As the power delivery system continues to rapidly evolve due to federal and state decarbonization policy initiatives, Inverter Based Resources (IBRs) are playing central role when it comes to adding new electric generation capacity into the bulk power system (BPS).
To address reliability gaps related to IBR technology in Solar, Wind and Battery Energy Storage applications, FERC has recently issued Order No. 901. Order No. 901 directs NERC to develop new or modified standards that require owners and/or operators to provide accurate data related to facility performance when connected to the BPS. FERC noted that such data is necessary to apply accurate system models so interconnecting utilities can successfully plan, operate and analyze performance of IBRs.
FERC Order No. 901 documents the poor reliability performance of IBRs since 2016 and outlines the reliability gaps that have been detected broadly within four key areas:
As noted in TRC’s previous Regulatory Update on the NERC IBR Webinar Series, NERC has been providing educational resources to help industry technical experts navigate this complex issue. Additionally, NERC released an FAQ document covering the general themes identified in the more than 1,000 comments and questions received throughout the series.
NERC must submit an informational filing within 90 days of the issuance of Order No. 901, including a detailed and comprehensive standards development plan that demonstrates how NERC will prioritize the development of new or modified Reliability Standards to meet the following deadlines over the next three years:
NERC must submit new or modified Reliability Standards that establish IBR performance requirements:
NERC must submit new or modified Reliability Standards addressing:
NERC must submit new or modified Reliability Standards addressing planning and operational studies by requiring:
In its Order FERC stated that NERC should use its discretion to identify the appropriate technical requirements needed to ensure frequency and voltage ride through by registered IBRs during the future standards development process. TRC clients should be aware that NERC has the discretion to consider incorporating or referencing other standards, for example IEEE 2800-2022 – Standard for Interconnection and Interoperability of Inverter-Based Resources (IBRs) Interconnecting with Associated Transmission Electric Power Systems.
To stay ahead of reliability risk issues and the FERC mandated compliance obligations, TRC recommends that utility compliance managers and system planning and interconnection study personnel review the FERC Order No. 901 and assess the implications of the FERC directives to NERC mandatory standards in light of their company’s functional registration(s).
TRC closely follows the national, provincial, and state regulatory trends in all regions of North America. Our approach to power system security, engineering, planning, design, construction and commissioning testing, balances solutions that incorporate industry reliability risk trends, mandatory reliability standard requirements, regulatory guidance, compliance obligations, best practices, operational goals and budgets. With expertise in power system planning, engineering and operations, TRC supports public utilities and private energy providers in their efforts to stay ahead of the regulatory curve and to meet or exceed regulatory requirements as they evolve.
This regulatory update is provided as a service to TRC’s utility clients, helping to keep you informed of forward-looking issues that will impact your company’s electric system reliability risks along with related topics regarding regulatory development, to help you achieve your company’s business goals.
FERC Order No. 901 Published October 19, 2023
IBR Webinar FAQ Published November 27, 2023
IBR related system disturbances Event Report list Published
Our practitioners share their insights and perspectives on the trends and challenges shaping the market.
This update provides details from FERC 2024 staff report from CIP audits, so utilities can improve compliance and reduce security risks.
The North American Electric Reliability Corporation (NERC) recently released its 2024 State of Reliability report, examining power system performance in calendar year 2023.
Facility Ratings play a critical role in the reliable planning and operation of the Bulk Electric System (BES) and yet maintaining compliance with relevant NERC standards remains an industry challenge.
Learn about the recent geomagnetic disturbance which caused stakeholders within the bulk power system to react swiftly to protect grid reliability. Find out the impacts and what NERC and the industry are doing about it.
While utilities often work in technical silos, NERC auditors are trained to cross check compliance evidence and data between interrelated standards.
As part of NERC’s ongoing effort to bolster Critical Infrastructure Protection (CIP) requirements and enable the implementation of a security improvement concept known as virtualization.
While utilities often work in technical silos, NERC auditors are trained to cross check compliance evidence and data between interrelated standards. Working in silos often leads to inadvertent situations where the compliance evidence from one standard is used but inconsistent with information produced or used by other standards. To assure compliance evidence reporting objectives are achieved in each applicable standard and requirement, it is important to identify interrelationships and create a framework where subject matter experts (SMEs) in all technical disciplines consider the evidence data consistency requirements. NERC compliance auditors are also trained to examine process flows and identify whether they are comprehensive or incomplete. Auditors determine the appropriateness of information by examining the quality and completeness of compliance evidence. They examine the relevance, validity, consistency and reliability of evidence used for addressing the audit reliability objectives and supporting their findings and conclusions. If conflicting evidence is found, they will identify this in their formal Regional Entity (RE) audit report findings which could further lead to a compliance violation and related fines. To improve the likelihood of favorable NERC audit compliance outcomes and avoid the need for implementing mitigation plans, individual contributors and SMEs should look at certain cross linked compliance evidence to assure consistency between approaches used to record compliance evidence. Doing so will allow a company to spend more time on executing core reliability duties and enhance company regulatory obligations. Avoid waiting until the RE compliance audits are underway to identify conflicting evidence situations.
NERC has submitted for FERC approval new compliance criteria for the registration of IBRs as part of continuing efforts to address reliability risks. It is critical for renewable energy developers, generation owners and transmission owners to understand the potential implications for interconnection studies and interconnection queues.
NERC has submitted proposed revisions to the EOP-012-2 – Extreme Cold Weather Preparedness and Operations standard, for FERC approval on an expedited basis. The proposed revisions address the remaining key recommendations from the FERC–NERC Joint Inquiry Report into Winter Storm Uri and directives arising from a 2023 FERC Order regarding the previously submitted cold weather standards.
Update to FAC-003-5 Brings Sweeping Changes to Transmission Classifications Starting April 1
Every NERC-registered utility must strive for continuous compliance with their portfolio of applicable NERC Reliability Standards
NERC has submitted its 2024-2026 Reliability Standards Development Plan to the Federal Energy Regulatory Commission (FERC), outlining its current priorities and future standard development plans to protect the reliability of the Bulk Power System over the next three years.
NERC and FERC have released their final report on Winter Storm Elliott which provides reinforcement for recommendations in prior cold weather-related disturbance event reports. The Report identifies critical reliability performance shortcomings and the reliability related near misses. NERC states that a crisis was “narrowly dodged.” The Report outlines the steps the industry must take to avoid a repeat in the future.
Inverter Based Resources are playing central role when it comes to adding new electric generation capacity into the bulk power system.
As the power delivery system continues to rapidly evolve due to decarbonization policy initiatives, inverter-based resources (IBRs) are playing an ever-more significant role in generation additions to the bulk power system. NERC and other technical organizations have taken numerous actions to support the reliable integration of these resources.
The Federal Energy Regulatory Commission has approved Order 2023 to facilitate and improve the speed and reliability of adding new energy resources to the power system
Regulated organizations should continue to follow DHS cybersecurity requirements.
Expert Discussions and Key Takeaways Focus on Physical Security
As renewable energy proliferates across the US power system, the North American Electric Reliability Corporation (NERC) continues to actively address reliability risks resulting from the implementation of inverter-based resources (solar and wind generation technology) connected at both transmission and Distributed Energy Resources (DER) levels.
FERC issued a Final Rule directing NERC to develop a new or modified reliability standard addressing transmission system planning performance requirements for extreme heat or cold weather events.
FERC issued an order approving NERC’s compliance filings.
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 has approved two NERC proposed cold weather-related reliability standards.
FERC directed NERC to develop Reliability Standards to implement INSM within trusted CIP environments.
NERC and TRE release the Odessa II Power System Disturbance Report
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 report on best practices for utilities that have encountered facility ratings program challenges.
The rulemaking addresses improvements needed to reliably facilitate the power industry’s transition to renewable and distributed generating resources utilizing inverter-based technologies.
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.
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 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.
Reliability Standards FAC-001-4 and FAC-002-will resolve uncertainty regarding the meaning of “materially modify” under the currently effective standards.
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.
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.
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.
NERC has issued a new report highlighting the key attributes of various inverter controls to support proper implementation and to protect reliability.
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.
Between 18 and 36 percent of reported utility misoperations were attributed to issues that could have been detected through a properly implemented PSC.
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.
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.
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.
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.
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.
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.
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.
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.
ERCOT’s recently released “Roadmap to Improving Grid Reliability” presents a plan for change in Texas that includes increasing electric power generation and purchasing significantly more power reserves.
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.
Two recent actions will change the current system planning, investment needs and operating procedures for electric utilities. New infrastructure investments and more robust compliance programs will be needed.
Due to recent extreme weather-related power systems failures, stakeholders are examining the planning and operations practices for all electric utilities.
FAC-008 is one of the most data-intensive standards in the NERC regulatory framework. Compliance has been difficult for many utilities. Recently, FERC made public it’s intent to address serious allegations of facility ratings violations, including a lack of rigor by one utility.
While NERC has recently published a reliability guideline addressing inverter-based resources generally, they are now giving more attention to the various potential uses of BESS to support effective implementation with newly released guidance.
NERC’s CIP-008 standard aims to mitigate reliability risks resulting from a Cyber Security Incident by specifying incident response requirements. Newly proposed revisions would augment mandatory reporting to include incidents that compromise, or attempt to compromise, a utility’s Electronic Security Perimeter (ESP) or associated Electronic Access Control or Monitoring Systems (EACMS).
The latest weather impacts to power reliability have accelerated the need for mandatory regulatory compliance changes.
NERC’s 2021 Compliance Monitoring and Enforcement Program reframes the previous year’s risks and their associated areas of focus. Utilities should review their compliance programs and internal controls to determine if enhancement or changes are need to maintain compliance.
NERC has recently undertaken important standards and guidance development activities related to the proliferation of inverter-based technologies such as solar and wind generation, as well as battery energy storage which is growing as an industry solution to ensure the reliability of renewable power for end-use customers.
There has been significant work across the electric industry to improve facility ratings related processes, programs, frameworks, internal controls and best practices. Yet this continues to be a challenging area for utilities, particularly from an asset management and regulatory compliance perspective.
In its 2020 Report on CIP Reliability Audits, the Federal Energy Regulatory Commission found that most of the cybersecurity protection processes and procedures adopted by utilities met the mandatory CIP requirements for protecting the Bulk Electric System. However, there are areas for improvement.
As inverter-based resources found in wind and solar generation technologies continue to rapidly penetrate the U.S. power delivery system, NERC remains focused on managing the potential reliability consequences.
The Report identifies areas of ongoing concern including generation reserve margins and the reliability risk from shifting the resource mix toward renewables.
On July 10, 2020 NERC released new Lessons Learned guidance to address situations where multiple composite protection systems have misoperated as a result of mixing protective relay technologies at the remote terminals of directional comparison blocking (DCB) schemes. This technical information will help utilities improve the reliability of the Bulk Power System.
On July 9, 2020 NERC standard PRC-024-3 was approved, paving the way for improved protection systems in support of keeping generating resources connected during defined frequency and voltage excursions.
FERC has released a notice of inquiry seeking comments on potential enhancements to NERC’s Critical Infrastructure Protection (CIP) Reliability Standards.
NERC’s PRC-027-1 standard was approved by FERC in 2018 and is set to go into effect on October 1, 2020. Utilities should begin preparing now to meet compliance requirements which include significant system studies.
Assuring continued power system reliability is a complex undertaking for utilities. Balancing the demands of system changes and regulatory compliance is an essential strategy for optimizing ongoing operations. Given the wide range of NERC standard families that require simultaneous data management for compliance, data integrity, data flow and data verification are critical for avoiding violations that can impact electric service to customers and communities.
NERC’s 2019 ERO Reliability Risk Priorities Report identified and prioritized the major risks facing the utility industry with a particular focus on security issues.
Looking ahead to the many changes coming to North America’s Bulk Power System (BPS), NERC’s 2019 ERO Reliability Risk Priorities Report highlights the top issues requiring industry and regulatory attention and recommends actions for the ongoing protection of BPS reliability.
Two Standards Authorization Requests currently being debated in the NERC stakeholder engagement process could help clarify PRC standards obligations for generator owners and operators.
Renewable energy systems have dramatically changed the power generation resource mix. These new generation technologies no longer involve directly coupled rotating generators which were once standard in the industry. Now, inverters that change Direct Current (DC) electricity to the Alternating Current (AC) electricity suitable for delivery via AC transmission systems are becoming more prevalent, raising reliability…
Under the proposed NERC TPL-001-5 standard, utilities with transmission planning responsibilities will be required to identify reliability risks related to protection system failures and take mandatory corrective action. It will be critical to have an in depth understanding of your company’s protection system settings and to perform the system studies necessary to identify where single points of failure may result in cascading tripping of transmission elements. Mitigation actions may require the installation of redundant protection systems which in turn may lead to significant substation redesign. Transmission planners and planning coordinators should begin preparing for any necessary protection system changes. TPL-001-5 Overview NERC began studying the reliability risk associated with single points of protection system failure starting in 2011 as directed in FERC Order 754. TPL-001-5 will bring significant changes for Planning Coordinators and Transmission Planners as they perform annual Planning Assessments. There is a new obligation to adequately account for the reliability risk posed by single point of protection system failure via risk-based Assessment. This reliability risk management approach will be implemented through modifications to the Category P5 Planning Event which is described in Table 1 of the TPL-001-5 standard. NERC believes that the most cost-effective Corrective Action Plans to address unacceptable system performance for the P5 Planning Events will likely be to add protection system component redundancy in certain cases. Protection system redundancy changes to address Category P5 Event system performance violations should reduce or even negate non-redundant component related risks that need to be considered in assessing transmission system performance. These risks will be identified during simulations of certain extreme events as required under the standard. TPL-001-5 also addresses reliability risks related to outage management as directed in FERC Order 786. The standard requires utility planners to consider maintenance outages of significant facilities as well as outages for critical long lead time to repair or replace equipment. Specifically, it addresses stability analysis to assess system performance for conditions expected during possible unavailability of long lead time equipment. Although it is not a NERC defined term, it is believed that a “spare equipment strategy will be sufficient to allow flexibility for utilities to conduct both steady state and stability analysis required by TPL-001-5. For example, a utility’s spare equipment strategy may include the warehousing of a replacement transformer to be installed given the failure of an in service transformer. When a utility’s spare equipment strategy may prevent major transmission equipment from being out-of-service for one year or more, this possible equipment unavailability need not be assessed as part of TPL-001-5.
This month, NERC released the first draft of its 2019 Compliance Monitoring and Enforcement Plan (CMEP) which identifies power delivery system risks and outlines compliance audit requirements for next year. The risk elements outlined in the plan include significant differences from previous years, as shown in the table below. Each NERC region must consider these risks as they develop their monitoring and audit scopes for utilities. Utilities should be prepared to be audited and implement any necessary compliance initiatives in these areas.
A recently published NERC report concludes that as reliance on natural gas to meet electric generation requirements increases, additional planning and operational measures must be considered to mitigate power system reliability risks.
Federal CFATS regulations cover more than just the handling, transport and storage of dangerous chemicals. They also deal with tools and methods terrorists could use to acquire the deadly agents – such as a cyber attack.
NERC has filed mandatory standard CIP-013-1 for supply chain risk management, requiring controls to mitigate cyber threats and their impact to the reliable operation of the Bulk Electric System.
NERC has released a report documenting its findings and recommendations related to reliability risks from utility scale solar generation projects with implications for PRC-024 compliance, as well as generation, interconnection and protection system technologies.
The approval of NERC Standard PRC-005-2 extends protection system maintenance obligations to Generators and crates one comprehensive standard establishing minimum maintenance activities and maximum time intervals for protection systems and load shedding equipment affecting the bulk electric system.
On November 1, 2024, FERC Commissioners led a technical conference regarding co-locating large loads at generating facilities.
On Tuesday, December 17th, the United States Environmental Protection Agency (USEPA) issued a final rule reclassifying several ozone nonattainment areas as “Serious” nonattainment for the 2015 ozone national ambient air quality standard.
In 2023, the Texas State Legislature approved Senate Bill 1397 and House Bill 1505, which require that “A person who holds a temporary permit or permit with an indefinite term shall report to the commission annually whether the activity subject to the permit is ongoing” and that the person “shall first report to the Texas Commission on Environmental Quality the status of the permitted activity not later than December 31, 2024”. The Texas Water Code has been amended to include this requirement in Sec. 5.587.
On November 1, 2024, FERC Commissioners led a technical conference regarding co-locating large loads at generating facilities.
Over 70% of the power grid is more than 25 years old, and much has changed in the last quarter of a century. From increasing demands on existing infrastructure to a renewed focus on moving away from fossil fuels, the grid must achieve unprecedented goals. However, today’s grid cannot meet growing energy needs or complex challenges brought on by a shift to renewable energy sources. A modern grid design is the only way to reinvigorate existing infrastructure and assets to cope with challenges ranging from climate anomalies to cybercrime. Grid modernization blends advanced technologies with a sustainable strategy to make the electric grid more reliable, resilient, secure and affordable. An Introduction to Grid Modernization In simple terms, electric grid modernization is the process of upgrading the grid and integrating new technology to make it more efficient and resilient. It requires several significant changes, including incorporating new energy generation and storage forms, installing smart technologies and upgrading or extending the existing infrastructure. Today’s electric grid is one of the most complex machines in the world. Yet, objectives have evolved in the face of climate change. Grid modernization paves the way for a complete energy transition — eliminating reliance on fossil fuels to produce energy. The power industry has changed considerably, from generation to transmission and distribution. An effective grid modernization strategy allows the grid to keep up with these changes. Increasingly complex energy challenges combined with the grid’s age make providing consistent and continuous energy more challenging. In short, the current grid alone cannot support the energy transition. More consumers are turning to renewable energy sources and distributed energy resources (DERs) to ensure a reliable, separate power source. Integrating these advancements into the existing grid can make it capable of supporting and maintaining a complete energy transition. Power Grid Modernization and Its Critical Importance Power outages have become more frequent across the United States as the grid struggles to cope with evolving power requirements and increasingly severe weather events. Modernizing the grid to align with smart technology makes it more reliable and resilient. Blending the latest technologies and equipment with digital controls that integrate and communicate can significantly reduce the frequency and duration of power outages and the impact of inclement weather. In addition, grid modernization supports faster service return when outages occur. Smart grid technology also gives consumers easy access to their energy data, empowering them to manage their consumption and costs. The process also benefits utilities, and 60% of leaders and investors in the energy sector identify the need to monitor, control and protect grid conditions as a primary driver for global grid modernization. It provides improved security and load management, lowers costs and facilitates the integration of renewables. Many existing grid modernization projects are already meeting 21st-century energy needs. In the U.S., the modern grid will incorporate innovative technologies like microgrids and smart grid technologies to boost grid flexibility and agility, meeting today’s needs. Renewable energy sources could provide 90% of the reductions in carbon dioxide (CO2) emissions. In line with global net-zero goals, integrating renewables like wind, solar and hydrogen power into the grid is a top priority. Grid modernization aims to address many of today’s energy challenges, optimize grid operations, enhance reliability and support frictionless integration of renewable technologies. The Crucial Role of Technology in Grid Transformation Digital transformation profoundly impacts the energy sector, providing benefits like improved efficiency, cost reduction and elevated consumer experience. Implementing grid modernization technology is the only way to boost grid reliability, resiliency and power quality. Several groundbreaking technologies have emerged as many utilities, organizations and communities collaborate around grid modernization. Leveraging Smart Grid Technologies The smart grid is the heart of the grid modernization effort. It enables real-time monitoring through advanced sensing, communications and control capabilities, optimizing the energy system to meet modern demands. Instead of the one-way flow of communication in the traditional grid, the smart grid leverages digital technology that allows for two-way communication between consumers and utilities. Smart meters, distribution automation and intelligent grid management systems empower utilities to monitor energy consumption. They can detect faults in real time and manage demand. When all the smart grid elements work together, it ultimately results in improved reliability and resilience in times of crisis. Integrating Renewable Energy Sources Renewable energy sources are an integral part of the modern grid. Solar photovoltaics, wind turbines, hydrogen power and hydropower systems have experienced massive growth as industries aim to minimize emissions. Innovative technology allows the integration of renewable technologies and smart grids, offering abundant clean energy alternatives alongside efficient energy management, distribution and consumption. Climate variability and weather unpredictability are significant challenges in transitioning to renewables. The energy demand is inconsistent, and people use energy in peaks and valleys. Grid modernization facilitates the transition to renewables, counteracting source variability with innovations like advanced forecasting and demand response programs. These technologies reduce greenhouse gas emissions in the energy sector while enhancing grid flexibility and reliability. Incorporating Energy Storage Systems Energy storage systems like DERs remove much unpredictability in renewable energy integration. DERs integration, including small-scale clean energy installations like photovoltaic panels and energy storage, enhances energy efficiency and resilience while supporting the decarbonization of the energy sector. DER technology can transform energy systems, decentralizing the energy market and reducing pressure on the grid. While often provided as standalone solutions, the value of DERs compounds when integrated into smart grids. Modernization includes adapting the grid to integrate and optimize power from DERs. Once integrated, DERs need extensive monitoring and control via an advanced distribution management system to detect and mitigate faults before they become outages. Distributed energy resource management systems can solve many modern grid resiliency challenges. Modernizing With the Cloud Grid modernization requires complete visibility. A modern grid requires transparent communication across all components. The cloud is critical in achieving grid modernization objectives, including resilience, flexibility and affordability. Cloud services and solutions are designed to provide extreme redundancy and availability while optimizing cost and performance. Agility is another critical grid modernization goal. The grid must meet growing customer demands, maintain compliance with evolving regulations and respond to unforeseen events. The cloud can facilitate rapid system positioning and help utilities stay agile despite shifting operating conditions.
On October 16, 2024, the Federal Energy Regulatory Commission held its annual Commissioner-led Reliability Technical Conference.
This update provides details from FERC 2024 staff report from CIP audits, so utilities can improve compliance and reduce security risks.
Garanzuay Consulting provides a foundation in Ireland to continue TRC’s growth and expansion in Europe in support of the energy transition for all energy market participants.
The North American Electric Reliability Corporation (NERC) recently released its 2024 State of Reliability report, examining power system performance in calendar year 2023.
Facility Ratings play a critical role in the reliable planning and operation of the Bulk Electric System (BES) and yet maintaining compliance with relevant NERC standards remains an industry challenge.
Learn about the recent geomagnetic disturbance which caused stakeholders within the bulk power system to react swiftly to protect grid reliability. Find out the impacts and what NERC and the industry are doing about it.
Joint use has never been as important as it is today. With demand for telecommunications infrastructure skyrocketing, governments are investing big in initiatives like the $42.5 billion Broadband Equity Access Deployment Program (BEAD) and the $20.4 billion Rural Digital Opportunity Fund (RDOF).
While utilities often work in technical silos, NERC auditors are trained to cross check compliance evidence and data between interrelated standards.
As part of NERC’s ongoing effort to bolster Critical Infrastructure Protection (CIP) requirements and enable the implementation of a security improvement concept known as virtualization.
In the actively changing energy landscape, utilities are grappling with many workforce-related challenges linked to the ongoing shift towards cleaner energy and the modernization of power grids. As veteran employees retire, it is critical to bridge the knowledge and skill gap by recruiting and developing younger talent.
In the actively changing landscape of transportation, the electrification of fleets has emerged as a pivotal step towards a sustainable and clean energy future. Electrification can, in the right applications, help fleets drastically cut emissions, reducetotal lifetime operating costs and improve the air quality in and around their communities.
Creating new pathways for workforce development requires adapting to the shifting needs of a new generation In the actively changing energy landscape, utilities are grappling with many workforce-related challenges linked to the ongoing shift towards cleaner energy and the modernization of power grids. As veteran employees retire, it is critical to bridge the knowledge and skill gap by recruiting and developing younger talent. While education and technology play crucial roles, adapting workplace behaviors and culture to suit the preferences and expectations of diverse generations is equally vital. Growing a strong, multi-generational workforce has its challenges, but there are many opportunities ahead to ensure today’s utility professionals can support a resilient power system capable of navigating tomorrow’s industry demands. Contact Us
NERC has submitted for FERC approval new compliance criteria for the registration of IBRs as part of continuing efforts to address reliability risks. It is critical for renewable energy developers, generation owners and transmission owners to understand the potential implications for interconnection studies and interconnection queues.
This blog delves into common misconceptions surrounding cloud migration in the utility industry, addressing concerns about security, reliability, regulatory compliance, cost effectiveness, and complexity, while highlighting the substantial benefits and strategies for successful adoption.
NERC has submitted proposed revisions to the EOP-012-2 – Extreme Cold Weather Preparedness and Operations standard, for FERC approval on an expedited basis. The proposed revisions address the remaining key recommendations from the FERC–NERC Joint Inquiry Report into Winter Storm Uri and directives arising from a 2023 FERC Order regarding the previously submitted cold weather standards.
Update to FAC-003-5 Brings Sweeping Changes to Transmission Classifications Starting April 1
Every NERC-registered utility must strive for continuous compliance with their portfolio of applicable NERC Reliability Standards
NERC has submitted its 2024-2026 Reliability Standards Development Plan to the Federal Energy Regulatory Commission (FERC), outlining its current priorities and future standard development plans to protect the reliability of the Bulk Power System over the next three years.
NERC and FERC have released their final report on Winter Storm Elliott which provides reinforcement for recommendations in prior cold weather-related disturbance event reports. The Report identifies critical reliability performance shortcomings and the reliability related near misses. NERC states that a crisis was “narrowly dodged.” The Report outlines the steps the industry must take to avoid a repeat in the future.
Inverter Based Resources are playing central role when it comes to adding new electric generation capacity into the bulk power system.
Locana, an international leader in spatial technology, received the Modern Network Management Award at the 2023 Esri Infrastructure Management and GIS (IMGIS) Conference held in Palm Springs, California, October 10-12, 2023.
As the power delivery system continues to rapidly evolve due to decarbonization policy initiatives, inverter-based resources (IBRs) are playing an ever-more significant role in generation additions to the bulk power system. NERC and other technical organizations have taken numerous actions to support the reliable integration of these resources.
Locana, an international leader in spatial technology, received Esri’s ArcGIS Cloud Services Specialty, which designates Locana as an expert in deploying and managing ArcGIS in cloud environments such as Amazon Web Services (AWS) and Microsoft Azure.
As technology advances and cybersecurity threats loom, companies must prioritize communications retrofits and upgrades to ensure reliability, availability and business continuity.
The Federal Energy Regulatory Commission has approved Order 2023 to facilitate and improve the speed and reliability of adding new energy resources to the power system
Expert Discussions and Key Takeaways Focus on Physical Security
As the urgency to decarbonize and build resiliency grows, renewable energy continues to be a pivotal solution for reshaping the future of power in the U.S. From solar to wind, hydro, geothermal and biomass, each renewable resource has its sweet spot for efficient development, deployment and optimal performance. And while they all have their own pros and cons, it is imperative that we leverage them all into the energy mix to achieve decarbonization goals and ensure adequate capacity to meet increasing load demands.
As renewable energy proliferates across the US power system, the North American Electric Reliability Corporation (NERC) continues to actively address reliability risks resulting from the implementation of inverter-based resources (solar and wind generation technology) connected at both transmission and Distributed Energy Resources (DER) levels.
EJScreen is currently at the forefront of federal efforts to identify potential disproportionate environmental burdens and communities with potential environmental justice (EJ) concerns.
Leveraging new tools and technologies such as mixed and virtual reality (MR/VR) to develop a new generation of skilled engineers and technicians to maintain the reliability and resiliency of the future grid.
FERC issued a Final Rule directing NERC to develop a new or modified reliability standard addressing transmission system planning performance requirements for extreme heat or cold weather events.
The impact of adapting behavioral and cultural norms to focus on the principles of human performance cannot be underestimated in building the power workforce of the future.
According to the Edison Foundation’s Institute for Electric Innovation, over 124 million smart meters were expected to be installed in 78 percent of US households by the end of 2022.
FERC issued an order approving NERC’s compliance filings.
The role of field service management continues to dominate the world economy, as the market grows at an exponential rate. The market was estimated at 3.2 billion in 2021 and is projected to reach 5.7 billion by the end of 2026.
TRC has developed utility network Master Plans and designed and architected utility-wide networks
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 has approved two NERC proposed cold weather-related reliability standards.
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 directed NERC to develop Reliability Standards to implement INSM within trusted CIP environments.
TRC Companies announces its role as a consultant in supporting the new transmission project by LS Power Grid Maine.
NERC and TRE release the Odessa II Power System Disturbance Report
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
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 report on best practices for utilities that have encountered facility ratings program challenges.
The rulemaking addresses improvements needed to reliably facilitate the power industry’s transition to renewable and distributed generating resources utilizing inverter-based technologies.
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.
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 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.
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
Reliability Standards FAC-001-4 and FAC-002-will resolve uncertainty regarding the meaning of “materially modify” under the currently effective standards.
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.
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.
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.).
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.
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 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.
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.
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.
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.
NERC has issued a new report highlighting the key attributes of various inverter controls to support proper implementation and to protect reliability.
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.
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.
