. And without an integrated data picture, your staff are left to make decisions with an incomplete understanding. But with modern GIS, you gain a connected geospatial enterprise. You can leverage the locational aspect of data in any system to integrate information, people, and processes to achieve business value across every department. As a result, you optimize networks, grow the business, and deliver amazing service using timely, accurate, and complete information. And with mapping and location intelligence embedded in your IT infrastructure, the applications and use cases are limitless. CONTACT US
Revisions to FAC-001 and FAC-002 Submitted for FERC Approval
July 12, 2022
Reliability Standards FAC-001-4 and FAC-002-will resolve uncertainty regarding the meaning of “materially modify” under the currently effective standards.
FERC Order No. 881-A Has Implications for NERC Compliance Programs
June 23, 2022
Updated Order will have significant impact on NERC compliance programs related to both PRC standards and facilities ratings. Utilities should review the Order’s requirements and prepare for changes needed to remain compliant.
Brookings Municipal Utilities Streamlines Processes, Boosts Efficiency with Modern GIS
June 14, 2022
Locana, a global leader in technology consulting and geospatial systems development, announced Brookings Municipal Utilities (BMU) successful deployment of a modern geospatial enterprise leveraging Locana services.
Omaha Metropolitan Utilities District Drives Reliable Operations with Locana Lemur Mobile GIS Solution
June 8, 2022
Locana, a global leader in technology consulting and geospatial systems development, today announced the successful deployment of its LemurSM Solution by Omaha Metropolitan Utilities District (M.U.D.).
NERC’s Revised PRC-024-3 Standard for Inverter-Based Generation Effective in October 2022
May 11, 2022
Changes to PRC-024-3 in support of inverter-based generation performance are going into effect in October of this year. Interconnection programs and documentation procedures may need to be updated in order to maintain compliance.
FERC Issues Notice of Inquiry Regarding Dynamic Line Ratings
April 25, 2022
There are significant technical challenges involved in implementing Dynamic Line Ratings in the planning and operation of utility systems. Utilities should be prepared to modify their NERC compliance programs as necessary to address the potential introduction of DLR in their businesses.
Creating a Culture of Safety During Plant Decommissioning
April 13, 2022
Creating intrinsically motivated safety cultures within nuclear power plants is imperative, especially during the decommissioning process. Employees’ long-standing beliefs and attitudes often determine their decisions and actions, so cultivating a safety-first culture requires commitment and accountability.
Start Your Batteries: Mass Fleet Electrification is Coming (And What We Can do to Prepare)
April 13, 2022
As we plan for and make early investments for fleets, we’ll be paving the way for higher degrees of market penetration of passenger vehicles and other modes of transportation as well.
TRC Selected as Systems Integrator for Otter Tail Power Company’s Advanced Metering Infrastructure Program
April 5, 2022
Otter Tail Power Company selects TRC to serve as systems integrator for their AMI program covering northwestern Minnesota, eastern North Dakota, and northeastern South Dakota.
Webinar Replay: Substation Automation – Best Practices for IEC 61850 Implementation
March 29, 2022
Modernizing utility equipment, standards and processes pays dividends for improved safety, security and reliability. But transitioning to a new high-tech system model can be challenging.
New NERC Guidance Supports the Implementation of Grid Forming Inverters
March 8, 2022
NERC has issued a new report highlighting the key attributes of various inverter controls to support proper implementation and to protect reliability.
NERC Recommends Approaches for Underfrequency Load Shedding Programs
February 24, 2022
In a recently released reliability guideline, NERC recommends additional approaches for Underfrequency Load Shedding (UFLS) program design to help utilities effectively consider the effects of Distributed Energy Resources (DERs). The guidance was developed to address the accelerated transition of the power system to locally installed, decarbonized resources that depend on inverters. These new technologies introduce operational controls issues into the electric grid. UFLS data gathering and analysis methodologies may require modification to address reliability risks.
The Best Process for Transforming Thermal Generation Power Plants
February 9, 2022
Faced with an aging fleet, stricter environmental regulations, reduced costs for natural gas and competition from renewables, more than 600 power plants have been decommissioned in the last 20 years, a pace that will increase with the announced closure of nearly 350 additional plants by 2025.
Ensuring a Just Transition: Optimizing Opportunities for All in the Low-Carbon Future
January 24, 2022
Carbon elimination of the magnitude needed to address climate change requires systems-level change that can only be reached by incremental, ground-up progress, building upon what we have achieved thus far.
NERC and FERC Recommend Protection System Commissioning Improvements
January 18, 2022
Between 18 and 36 percent of reported utility misoperations were attributed to issues that could have been detected through a properly implemented PSC.
FERC & NERC Issue Joint Report on Freeze Reliability Failures
December 15, 2021
The in-depth report outlines twenty-eight recommendations to address freeze reliability failures, including operating practices and recommendations for NERC standards modifications surrounding generator winterization and gas-electric coordination.
Decarbonization: A Systems-Level Challenge and Actions to Address Climate Change
December 7, 2021
Carbon elimination of the magnitude needed to address climate change requires systems-level change that can only be reached by incremental, ground-up progress, building upon what we have achieved thus far.
NERC Accelerates Additional Cold Weather Standards Changes
November 22, 2021
At its November 2021 meeting, NERC’s Board of Trustees took aggressive action to advance critical cold weather Reliability Standards. Most notably, the group approved the 2022-2024 Reliability Standards Development Plan, which prioritizes standards projects for the coming years including a resolution to include new cold weather operations, preparedness and coordination standards as high priority development projects.
PRC-002-2 Disturbance Monitoring and Reporting Standard: Initial Mandatory Implementation Plan Dates Approach
November 18, 2021
The Federal Energy Regulatory Commission approved PRC-002-2 in September, 2015. The initial due date for system studies necessary to identify locations for the collection of disturbance related data under Requirement R1 is January 1, 2017.
10 Takeaways from the COP26 Climate Meeting
November 17, 2021
There are compelling reasons to be optimistic about the outcomes of the COP26 meeting. Notably, agreement among all nations that more needs to be done, by both private and governmental bodies, to contain and mitigate climate change.
The Price of Natural Gas: Onward and Upward or Just a Temporary Blip?
November 12, 2021
Most industry experts agree that weather aside, the global energy and gas markets are likely to remain uncertain with supply and market demand becoming tighter and more challenging to forecast.
Six Considerations for a Successful Utility Network Cloud Implementation
October 26, 2021
For any GIS manager or IT professional tasked with implementing ArcGIS Utility Network (UN), knowing where to start can be daunting. If not properly planned, a UN setup in the cloud can be significantly more expensive and less accessible, stable, and secure.
How Do Energy Storage Systems Work?
October 18, 2021
For more than five decades, TRC has brought efficient, resilient energy systems to the world. We understand the challenges of implementing energy storage projects.
New Potential Compliance Standards Identified at FERC Technical Conference on Reliability
October 18, 2021
With a focus on the reliability impact of extreme weather and the shortcomings of current system planning approaches, both NERC and FERC conference participants opened the door to potential forthcoming compliance standard enhancements or changes.
On the Road to Decarbonization: The Role of All-Source Competitive Solicitations
October 14, 2021
All-Source Competitive Solicitations offer utilities an alternative to centralized planning, construction and dispatch of power supplies, helping to usher in a new era of market-driven technology innovation.
How Does a Distribution Grid Work?
October 2, 2021
Electric distribution systems rely on sophisticated technology to provide power when needed. Electricity is generated on-demand, which means there are often peak periods when providers see a greater need for power and the system must prove responsive.
Amplifying the Next Phase of Fleet Electrification: The Pickup
September 30, 2021
TRC’s analysis for one client fleet shows that even a $70,000 EV can compete on cost with a comparable gas-hybrid vehicle priced at $40,000 – at least in California where upfront and ongoing incentives stack up quickly.
NERC Issues Odessa Texas Disturbance Report
September 29, 2021
While NERC has analyzed multiple similar events in California, this is the first disturbance involving a widespread reduction of PV resource power output observed in the Texas Interconnection.
Pacific Gas and Electric Selects TRC as Program Implementer for New Construction Residential All-Electric and Mixed Fuel Programs
September 27, 2021
Pacific Gas and Electric Company (PG&E) formally announced TRC as the designated lead Program Implementer for the Statewide New Construction (SWNC) Residential All-Electric and Mixed Fuel Programs following a competitive solicitation process.
TRC Digital Selected by Snohomish County Public Utility District to Implement Siemens EnergyIP® Meter Data Management
September 15, 2021
Snohomish PUD selected TRC to implement, integrate and deliver their meter data management system (MDMS) on the Siemens EnergyIP® platform as a part of the utility’s Connect Up program.
FERC Approves Modifications to NERC’s Cold Weather-Related Standards
September 7, 2021
The Federal Energy Regulatory Commission has approved changes to three mandatory NERC Reliability Standards that aim to better prepare the North American power system to withstand extreme cold weather events.
NERC’s Generator Relay Loadability Standard is Now in Effect
August 30, 2021
The Federal Energy Regulatory Commission (FERC) has approved changes to three mandatory NERC Reliability Standards that aim to better prepare the North American power system to withstand extreme cold weather events. All utilities, even those not impacted by recent events, will be required to comply. The modified standards include: EOP-011-2 (Emergency Preparedness and Operations) IRO-010-4 (Reliability Coordinator Data Specification and Collection) TOP-003-5 (Operational Reliability Data) NERC proposed the standards modifications in response to the findings of the NERC FERC Joint Report on the 2018 South Central Cold Weather Event. The changes address the need to winterize facilities; ensure the accurate reporting of design specifications to reliability coordinators for generating units; and the need for balancing authorities and reliability coordinators to be aware of, and plan for, generating units’ limitations during extreme cold weather.
NERC Seeks to Improve GADS Reliability Performance Reporting
August 26, 2021
Under the enabling legislation that created the Electric Reliability Organization, NERC is responsible for assessing the reliable performance of the power system. One way NERC does so is via an industry reporting system for generation and transmission. The Generator Availability Data System (GADS) has been used by NERC and the industry for over 40 years to obtain data on the generation component of the power system[1]. Due to the rapidly changing generating resource mix, it is essential that NERC have comprehensive plant, event, outage and performance data for photovoltaic and wind generation to ensure reliability. As renewable technologies are increasingly deployed, a complete set of generation asset performance statistics is necessary to allow NERC to evaluate the system’s ability to serve load, the performance of the power system and to forecast any potential reliability issues due to resource inadequacy. Therefore, NERC is proposing to make the following enhancements to the GADS data collection process for renewable generation: Add Generator Owners that operate solar photovoltaic facilities of 20 MW or greater to the Generating Availability Data System (referred to as “GADS-PV”); and Expand GADS Wind (“GADS-W”) reporting to include connected energy storage and event reporting.
Prepare for Upcoming NERC Compliance Deadlines
August 20, 2021
With 2020 right around the corner, there are many new NERC standards and standards requirements set to go into effect in the areas of Critical Infrastructure Protection and Transmission Operations and Planning.
TRC Talks – Attaching Telecommunications Fiber in the Supply Space
August 10, 2021
Today’s utility and communications infrastructure is being challenged to support a growing demand for automation, broadband and 5G network services. Attaching fiber in the power distribution or supply space can mitigate risks related to overloading and overcrowding.
Oklahoma Gas & Electric Company uses AI to assess and repair distribution pole damage
August 4, 2021
As part of its grid enhancement program, OG&E will leverage collaborative AI-powered image recognition technology that enables engineers to complete distribution pole inspections with greater accuracy and helps to reduce manual review of images.
