NERC filed a joint petition March 9, 2018 for approval of retirement of PRC-004-WECC-2.

Entities will be required to establish 50% compliance with Requirements R2-R4 and R6-R11 by January 1, 2021. **, *Select "NERC Email Distribution Lists" from the "Service" drop-down menu and specify the list in the Description Box. Copyright 2020 North American Electric Reliability Corporation. Entities with newly classified “Remedial Action Scheme” (RAS) resulting from the application of the revised definition must be fully compliant with all Reliability Standards applicable RAS twenty-four (24) months from the Effective Date of the revised def. Please select the report you would like to view: Mandatory Standards Subject to Enforcement, Primary Frequency Response in the ERCOT Region, Disturbance Control Standard – Contingency Reserve for Recovery from a Balancing Contingency Event, Frequency Response and Frequency Bias Setting, Planning Resource Adequacy Analysis, Assessment and Documentation, Operating Personnel Communications Protocols, Cyber Security — BES Cyber System Categorization, Cyber Security — Security Management Controls, Cyber Security — Electronic Security Perimeter(s), Cyber Security — Physical Security of BES Cyber Systems, Cyber Security — System Security Management, Cyber Security — Incident Reporting and Response Planning, Cyber Security — Recovery Plans for BES Cyber Systems, Cyber Security — Configuration Change Management and Vulnerability Assessments, Cyber Security - Supply Chain Risk Management, System Restoration from Blackstart Resources, System Operating Limits Methodology for the Planning Horizon, System Operating Limits Methodology for the Operations Horizon, Assessment of Transfer Capability for the Near-Term Transmission Planning Horizon, Establish and Communicate System Operating Limits, Interchange Initiation and Modification for Reliability, Reliability Coordination – Responsibilities, Reliability Coordination – Monitoring and Analysis, Reliability Coordination — Transmission Loading Relief (TLR), Transmission Loading Relief Procedure for the Eastern Interconnection, Qualified Path Unscheduled Flow (USF) Relief, Reliability Coordinator Operational Analyses and Real-time Assessments, Reliability Coordinator Actions to Operate Within IROLs, Reliability Coordinator Data Specification and Collection, Coordination Among Reliability Coordinators, Reliability Coordinator Real-time Reliability Monitoring and Analysis Capabilities, Transmission Reliability Margin Calculation Methodology, Providing Interruptible Demands and Direct Control Load Management Data to System Operators and Reliability Coordinators, Verification and Data Reporting of Generator Real and Reactive Power Capability and Synchronous Condenser Reactive Power Capability, Verification of Models and Data for Generator Excitation Control System or Plant Volt/Var Control Functions, Verification of Models and Data for Turbine/Governor and Load Control or Active Power/Frequency Control Functions, Data for Power System Modeling and Analysis, Steady-State and Dynamic System Model Validation, Disturbance Monitoring and Reporting Requirements, Protection System Misoperation Identification and Correction, Protection System and Remedial Action Scheme Misoperation, Transmission and Generation Protection System Maintenance and Testing, Protection System, Automatic Reclosing, and Sudden Pressure Relaying Maintenance, Automatic Underfrequency Load Shedding Requirements, Implementation and Documentation of Underfrequency Load Shedding Equipment Maintenance Program, Undervoltage Load Shedding System Maintenance and Testing, Remedial Action Scheme Data and Documentation, Remedial Action Scheme Maintenance and Testing, Disturbance Monitoring Equipment Installation and Data Reporting, Coordination of Generating Unit or Plant Capabilities, Voltage Regulating Controls, and Protection, Generator Frequency and Voltage Protective Relay Settings, Relay Performance During Stable Power Swings, Real-time Reliability Monitoring and Analysis Capabilities, Transmission System Planning Performance Requirements, Transmission System Planned Performance for Geomagnetic Disturbance Events, Generator Operation for Maintaining Network Voltage Schedules, BAL-005-1 will replace BAL-005-0.2b and BAL-006-2, See Key Resources: NERC Standards CIP-002 through CIP-009 each contribute to the cyber-security framework for the identification and protection of all Critical Cyber-Assets to support the reliable operation of the BES. Replaces PRC-006-2.

Requirement 2 of Reliability Standard EOP-010-1 will not become effective until the first day following retirement of Reliability Standard IRO-005-3.1a. FAC-010-3 replaces FAC-010-2.1. All rights reserved.

All existing and future Pseudo-Ties are to be registered in the NAESB Electric Industry Registry. Please enable scripts and reload this page. Please turn on JavaScript and try again. Technology and Security Committee (BOTTSC), Corporate Governance and Human Resources Committee (GOVERNANCE), Compliance and Certification Committee (CCC), Personnel Certification Governance Committee (PCGC), Reliability Issues Steering Committee (RISC), Reliability and Security Technical Committee (RSTC), Organization Registration and Certification, Reliability Assessment & Performance Analysis, System Operator Certification & Credential Maintenance Program, Archived Reliability Standards Under Development, One-Stop-Shop (Status, Purpose, Implementation Plans, FERC Orders, RSAWS), US Effective Date Status/Functional Applicability, Reliability standards are enforceable in all interconnected jurisdictions in North America: the continental United States; the Canadian provinces of Alberta, British Columbia, Manitoba, New Brunswick, Nova Scotia, Ontario, Quebec, and Saskatchewan; and the Mexican state of Baja California Norte.
All rights reserved. Details will be provided at a later time. None of the continent-wide requirements have changed. Reliability Standard PRC-006-3 revises the regional Variance for the Québec Interconnection as necessary to account for the physical characteristics and operational practices of that Interconnection. Refer to the Implementation Plan for Phased-in Compliance details.

The retirement date for INT-004-3 and the enforcement date for INT-004-3.1 have been coordinated to ensure seamless transition from the original to the errata Reliability Standard on the date of Commission approval for the errata Reliability Standard. in 2020, there will be changes to the Reliability Standards webpage and associated reports, including the One-Stop-Shop, US Effective Date Status/Functional Applicability spreadsheet, and VRF and VSL matrices. Requirements R2, R3 and R4 are effective 1/1/2020. Following adoption of a standard by the NERC Board of Trustees, NERC files the standard with the appropriate authority in each jurisdiction. MOD-029-2a replaces MOD-029-1a, Entities with newly classified “Remedial Action Scheme” (RAS) resulting from the application of the revised definition must be fully compliant with all Reliability Standards applicable RAS twenty-four (24) months from the Effective Date of the revised definition of RAS.

Each of these different standards recognizes the … Copyright 2020 North American Electric Reliability Corporation. WECC Regional Variance added. See Implementation Plan for Compliance dates. This additional time applies only to existing schemes that must transition to RAS due to the revised definition. NERC requires thorough documentation of this process, including the identification of access points and all electronic systems monitoring access (e.g., requests, grants, alerts).

EOP-011-1 consolidates the requirements in three existing Reliability Standards: EOP-001-2.1b, EOP-002-3.1 and EOP-003-2 into a single Reliability Standard.

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