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Standards:
Reliability Standards
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This page provides a copy of the latest version of the standard approved by the NERC Board of Trustees and any prior versions that were BOT approved and are still in effect in at least one regulatory jurisdiction. Note that not all the standards on this page have been approved by governmental authorities as enforceable standards. The Mandatory Enforcement Dates Web pages identify, by regulatory jurisdiction, the status of the standards and the applicable dates. Prior versions of standards may be found on the Inactive Standards Web page.
All standards on this page have been adopted by the NERC Board of Trustees. The date field indicates the date on which the NERC Board of Trustees adopted the standard.
All comments should be forwarded to sarcomm@nerc.net. Questions? E-mail Herb Schrayshuen or call 404-446-2560, Ext. 563.
Complete Set of Reliability Standards: To download a complete set of the Reliability Standards posted on this page along with the Glossary of Terms Used in NERC Reliability Standards, please click here.
Resource and Demand Balancing (BAL) |
| Number |
Title/Summary |
Date |
|
| BAL-001-0.1a |
Real Power Balancing Control Performance
To maintain Interconnection steady-state frequency within defined limits by balancing real power demand and supply in real-time. [Archive] |
10.29.2008 |
pdf |
| BAL-002-0 |
Disturbance Control Performance
The purpose of the Disturbance Control Standard (DCS) is to ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return interconnection frequency within defined limits following a Reportable Disturbance. Because generator failures are far more common than significant losses of load and because Contingency Reserve activation does not typically apply to the loss of load, the application of DCS is limited to the loss of supply and does not apply to the loss of load. [Archive] |
02.08.2005 |
pdf |
| BAL-002-1 |
Disturbance Control Performance
The purpose of the Disturbance Control Standard (DCS) is to ensure the Balancing Authority is able to utilize its Contingency Reserve to balance resources and demand and return Interconnection frequency within defined limits following a Reportable Disturbance. Because generator failures are far more common than significant losses of load and because Contingency Reserve activation does not typically apply to the loss of load, the application of DCS is limited to the loss of supply and does not apply to the loss of load. [Archive] |
08.05.2010 |
pdf |
| BAL-002-WECC-1 |
Contingency Reserve (WECC)
Contingency Reserve is required for the reliable operation of the interconnected power system. Adequate generating capacity must be available at all times to maintain scheduled frequency, and avoid loss of firm load following transmission or generation contingencies. This generating capacity is necessary to replace generating capacity and energy lost due to forced outages of generation or transmission equipment. [Archive] |
10.29.2008 |
pdf |
| BAL-003-0.1b |
Frequency Response and Bias
This standard provides a consistent method for calculating the Frequency Bias component of ACE. [Archive] [CAN-0040] |
10.29.2008 |
pdf |
| BAL-004-0 |
Time Error Correction
The purpose of this standard is to ensure that Time Error Corrections are conducted in a manner that does not adversely affect the reliability of the Interconnection. [Archive] |
02.08.2005 |
pdf |
| BAL-004-1 |
Time Error Correction
The purpose of this standard is to ensure that Time Error Corrections are conducted in a manner that does not adversely affect the reliability of the Interconnection. [Archive] |
03.26.2008 |
pdf |
| BAL-004-WECC-01 |
Automatic Time Error Correction (WECC)
To maintain Interconnection frequency within a predefined frequency profile under all conditions (i.e. normal and abnormal), and to ensure that Time Error Corrections are effectively conducted in a manner that does not adversely affect the reliability of the Interconnection. [Archive] |
03.26.2008 |
pdf |
| BAL-005-0.1b |
Automatic Generation Control
This standard establishes requirements for Balancing Authority Automatic Generation Control (AGC) necessary to calculate Area Control Error (ACE) and to routinely deploy the Regulating Reserve. The standard also ensures that all facilities and load electrically synchronized to the Interconnection are included within the metered boundary of a Balancing Area so that balancing of resources and demand can be achieved. [Archive] [Archive to Interpretation] |
10.29.2008 |
pdf |
| BAL-006-2 |
Inadvertent Interchange
This standard defines a process for monitoring Balancing Authorities to ensure that, over the long term, Balancing Authority Areas do not excessively depend on other Balancing Authority Areas in the Interconnection for meeting their demand or Interchange obligations. [Archive] |
11.05.2009 |
pdf |
| BAL-502-RFC-02 |
Planned Resource Adequacy Assessment (RFC)
To establish common criteria, based on “one day in ten year” loss of Load expectation principles, for the analysis, assessment and documentation of Resource Adequacy for Load in the ReliabilityFirst Corporation (RFC) region. [Archive] |
08.05.2009 |
pdf |
| BAL-STD-002-0 |
Operating Reserves (WECC)
Regional Reliability Standard to address the Operating Reserve requirements of the Western Interconnection. [Archive] |
03.12.2007 |
pdf |
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Communications (COM) |
| Number |
Title/Summary |
Date |
|
| COM-001-1.1 |
Telecommunications
Each Reliability Coordinator, Transmission Operator and Balancing Authority needs adequate and reliable telecommunications facilities internally and with others for the exchange of Interconnection and operating information necessary to maintain reliability. [Archive] |
10.29.2008 |
pdf |
| COM-002-2 |
Communications and Coordination
To ensure Balancing Authorities, Transmission Operators, and Generator Operators have adequate communications and that these communications capabilities are staffed and available for addressing a real-time emergency condition. To ensure communications by operating personnel are effective. [Archive] |
11.01.2006 |
pdf |
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Critical Infrastructure Protection (CIP) |
| Number |
Title/Summary |
Date |
|
| CIP-001-2a |
Sabotage Reporting
Disturbances or unusual occurrences, suspected or determined to be caused by sabotage, shall be reported to the appropriate systems, governmental agencies, and regulatory bodies. [Archive] [Archive to ERCOT Regional Variance] [Archive to Interpretation] [CAN-0016] |
02.16.2011 |
pdf |
| CIP-002-3 |
Cyber Security - Critical Cyber Asset Identification
NERC Standards CIP-002-3 through CIP-009-3 provide a cyber security framework for the identification and protection of Critical Cyber Assets to support reliable operation of the Bulk Electric System.
These standards recognize the differing roles of each entity in the operation of the Bulk Electric System, the criticality and vulnerability of the assets needed to manage Bulk Electric System reliability, and the risks to which they are exposed.
Business and operational demands for managing and maintaining a reliable Bulk Electric System increasingly rely on Cyber Assets supporting critical reliability functions and processes to communicate with each other, across functions and organizations, for services and data. This results in increased risks to these Cyber Assets.
Standard CIP-002-3 requires the identification and documentation of the Critical Cyber Assets associated with the Critical Assets that support the reliable operation of the Bulk Electric System. These Critical Assets are to be identified through the application of a risk-based assessment. [Archive] [Reference: Identifying Critical Assets] [Implementation Plan] [CAN-0005] [CAN-0024][Nuclear Implementation Plan] [Archive for Nuclear Implementation Plan] [Reference: Identifying Critical Cyber Assets]
|
12.16.2009 |
pdf |
| CIP-002-4 |
Cyber Security - Critical Cyber Asset Identification
NERC Standards CIP-002-4 through CIP-009-4 provide a cyber security framework for the identification and protection of Critical Cyber Assets to support reliable operation of the Bulk Electric System.
These standards recognize the differing roles of each entity in the operation of the Bulk Electric System, the criticality and vulnerability of the assets needed to manage Bulk Electric System reliability, and the risks to which they are exposed.
Business and operational demands for managing and maintaining a reliable Bulk Electric System increasingly rely on Cyber Assets supporting critical reliability functions and processes to communicate with each other, across functions and organizations, for services and data. This results in increased risks to these Cyber Assets.
Standard CIP-002-4 requires the identification and documentation of the Critical Cyber Assets associated with the Critical Assets that support the reliable operation of the Bulk Electric System. These Critical Assets are to be identified through the application of the criteria in Attachment 1. [Archive] [Identifying Critical Cyber Assets] [CAN-0005] [CAN-0024]
The Critical Cyber Assets reference document was developed in the context of Versions 1, 2, and 3, and is generally applicable to Version 4. [Reference: Critical Cyber Asset Identification]
|
01.24.2011 |
pdf |
| CIP-003-3 |
Cyber Security - Security Management Controls
Standard CIP-003-3 requires that Responsible Entities have minimum security management controls in place to protect Critical Cyber Assets. Standard CIP-003-3 should be read as part of a group of standards numbered Standards CIP-002-3 through CIP-009-3. [Archive] [Implementation Plan] [Nuclear Implementation Plan] [Archive for Nuclear Implementation Plan] |
12.16.2009 |
pdf |
| CIP-003-4 |
Cyber Security - Security Management Controls
Standard CIP-003-4 requires that Responsible Entities have minimum security management controls in place to protect Critical Cyber Assets. Standard CIP-003-4 should be read as part of a group of standards numbered Standards CIP-002-4 through CIP-009-4. [Archive] |
01.24.2011 |
pdf |
| CIP-004-3 |
Cyber Security - Personnel & Training
Standard CIP-004-3 requires that personnel having authorized cyber or authorized unescorted physical access to Critical Cyber Assets, including contractors and service vendors, have an appropriate level of personnel risk assessment, training, and security awareness. Standard CIP-004-3 should be read as part of a group of standards numbered Standards CIP-002-3 through CIP-009-3. [Archive] [Implementation Plan] [Nuclear Implementation Plan] [Archive for Nuclear Implementation Plan] [CAN-0007] |
12.16.2009 |
pdf |
| CIP-004-4 |
Cyber Security - Personnel & Training
Standard CIP-004-4 requires that personnel having authorized cyber or authorized unescorted physical access to Critical Cyber Assets, including contractors and service vendors, have an appropriate level of personnel risk assessment, training, and security awareness. Standard CIP-004-4 should be read as part of a group of standards numbered Standards CIP-002-4 through CIP-009-4. [Archive] [CAN-0007] |
01.24.2011 |
pdf |
| CIP-005-3a |
Cyber Security - Electronic Security Perimeter(s)
Standard CIP-005-3 requires the identification and protection of the Electronic Security Perimeter(s) inside which all Critical Cyber Assets reside, as well as all access points on the perimeter. Standard CIP-005-3 should be read as part of a group of standards numbered Standards CIP-002-3 through CIP-009-3. [Archive] [Archive to Interpretation] [Implementation Plan] [Nuclear Implementation Plan] [Archive for Nuclear Implementation Plan] |
02.16.2010 |
pdf |
| CIP-005-4a |
Cyber Security - Electronic Security Perimeter(s)
Standard CIP-005-4a requires the identification and protection of the Electronic Security Perimeter(s) inside which all Critical Cyber Assets reside, as well as all access points on the perimeter. Standard CIP-005-4a should be read as part of a group of standards numbered Standards CIP-002-4 through CIP-009-4. [Archive] [Archive to Interpretation] |
01.24.2011 |
pdf |
| CIP-006-3c |
Cyber Security - Physical Security of Critical Cyber Assets
Standard CIP-006-3 is intended to ensure the implementation of a physical security program for the protection of Critical Cyber Assets. Standard CIP-006-3 should be read as part of a group of standards numbered Standards CIP-002-3 through CIP-009-3. [Archive] [CAN-0031] [Implementation Plan] [Nuclear Implementation Plan] [Archive for Nuclear Implementation Plan] [Compliance Analysis Reports] |
02.16.2010 |
pdf |
| CIP-006-4c |
Cyber Security - Physical Security of Critical Cyber Assets
Standard CIP-006-4c is intended to ensure the implementation of a physical security program for the protection of Critical Cyber Assets. Standard CIP-006-4c should be read as part of a group of standards numbered Standards CIP-002-4 through CIP-009-4. [Archive] [CAN-0031] [Compliance Analysis Reports] |
01.24.2011 |
pdf |
| CIP-007-3 |
Cyber Security - Systems Security Management
Standard CIP-007-3 requires Responsible Entities to define methods, processes, and procedures for securing those systems determined to be Critical Cyber Assets, as well as the other (non-critical) Cyber Assets within the Electronic Security Perimeter(s). Standard CIP-007-3 should be read as part of a group of standards numbered Standards CIP-002-3 through CIP-009-3. [Archive] [CAN-0017] [Implementation Plan] [Nuclear Implementation Plan] [Archive for Nuclear Implementation Plan] [Compliance Analysis Reports] |
12.16.2009 |
pdf |
| CIP-007-4 |
Cyber Security - Systems Security Management
Standard CIP-007-4 requires Responsible Entities to define methods, processes, and procedures for securing those systems determined to be Critical Cyber Assets, as well as the other (non-critical) Cyber Assets within the Electronic Security Perimeter(s). Standard CIP-007-4 should be read as part of a group of standards numbered Standards CIP-002-4 through CIP-009-4. [Archive] [CAN-0017] [Compliance Analysis Reports] |
01.24.2011 |
pdf |
| CIP-008-3 |
Cyber Security - Incident Reporting and Response Planning
Standard CIP-008-3 ensures the identification, classification, response, and reporting of Cyber Security Incidents related to Critical Cyber Assets. Standard CIP-008-23 should be read as part of a group of standards numbered Standards CIP-002-3 through CIP-009-3. [Archive] [Implementation Plan] [Nuclear Implementation Plan] [Archive for Nuclear Implementation Plan] |
12.16.2009 |
pdf |
| CIP-008-4 |
Cyber Security - Incident Reporting and Response Planning
Standard CIP-008-4 ensures the identification, classification, response, and reporting of Cyber Security Incidents related to Critical Cyber Assets. Standard CIP-008-4 should be read as part of a group of standards numbered Standards CIP-002-4 through CIP-009-4. [Archive] |
01.24.2011 |
pdf |
| CIP-009-3 |
Cyber Security - Recovery Plans for Critical Cyber Assets
Standard CIP-009-3 ensures that recovery plan(s) are put in place for Critical Cyber Assets and that these plans follow established business continuity and disaster recovery techniques and practices. Standard CIP-009-3 should be read as part of a group of standards numbered Standards CIP-002-3 through CIP-009-3. [Archive] [Implementation Plan] [Nuclear Implementation Plan] [Archive for Nuclear Implementation Plan] |
12.16.2009 |
pdf |
| CIP-009-4 |
Cyber Security - Recovery Plans for Critical Cyber Assets
Standard CIP-009-4 ensures that recovery plan(s) are put in place for Critical Cyber Assets and that these plans follow established business continuity and disaster recovery techniques and practices. Standard CIP-009-4 should be read as part of a group of standards numbered Standards CIP-002-4 through CIP-009-4. [Archive] |
01.24.2011 |
pdf |
|
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Emergency Preparedness and Operations (EOP) |
| Number |
Title/Summary |
Date |
|
| EOP-001-0b |
Emergency Operations Planning
Each Transmission Operator and Balancing Authority needs to develop, maintain, and implement a set of plans to mitigate operating emergencies. These plans need to be coordinated with other Transmission Operators and Balancing Authorities, and the Reliability Coordinator. [Archive] [Archive to Interpretation a] [Archive to Interpretation b] |
11.04.2010 |
pdf |
| EOP-001-2b |
Emergency Operations Planning
Each Transmission Operator and Balancing Authority needs to develop, maintain, and implement a set of plans to mitigate operating emergencies. These plans need to be coordinated with other Transmission Operators and Balancing Authorities, and the Reliability Coordinator. [Archive] [Archive to Interpretation a] [Archive to Interpretation b] |
11.04.2010 |
pdf |
| EOP-002-3 |
Capacity and Energy Emergencies
To ensure Reliability Coordinators and Balancing Authorities are prepared for capacity and energy emergencies. [Archive] |
08.05.2010 |
pdf |
| EOP-003-1 |
Load Shedding Plans
A Balancing Authority and Transmission Operator operating with insufficient generation or transmission capacity must have the capability and authority to shed load rather than risk an uncontrolled failure of the Interconnection. [Archive] |
11.01.2006 |
pdf |
| EOP-003-2 |
Load Shedding Plans
A Balancing Authority and Transmission Operator operating with insufficient generation or transmission capacity must have the capability and authority to shed load rather than risk an uncontrolled failure of the Interconnection. [Archive] |
11.04.2010 |
pdf |
| EOP-004-1 |
Disturbance Reporting
Disturbances or unusual occurrences that jeopardize the operation of the Bulk Electric System, or result in system equipment damage or customer interruptions, need to be studied and understood to minimize the likelihood of similar events in the future. [Archive] [CAN-0039]
IROL and Preliminary Disturbance Reporting Form [Word Form] |
11.01.2006 |
pdf |
| EOP-005-1 |
System Restoration Plans
To ensure plans, procedures, and resources are available to restore the electric system to a normal condition in the event of a partial or total shut down of the system. [Archive] [CAN-0006] |
05.02.2006 |
pdf |
| EOP-005-2 |
System Restoration from Blackstart Resources
Ensure plans, Facilities, and personnel are prepared to enable System restoration from Blackstart Resources to assure reliability is maintained during restoration and priority is placed on restoring the Interconnection. [Archive] |
08.05.2009 |
pdf |
| EOP-006-1 |
Reliability Coordination - System Restoration
The Reliability Coordinator must have a coordinating role in system
restoration to ensure reliability is maintained during restoration and priority is placed
on restoring the Interconnection. [Archive] |
11.01.2006 |
pdf |
| EOP-006-2 |
System Restoration Coordination
Ensure plans are established and personnel are prepared to enable effective coordination of the System restoration process to ensure reliability is maintained during restoration and priority is placed on restoring the Interconnection. [Archive]
|
08.05.2009 |
pdf |
| EOP-008-0 |
Plans for Loss of Control Center Functionality
Each reliability entity must have a plan to continue reliability operations in the event its control center becomes inoperable. [Archive] |
02.08.2005 |
pdf |
| EOP-008-1 |
Loss of Control Center Functionality
Ensure continued reliable operations of the Bulk Electric System (BES) in the event that a control center becomes inoperable. [Archive] |
08.05.2010 |
pdf |
| EOP-009-0 |
Documentation of Blackstart Generating Unit Test Results
A system Blackstart Capability Plan (BCP) is necessary to ensure that the quantity and location of system blackstart generators are sufficient and that they can perform their expected functions as specified in overall coordinated Regional System Restoration Plans. [Archive] |
02.08.2005 |
pdf |
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Facilities Design, Connections, and Maintenance (FAC) |
| Number |
Title/Summary |
Date |
|
| FAC-001-0 |
Facility Connection Requirements
To avoid adverse impacts on reliability, Transmission Owners must establish facility connection and performance requirements. [Archive] |
02.08.2005 |
pdf |
| FAC-002-1 |
Coordination of Plans For New Generation, Transmission, and End-User Facilities
To avoid adverse impacts on reliability, Generator Owners and Transmission Owners and electricity end-users must meet facility connection and performance requirements. [Archive] |
08.05.2010 |
pdf |
| FAC-003-1 |
Transmission Vegetation Management Program
To improve the reliability of the electric transmission systems by preventing outages from vegetation located on transmission rights-of-way (ROW) and minimizing outages from vegetation located adjacent to ROW, maintaining clearances between transmission lines and vegetation on and along transmission ROW, and reporting vegetation related outages of the transmission systems to the respective Regional Reliability Organizations (RRO) and the North American Electric Reliability Council (NERC). [Archive] |
02.07.2006 |
pdf |
| FAC-003-2 |
Transmission Vegetation Management
To maintain a reliable electric transmission system by using a defense-in-depth strategy to manage vegetation located on transmission rights of way (ROW) and minimize encroachments from vegetation located adjacent to the ROW, thus preventing the risk of those vegetation-related outages that could lead to Cascading. [Archive] |
11.03.2011 |
pdf |
| FAC-008-1 |
Facility Ratings Methodology
To ensure that Facility Ratings used in the reliable planning and operation of the Bulk Electric System (BES) are determined based on an established methodology or methodologies. [Archive] [Compliance Analysis Reports] [CAN-0009] [CAN-0018] |
02.07.2006 |
pdf |
| FAC-008-3 |
Facility Ratings
To ensure that Facility Ratings used in the reliable planning and operation of the Bulk Electric System (BES) are determined based on technically sound principles. A Facility Rating is essential for the determination of System Operating Limits. [Archive] [CAN-0009] [CAN-0018] |
05.24.2011 |
pdf |
| FAC-009-1 |
Establish and Communicate Facility Ratings
To ensure that Facility Ratings used in the reliable planning and operation of the Bulk Electric System (BES) are determined based on an established methodology or methodologies. [Archive] [CAN-0009] [Compliance Analysis Reports] |
02.07.2006 |
pdf |
| FAC-010-2.1 |
System Operating Limits Methodology for the Planning Horizon
To ensure that System Operating Limits (SOLs) used in the reliable planning of the Bulk Electric System (BES) are determined based on an established methodology or methodologies. |
11.05.2009 |
pdf |
| FAC-011-2 |
System Operating Limits Methodology for the Operations Horizon
To ensure that System Operating Limits (SOLs) used in the reliable operation of the Bulk Electric System (BES) are determined based on an established methodology or methodologies. [Implementation Plan] [Archive] |
06.24.2008 |
pdf |
| FAC-012-1 |
Transfer Capability Methodology
To ensure that Transfer Capabilities used in the reliable planning and operation of the Bulk Electric System (BES) are determined based on an established methodology or methodologies. [Archive] |
02.07.2006 |
pdf |
| FAC-013-1 |
Establish and Communicate Transfer Capabilities
To ensure that Transfer Capabilities used in the reliable planning and operation of the Bulk Electric System (BES) are determined based on an established methodology or methodologies. [Archive] |
02.07.2006 |
pdf |
| FAC-013-2 |
Assessment of Transfer Capability for the Near-term Transmission Planning Horizon
To ensure that Planning Coordinators have a methodology for, and perform an annual assessment to identify potential future Transmission System weaknesses and limiting Facilities that could impact the Bulk Electric System’s (BES) ability to reliably transfer energy in the Near-Term Transmission Planning Horizon. [Archive] |
01.24.2011 |
pdf |
| FAC-014-2 |
Establish and Communicate System Operating Limits
To ensure that System Operating Limits (SOLs) used in the reliable planning and operation of the Bulk Electric System (BES) are determined based on an established methodology or methodologies. [Implementation Plan] [Archive] |
06.24.2008 |
pdf |
| FAC-501-WECC-1 |
Transmission Maintenance (WECC)
To ensure the Transmission Owner of a transmission path identified in the table titled “Major WECC Transfer Paths in the Bulk Electric System” including associated facilities has a Transmission Maintenance and Inspection Plan (TMIP); and performs and documents maintenance and inspection activities in accordance with the TMIP. [Archive] |
10.29.2008 |
pdf |
|
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Interconnection Reliability Operations and Coordination (IRO) |
| Number |
Title/Summary |
Date |
|
| IRO-001-1.1 |
Reliability Coordination - Responsibilities and Authorities
Reliability Coordinators must have the authority, plans, and agreements in place to immediately direct reliability entities within their Reliability Coordinator Areas to re-dispatch generation, reconfigure transmission, or reduce load to mitigate critical conditions to return the system to a reliable state. If a Reliability Coordinator delegates tasks to others, the Reliability Coordinator retains its responsibilities for complying with NERC and regional standards. Standards of conduct are necessary to ensure the Reliability Coordinator does not act in a manner that favors one market participant over another. [Archive] |
10.29.2008 |
pdf |
| IRO-001-2 |
Reliability Coordination - Responsibilities and Authorities
Reliability Coordinators must have the authority, plans, and agreements in place to immediately direct reliability entities within their Reliability Coordinator Areas to re-dispatch generation, reconfigure transmission, or reduce load to mitigate critical conditions to return the system to a reliable state. If a Reliability Coordinator delegates tasks to others, the Reliability Coordinator retains its responsibilities for complying with NERC and regional standards. Standards of conduct are necessary to ensure the Reliability Coordinator does not act in a manner that favors one market participant over another. [Archive] |
08.04.2011 |
pdf |
| IRO-002-2 |
Reliability Coordination - Facilities
Reliability Coordinators need information, tools and other capabilities to perform their responsibilities. [Archive] |
10.17.2008 |
pdf |
| IRO-002-3 |
Reliability Coordination - Analysis Tools
To ensure that Reliability Coordinators provide their System Operators with authority with respect to analysis tool outages and to have procedures to mitigate effects of analysis tool outages. [Archive] |
08.04.2011 |
pdf |
| IRO-003-2 |
Reliability Coordination - Wide-Area View
The Reliability Coordinator must have a wide-area view of its own Reliability Coordinator Area and that of neighboring Reliability Coordinators. [Archive] |
11.01.2006 |
pdf |
| IRO-004-2 |
Reliability Coordination - Operations Planning
Each Reliability Coordinator must conduct next-day reliability analyses for its Reliability Coordinator Area to ensure the Bulk Electric System can be operated reliably in anticipated normal and Contingency conditions. System studies must be conducted to highlight potential interface and other operating limits, including overloaded transmission lines and transformers, voltage and stability limits, etc. Plans must be developed to alleviate System Operating Limit (SOL) and Interconnection Reliability Operating Limit (IROL) violations. [Archive] |
10.17.2008 |
pdf |
| IRO-005-3a |
Reliability Coordination - Current Day Operations
The Reliability Coordinator must be continuously aware of conditions within its Reliability Coordinator Area and include this information in its reliability assessments. The Reliability Coordinator must monitor Bulk Electric System parameters that may have significant impacts upon the Reliability Coordinator Area and neighboring Reliability Coordinator Areas. [Archive] [Archive to Interpretation] |
10.17.2008 |
pdf |
| IRO-005-4 |
Reliability Coordination - Current Day Operations
To ensure that entities are notified when an expected or actual event with Adverse Reliability Impacts is identified. [Archive] |
08.04.2011 |
pdf |
| IRO-006-5 |
Reliability Coordination - Transmission Loading Relief (TLR)
To ensure coordinated action between Interconnections when implementing Interconnection-wide transmission loading relief procedures to prevent or manage potential or actual SOL and IROL exceedances to maintain reliability of the bulk electric system. [Archive] |
11.04.2010 |
pdf |
| IRO-006-EAST-1 |
Transmission Loading Relief Procedure for the Eastern Interconnection
To provide an Interconnection-wide transmission loading relief procedure (TLR) for the Eastern Interconnection that can be used to prevent and/or mitigate potential or actual System Operating Limit (SOL) and Interconnection Reliability Operating Limit (IROL) exceedances to maintain reliability of the Bulk Electric System (BES). [Reference: TLR Levels] |
11.04.2010 |
pdf |
| IRO-006-TRE-1 |
IROL and SOL Mitigation in the ERCOT Region
To provide and execute transmission loading relief procedures that can be used to mitigate SOL or IROL exceedances for the purpose of maintaining reliable operation of the bulk electric system in the ERCOT Region. [Archive] |
11.03.2011 |
pdf |
| IRO-006-WECC-1 |
Qualified Transfer Path Unscheduled Flow Relief (WECC)
Mitigation of transmission overloads due to unscheduled flow on Qualified Transfer Paths. [Archive] |
02.10.2009 |
pdf |
| IRO-008-1 |
Reliability Coordinator Operational Analyses and Real-time Assessments
To prevent instability, uncontrolled separation, or cascading outages that adversely impact the reliability of the interconnection by ensuring that the Bulk Electric System is assessed during the operations horizon. [Archive] |
10.17.2008 |
pdf |
| IRO-009-1 |
Reliability Coordinator Actions to Operate Within IROLs
To prevent instability, uncontrolled separation, or cascading outages that adversely impact the reliability of the interconnection by ensuring prompt action to prevent or mitigate instances of exceeding Interconnection Reliability Operating Limits (IROLs). [Archive] |
10.17.2008 |
pdf |
| IRO-010-1a |
Reliability Coordinator Data Specification and Collection
To prevent instability, uncontrolled separation, or cascading outages that adversely impact the reliability of the interconnection by ensuring the Reliability Coordinator has the data it needs to monitor and assess the operation of its Reliability Coordinator Area. [Archive] [Archive to Interpretation] |
08.05.2009 |
pdf |
| IRO-014-1 |
Procedures, Processes, or Plans to Support Coordination Between Reliability Coordinators
To ensure that each Reliability Coordinator’s operations are coordinated such that they will not have an Adverse Reliability Impact on other Reliability Coordinator Areas and to preserve the reliability benefits of interconnected operations. [Archive] |
02.07.2006 |
pdf |
| IRO-014-2 |
Coordination Among Reliability Coordinators
To ensure that each Reliability Coordinator’s operations are coordinated such that they will not have an Adverse Reliability Impact on other Reliability Coordinator Areas and to preserve the reliability benefits of interconnected operations. [Archive] |
08.04.2011 |
pdf |
| IRO-015-1 |
Notifications and Information Exchange Between Reliability Coordinators
To ensure that each Reliability Coordinator’s operations are coordinated such that they will not have an Adverse Reliability Impact on other Reliability Coordinator Areas and to preserve the reliability benefits of interconnected operations. [Archive] |
02.07.2006 |
pdf |
| IRO-016-1 |
Coordination of Real-time Activities Between Reliability Coordinators
To ensure that each Reliability Coordinator’s operations are coordinated such that they will not have an Adverse Reliability Impact on other Reliability Coordinator Areas and to preserve the reliability benefits of interconnected operations. [Archive] |
02.07.2006 |
pdf |
|
|
Modeling, Data, and Analysis (MOD) |
| Number |
Title/Summary |
Date |
|
| MOD-001-1a |
Available Transmission System Capability
To ensure that calculations are performed by Transmission Service Providers to maintain awareness of available transmission system capability and future flows on their own systems as well as those of their neighbors [Archive][Archive to Interpretation] |
11.05.2009 |
pdf |
| MOD-004-1 |
Capacity Benefit Margin
To promote the consistent and reliable calculation, verification, preservation, and use of Capacity Benefit Margin (CBM) to support analysis and system operations. [Archive] |
11.13.2008 |
pdf |
| MOD-008-1 |
Transmission Reliability Margin Calculation Methodology
To promote the consistent and reliable calculation, verification, preservation, and use of Transmission Reliability Margin (TRM) to support analysis and system operations. [Archive] |
08.26.2008 |
pdf |
| MOD-010-0 |
Steady-State Data for Modeling and Simulation of the Interconnected Transmission System
To establish consistent data requirements, reporting procedures, and system models to be used in the analysis of the reliability of the Interconnected Transmission Systems. [Archive] |
02.08.2005 |
pdf |
| MOD-011-0 |
Maintenance and Distribution of Steady-State Data Requirements and Reporting Procedures
To establish consistent data requirements, reporting procedures, and system models to be used in the analysis of the reliability of the interconnected transmission systems. [Archive] |
02.08.2005 |
pdf |
| MOD-012-0 |
Dynamics Data for Modeling and Simulation of the Interconnected Transmission System
To establish consistent data requirements, reporting procedures, and system models to be used in the analysis of the reliability of the interconnected transmission systems. [Archive] |
02.08.2005 |
pdf |
| MOD-013-1 |
Maintenance and Distribution of Dynamics Data Requirements and Reporting Procedures
To establish consistent data requirements, reporting procedures, and system models to be used in the analysis of the reliability of the interconnected transmission systems. [Archive] |
05.02.2006 |
pdf |
| MOD-014-0 |
Development of Steady-State System Models
To establish consistent data requirements, reporting procedures, and system models to be used in the analysis of the reliability of the interconnected transmission systems. [Archive] |
02.08.2005 |
pdf |
| MOD-015-0 |
Development of Dynamics System Models
To establish consistent data requirements, reporting procedures, and system models to be used in the analysis of the reliability of the interconnected transmission systems. [Archive] |
02.08.2005 |
pdf |
| MOD-015-0.1 |
Development of Dynamics System Models
To establish consistent data requirements, reporting procedures, and system models to be used in the analysis of the reliability of the interconnected transmission systems. [Archive] |
10.29.2008 |
pdf |
| MOD-016-1.1 |
Documentation of Data Reporting Requirements for Actual and Forecast Demands
Net Energy for Load, and Controllable Demand-Side Management
Ensure that accurate, actual Demand data is available to support assessments and validation of past events and databases. Forecast Demand data is needed to perform future system assessments to identify the need for system reinforcements for continued reliability. In addition, to assist in proper real-time operating, Load information related to controllable Demand-Side Management (DSM) programs is needed. [Archive] |
10.29.2008 |
pdf |
| MOD-017-0.1 |
Aggregated Actual and Forecast Demands and Net Energy for Load
To ensure that assessments and validation of past events and databases can be performed, reporting of actual Demand data is needed. Forecast demand data is needed to perform future system assessment to identify the need for system reinforcement for continued reliability. In addition to assist in proper real-time operating, load information related to controllable Demand-Side Management programs is needed. [Archive] |
10.29.2008 |
pdf |
| MOD-018-0 |
Treatment of Nonmember Demand Data and How Uncertainties are Addressed in the Forecasts of Demand and Net Energy for Load
To ensure that Assessments and validation of past events and databases can be performed, reporting of actual demand data is needed. Forecast demand data is needed to perform future system assessments to identify the need for system reinforcement for continued reliability. In addition, to assist in proper real-time operating, load information related to controllable Demand-Side Management programs is needed. [Archive] |
02.08.2005 |
pdf |
| MOD-019-0.1 |
Reporting of Interruptible Demands and Direct Control Load Management
To ensure that assessments and validation of past events and databases can be performed, reporting of actual demand data is needed. Forecast demand data is needed to perform future system assessments to identify the need for system reinforcement for continued reliability. In addition, to assist in proper real-time operating, load information related to controllable Demand-Side Management programs is needed. [Archive] |
10.29.2008 |
pdf |
| MOD-020-0 |
Providing Interruptible Demands and Direct Control Load Management Data to System Operators and Reliability Coordinators
To ensure that assessments and validation of past events and databases can be performed, reporting of actual demand data is needed. Forecast demand data is needed to perform future system assessments to identify the need for system reinforcement for continued reliability. In addition to assist in proper real-time operating, load information related to controllable Demand-Side Management programs is needed. [Archive] |
02.08.2005 |
pdf |
| MOD-021-1 |
Documentation of the Accounting Methodology for the Effects of Demand-Side Management in Demand and Energy Forecasts
To ensure that assessments and validation of past events and databases can be performed, reporting of actual Demand data is needed. Forecast demand data is needed to perform future system assessments to identify the need for system reinforcement for continued reliability. In addition, to assist in proper real-time operating, load information related to Demand-Side Management (DSM) programs is needed. [Archive] |
08.05.2010 |
pdf |
| MOD-024-1 |
Verification of Generator Gross and Net Real Power Capability
To ensure accurate information on generator gross and net Real Power capability is available for steady-state models used to assess Bulk Electric System reliability. [Archive] |
02.07.2006 |
pdf |
| MOD-025-1 |
Verification of Generator Gross and Net Reactive Power Capability
To ensure accurate information on generator gross and net Reactive Power capability is available for steady-state models used to assess Bulk Electric System reliability. [Archive] |
02.07.2006 |
pdf |
| MOD-025-RFC-01 |
Verification and Data Reporting of Generator Gross and Net Reactive Power Capability
To ensure that planning entities have accurate generator gross and net Reactive Power capability modeling data to use in system planning studies. [Archive] |
11.03.2011 |
pdf |
| MOD-028-1 |
Area Interchange Methodology
To increase consistency and reliability in the development and documentation of Transfer Capability calculations for short-term use performed by entities using the Area Interchange Methodology to support analysis and system operations. [Archive] |
08.26.2008 |
pdf |
| MOD-029-1a |
Rated System Path Methodology
To increase consistency and reliability in the development and documentation of transfer capability calculations for short-term use performed by entities using the Rated System Path Methodology to support analysis and system operations. [Archive] [Archive to Interpretation] |
11.05.2009 |
pdf |
| MOD-030-2 |
Flowgate Methodology
To increase consistency and reliability in the development and documentation of transfer capability calculations for short-term use performed by entities using the Flowgate Methodology to support analysis and system operations. [Archive] |
02.10.2009 |
pdf |
|
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Personnel Performance, Training, and Qualifications (PER) |
| Number |
Title/Summary |
Date |
|
| PER-001-0.1 |
Operating Personnel Responsibility and Authority
Transmission Operator and Balancing Authority operating personnel must have the responsibility and authority to implement real-time actions to ensure the stable and reliable operation of the Bulk Electric System. [Archive] |
04.15.2009 |
pdf |
| PER-002-0 |
Operating Personnel Training
Each Transmission Operator and Balancing Authority must provide their personnel with a coordinated training program that will ensure reliable system operation. [Archive] [Compliance Analysis Reports] |
02.08.2005 |
pdf |
| PER-003-0 |
Operating Personnel Credentials
Certification of operating personnel is necessary to ensure minimum competencies for operating a reliable Bulk Electric System. [Archive] |
02.08.2005 |
pdf |
| PER-003-1 |
Operating Personnel Credentials
To ensure that System Operators performing the reliability-related tasks of the Reliability Coordinator, Balancing Authority and Transmission Operator are certified through the NERC System Operator Certification Program when filling a Real-time operating position responsible for control of the Bulk Electric System. [Archive] |
02.17.2011 |
pdf |
| PER-004-1 |
Reliability Coordination - Staffing
Reliability Coordinators must have sufficient, competent staff to perform the Reliability Coordinator functions. [Archive] |
11.01.2006 |
pdf |
| PER-004-2 |
Reliability Coordination - Staffing
Reliability Coordinators must have sufficient, competent staff to perform the Reliability Coordinator functions. [Archive] |
02.10.2009 |
pdf |
| PER-005-1 |
System Personnel Training
To ensure that System Operators performing real-time, reliability-related tasks on the North American Bulk Electric System (BES) are competent to perform those reliability-related tasks. The competency of System Operators is critical to the reliability of the North American Bulk Electric System. [Archive] |
02.10.2009 |
pdf |
|
|
Protection and Control (PRC) |
| Number |
Title/Summary |
Date |
|
| PRC-001-1 |
System Protection Coordination
To ensure system protection is coordinated among operating entities. [Archive] |
11.01.2006 |
pdf |
| PRC-002-1 |
Define Regional Disturbance Monitoring and Reporting Requirements
Ensure that Regional Reliability Organizations establish requirements for installation of Disturbance Monitoring Equipment (DME) and reporting of Disturbance data to facilitate analyses of events and verify system models. [Archive] |
08.02.2006 |
pdf |
| PRC-002-NPCC-01 |
Disturbance Monitoring
Ensure that adequate disturbance data is available to facilitate Bulk Electric System event analyses. All references to equipment and facilities herein unless otherwise noted will be to Bulk Electric System (BES) elements. [Archive] |
11.04.2010 |
pdf |
| PRC-003-1 |
Regional Procedure for Analysis of Misoperations of Transmission and Generation Protection Systems
To ensure all transmission and generation Protection System Misoperations affecting the reliability of the Bulk Electric System (BES) are analyzed and mitigated. [Archive] |
02.07.2006 |
pdf |
| PRC-004-1a |
Analysis and Mitigation of Transmission and Generation Protection System Misoperations
Ensure all transmission and generation Protection System Misoperations affecting the reliability of the Bulk Electric System (BES) are analyzed and mitigated. [Archive] [Archive to Interpretation] [CAN-0029] |
02.17.2011 |
pdf |
| PRC-004-2a |
Analysis and Mitigation of Transmission and Generation Protection System Misoperations
Ensure all transmission and generation Protection System Misoperations affecting the reliability of the Bulk Electric System (BES) are analyzed and mitigated. [Archive] [Archive to Interpretation] [CAN-0029] |
02.17.2011 |
pdf |
| PRC-004-WECC-1 |
Protection System and Remedial Action Scheme Misoperation (WECC)
Regional Reliability Standard to ensure all transmission and generation Protection System and Remedial Action Scheme (RAS) Misoperations on Transmission Paths and RAS defined in section 4 are analyzed and/or mitigated. [Archive] [CAN-0029] |
10.29.2008 |
pdf |
| PRC-005-1a |
Transmission and Generation Protection System Maintenance and Testing
To ensure all transmission and generation Protection Systems affecting the reliability of the Bulk Electric System (BES) are maintained and tested. [Archive] [Archive to Interpretation] [CAN-0008] [CAN-0011] [CAN-0043] |
02.17.2011 |
pdf |
| PRC-006-0 |
Development and Documentation of Regional UFLS Programs
Provide last resort system preservation measures by implementing an Under
Frequency Load Shedding (UFLS) program. [Archive] |
02.08.2005 |
pdf |
| PRC-006-1 |
Automatic Underfrequency Load Shedding
To establish design and documentation requirements for automatic underfrequency load shedding (UFLS) programs to arrest declining frequency, assist recovery of frequency following underfrequency events and provide last resort system preservation measures. [Archive] |
11.04.2010 |
pdf |
| PRC-006-SERC-01 |
Automatic Underfrequency Load Shedding Requirements
To establish consistent and coordinated requirements for the design, implementation, and analysis of automatic underfrequency load shedding (UFLS) programs among all SERC applicable entities. [Archive] |
11.03.2011 |
pdf |
| PRC-007-0 |
Assuring Consistency of Entity Underfrequency Load Shedding Programs
Provide last resort System preservation measures by implementing an Under Frequency Load Shedding (UFLS) program. [Archive] |
02.08.2005 |
pdf |
| PRC-008-0 |
Implementation and Documentation of Underfrequency Load Shedding Equipment Maintenance Program
Provide last resort system preservation measures by implementing an Under Frequency Load Shedding (UFLS) program. [Archive] |
02.08.2005 |
pdf |
| PRC-009-0 |
Analysis and Documentation of Underfrequency Load Shedding Performance Following an Underfrequency Event
Provide last resort System preservation measures by implementing an Under Frequency Load Shedding (UFLS) program. [Archive] |
02.08.2005 |
pdf |
| PRC-010-0 |
Technical Assessment of the Design and Effectiveness of Undervoltage Load Shedding Program
Provide System preservation measures in an attempt to prevent system voltage collapse or voltage instability by implementing an Undervoltage Load Shedding (UVLS) program. [Archive] |
02.08.2005 |
pdf |
| PRC-011-0 |
Undervoltage Load Shedding System Maintenance and Testing
Provide system preservation measures in an attempt to prevent system voltage collapse or voltage instability by implementing an Undervoltage Load Shedding (UVLS) program. [Archive] |
02.08.2005 |
pdf |
| PRC-012-0 |
Special Protection System Review Procedure
To ensure that all Special Protection Systems (SPS) are properly designed, meet performance requirements, and are coordinated with other protection systems. To ensure that maintenance and testing programs are developed and misoperations are analyzed and corrected. [Archive] |
02.08.2005 |
pdf |
| PRC-013-0 |
Special Protection System Database
To ensure that all Special Protection Systems (SPSs) are properly designed, meet performance requirements, and are coordinated with other protection systems. [Archive] |
02.08.2005 |
pdf |
| PRC-014-0 |
Special Protection System Assessment
To ensure that all Special Protection Systems (SPS) are properly designed, meet performance requirements, and are coordinated with other protection systems. To ensure that maintenance and testing programs are developed and misoperations are analyzed and corrected. [Archive] |
02.08.2005 |
pdf |
| PRC-015-0 |
Special Protection System Data and Documentation
To ensure that all Special Protection Systems (SPS) are properly designed, meet performance requirements, and are coordinated with other protection systems. To ensure that maintenance and testing programs are developed and misoperations are analyzed and corrected. [Archive] |
02.08.2005 |
pdf |
| PRC-016-0.1 |
Special Protection System Misoperations
To ensure that all Special Protection Systems (SPS) are properly designed, meet performance requirements, and are coordinated with other protection systems. To ensure that maintenance and testing programs are developed and misoperations are analyzed and corrected. [Archive] |
10.29.2008 |
pdf |
| PRC-017-0 |
Special Protection System Maintenance and Testing
To ensure that all Special Protection Systems (SPS) are properly designed, meet performance requirements, and are coordinated with other protection systems. To ensure that maintenance and testing programs are developed and misoperations are analyzed and corrected. [Archive] |
02.08.2005 |
pdf |
| PRC-018-1 |
Disturbance Monitoring Equipment Installation and Data Reporting
Ensure that Disturbance Monitoring Equipment (DME) is installed and that Disturbance data is reported in accordance with regional requirements to facilitate analyses of events. [Archive] |
08.02.2006 |
pdf |
| PRC-020-1 |
Under-Voltage Load Shedding Program Database
Ensure that a regional database is maintained for Under-Voltage Load Shedding (UVLS) programs implemented by entities within the Region to mitigate the risk of voltage collapse or voltage instability in the Bulk Electric System (BES). Ensure the UVLS database is available for Regional studies and for dynamic studies and simulations of the BES. [Archive] |
02.07.2006 |
pdf |
| PRC-021-1 |
Under-Voltage Load Shedding Program Data
Ensure data is provided to support the Regional database maintained for Under-Voltage Load Shedding (UVLS) programs that were implemented to mitigate the risk of voltage collapse or voltage instability in the Bulk Electric System (BES). [Archive] |
02.07.2006 |
pdf |
| PRC-022-1 |
Under-Voltage Load Shedding Program Performance
Ensure that Under Voltage Load Shedding (UVLS) programs perform as intended to mitigate the risk of voltage collapse or voltage instability in the Bulk Electric System (BES). [Archive] |
02.07.2006 |
pdf |
| PRC-023-1 |
Transmission Relay Loadability
Protective relay settings shall not limit transmission loadability; not interfere with system operators’ ability to take remedial action to protect system reliability and; be set to reliably detect all fault conditions and protect the electrical network from these faults. [Archive] [Reference] [CAN-0013] |
02.12.2008 |
pdf |
| PRC-023-2 |
Transmission Relay Loadability
Protective relay settings shall not limit transmission loadability; not interfere with system operators' ability to take remedial action to protect system reliability and; be set to reliably detect all fault conditions and protect the electrical network from these faults. [Archive] [CAN-0013] |
03.10.2011 |
pdf |
|
|
Transmission Planning (TPL) |
| Number |
Title/Summary |
Date |
|
| TPL-001-0.1 |
System Performance Under Normal (No Contingency) Conditions (Category A)
System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements with sufficient lead time, and continue to be modified or upgraded as necessary to meet present and future system needs. [Archive] |
10.29.2008 |
pdf |
| TPL-001-1 |
System Performance Under Normal Conditions
System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements with sufficient lead time, and continue to be modified or upgraded as necessary to meet present and future system needs. [Archive] |
02.17.2011 |
pdf |
| TPL-001-2 |
Transmission System Planning Performance Requirements
Establish Transmission system planning performance requirements within the planning horizon to develop a Bulk Electric System (BES) that will operate reliably over a broad spectrum of System conditions and following a wide range of probable Contingencies. [Archive] |
08.04.2011 |
pdf |
| TPL-002-0b |
System Performance Following Loss of a Single Bulk Electric System Element (Category B)
System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements with sufficient lead time, and continue to be modified or upgraded as necessary to meet present and future system needs. [Archive to Interpretation a][Archive to Interpretation b] [CAN-0020] |
11.05.2009 |
pdf |
| TPL-002-1b |
System Performance Following Loss of a Single BES Element
System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements with sufficient lead time, and continue to be modified or upgraded as necessary to meet present and future system needs. [Archive] [CAN-0020] |
02.17.2011 |
pdf |
| TPL-003-0a |
System Performance Following Loss of Two or More Bulk Electric System Elements (Category C)
System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements, with sufficient lead time and continue to be modified or upgraded as necessary to meet present and future System needs. [Archive to Interpretation] [CAN-0020] |
07.30.2008 |
pdf |
| TPL-003-1a |
System Performance Following Loss of Two or More BES Elements
System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements, with sufficient lead time and continue to be modified or upgraded as necessary to meet present and future System needs. [Archive] [CAN-0020] |
02.17.2011 |
pdf |
| TPL-004-0 |
System Performance Following Extreme Events Resulting in the Loss of Two or More Bulk Electric System Elements (Category D)
System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements, with sufficient lead time and continue to be modified or upgraded as necessary to meet present and future System needs. [Archive] [CAN-0020] |
02.08.2005 |
pdf |
| TPL-004-1 |
System Performance Following Extreme BES Events
System simulations and associated assessments are needed periodically to ensure that reliable systems are developed that meet specified performance requirements, with sufficient lead time and continue to be modified or upgraded as necessary to meet present and future System needs. [Archive] [CAN-0020] |
02.17.2011 |
pdf |
| TPL-005-0 |
Regional and Interregional Self-Assessment Reliability Reports
To ensure that each Regional Reliability Organization complies with planning criteria, for assessing the overall reliability (Adequacy and Security) of the interconnected Bulk Electric Systems, both existing and as planned. [Archive] |
02.08.2005 |
pdf |
| TPL-006-0 |
Data From the Regional Reliability Organization Needed to Assess Reliability
To ensure that each Regional Reliability Organization complies with planning criteria, for assessing the overall reliability (Adequacy and Security) of the interconnected Bulk Electric Systems, both existing and as planned. [Archive] |
02.08.2005 |
pdf |
| TPL-006-0.1 |
Data From the Regional Reliability Organization Needed to Assess Reliability
To ensure that each Regional Reliability Organization complies with planning criteria, for assessing the overall reliability (Adequacy and Security) of the interconnected Bulk Electric Systems, both existing and as planned. [Archive] |
04.15.2009 |
pdf |
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