Ten NERC maintenance areas utilities should know for compliance

For utilities operating in North America, adherence to the standards set by the North American Electric Reliability Corporation (NERC) is done to maintain grid reliability and meet regulatory requirements. Mexico, Canada, and the United States signed an agreement with the European Union to implement a collaborative approach to ensure their respective grid reliability. The evolution of NERC standards makes compliance a moving target, requiring utilities to stay up to date with maintenance, cybersecurity, and documentation practices. In this blog, we’ll cover the ten NERC maintenance areas every utility should prioritize to enhance reliability and ensure compliance.

1. Facility Ratings (FAC-008) and Protection System Maintenance (PRC-005)

Regular maintenance under Facility Ratings (FAC-008) and Protection System Maintenance (PRC-005) reduces the risk of equipment failure, thereby bolstering reliability and compliance. Both are considered NERC standards to follow to utilities. FAC-008 (opens in new tab) is focused on ensuring that facility ratings are used in the reliable planning and operation of the bulk electric system (BES). While PRC-005 (opens in new tab) requires transmission owners, generator owners, and distribution providers to maintain protection systems, automatic reclosing, and sudden pressure relaying for BES reliability.

Their focus areas are as follows:

• FAC-008: This standard focuses on facility ratings and requires utilities to develop methods that define accurate ratings for transmission facilities. These ratings are crucial as they influence equipment maintenance intervals and help prevent overloads that could jeopardize grid stability.
• PRC-005: This mandated standard focuses on protection system maintenance and requires regular testing and maintenance of protective relays, DC control circuitry, and associated equipment. By adhering to PRC-005, utilities and their protective system operate effectively, preventing outages and aligning with NERC’s reliability standards.

2. Cybersecurity and Critical Infrastructure Protection (CIP)

NERC’s Critical Infrastructure Protection (CIP) standard outlines cybersecurity requirements and standards for protecting critical infrastructure. These standards include:

• Regular patching: Ensuring all systems and software are up to date with the latest security patches to protect against known vulnerabilities.
• Network monitoring: Continuously monitoring network traffic for suspicious activities and potential intrusions.
• Vulnerability assessments: Conducting regular assessments to identify and mitigate security weaknesses.
• Incident response plans: Developing and maintaining robust incident response plans to quickly address and recover from cyber incidents.

By including cybersecurity as a regular part of maintenance activities, utilities can address the specific requirements of NERC CIP and protect critical assets against evolving digital threats, contributing to system resilience.

3. Protection Coordination (PRC-027)

PRC-027 requires regular coordination and documentation of protection system settings to ensure protective devices operate harmoniously. Prioritizing PRC-027 for maintenance means routinely reviewing and updating device settings, which is essential to prevent cascading outages and to comply with evolving NERC requirements for protection coordination.

Other key maintenance activities include:

• Reviewing protection settings: Regularly reviewing and updating protection system settings to reflect changes in the grid and ensure optimal performance.
• Testing and calibration: Periodically testing and calibrating protective devices to verify their accuracy and reliability.
• Documentation: Maintaining detailed records of protection settings and coordination studies to demonstrate compliance with NERC standards.

4. Emergency Preparedness (EOP)

Maintenance of critical infrastructure per NERC’s Emergency Operations Planning (EOP) and CIP standards prepares utilities to respond effectively in emergencies. Regular maintenance of essential equipment, such as backup systems and communication channels, helps ensure readiness and continuity of operations during unforeseen events. Additionally, conducting regular training and emergency drills to prepare staff for various emergency scenarios.

5. Voltage and Reactive Control (VAR)

NERC’s VAR standards require utilities to maintain voltage levels and reactive power within specific limits to support grid stability. Prioritizing maintenance in this area ensures that reactive power equipment, such as capacitors and reactors, operates effectively. Regular calibration and testing help utilities prevent voltage instability. Additionally, teams should be conducting monitoring and analysis for voltage levels and reactive power flows to identify and address potential issues.

6. Control center equipment maintenance

Control centers are central to monitoring and managing grid operations. Regular maintenance of control room systems, including Supervisory Control and Data Acquisition (SCADA) and Energy Management Systems (EMS), is essential for real-time visibility and control. A part of the maintenance team’s responsibility is to provide ongoing training for control center operators to ensure they are proficient in using the systems and responding to operational issues. This maintenance ensures that operators have accurate data to make decisions, contributing to compliance and preventing operational errors.

7. Distributed Energy Resource (DER) Data Management

With more DERs (such as solar and wind) integrated into the grid, utilities face challenges in managing data consistency and quality. Prioritizing data integration and maintenance for DER systems helps ensure accurate monitoring of these resources and enhance alignment with NERC’s proactive maintenance approach.

Key maintenance activities include:

• Data integration: Ensuring that data from DERs is accurately integrated into the utility’s monitoring and control systems.
• Data quality: Regularly validating and cleaning data to ensure its accuracy and reliability.
• System upgrades: Upgrading data management systems to handle the increased volume and complexity of DER data.

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8. Automatic Generation Control (AGC) system maintenance

AGC systems play a crucial role in balancing supply and demand. Routine maintenance of AGC components ensures optimal performance, enabling utilities to maintain grid frequency and avoid imbalances that could destabilize the grid. Maintaining AGC systems is vital for staying compliant with NERC standards and preventing blackouts.

Key maintenance activities include:

• Component testing: Regularly testing AGC components to ensure they are functioning correctly.
• System calibration: Periodically calibrating AGC systems to maintain accurate control over generation and load balancing.
• Performance monitoring: Continuously monitoring AGC system performance to identify and address potential issues.

9. Relay and breaker testing

Relays and breakers are vital for protecting electrical infrastructure. Routine testing and maintenance of these components ensure they function correctly in faulty conditions. Proper relay and breaker maintenance reduces the risk of equipment failure, enhancing system protection and aligning with NERC’s emphasis on system reliability.

10. Communication System Reliability (COM-001 and COM-002)

Communication systems are essential for grid coordination, especially during emergency situations. NERC’s COM standards outline the requirements for reliable communication among control centers and field personnel. Prioritizing maintenance of communication equipment ensures clear, uninterrupted channels, which are crucial for coordinated response and compliance with NERC’s operational standards.

Maintaining compliance with NERC standards for maintenance

NERC standards require utilities to implement structured preventive maintenance, cybersecurity practices, and effective documentation strategies. A Computerized Maintenance Management System (CMMS) can significantly streamline these efforts, from automating maintenance records to simplifying audit preparation. However, utilities must navigate the challenges of legacy systems and data inconsistencies to fully realize the benefits of an integrated CMMS. By prioritizing these essential maintenance practices, utilities can not only meet NERC requirements but also enhance reliability and resilience across their operations.