Table of Compliance Elements R # Time Horizon VRF Violation Severity Levels Lower VSL Moderate VSL High VSL Severe VSL R1 Operational Planning High N/A N/A N/A The Transmission Operator does not specify a system voltage schedule (which is either a range or a target value with an associated tolerance band). R2 Real-time Operations, Same-day Operations, and Operational Planning High N/A N/A The Transmission Operator does not schedule sufficient reactive resources as necessary to avoid violating an SOL. The Transmission Operator does not schedule sufficient reactive resources as necessary to avoid violating an IROL. R3 Real-time Operations, Same-day Operations, and Operational Planning High N/A N/A The Transmission Operator does not operate or direct any real-time operation of devices as necessary to avoid violating an SOL. The Transmission Operator does not operate or direct any real-time operation of devices as necessary to avoid violating an IROL.
voltage schedules listed in E.A.13 to at least one generation resource but less than or equal to 5% of the generation resources that are on-line and part of the BES in the Transmission Operator Area. voltage schedules listed in E.A.13 to more than 5% but less than or equal to 10% of the generation resources that are on-line and part of the BES in the Transmission Operator Area. voltage schedules listed in E.A.13 to more than 10% but less than or equal to 15% of the generation resources that are on-line and part of the BES in the Transmission Operator Area. in E.A.13 to more than 15% of the generation resources that are and part of the BES in the Transmission Operator Area. E.A.14 The Transmission Operator did not provide a voltage schedule reference point for at least one but less than or equal to 5% of the generation resources in the Transmission Operator area. The Transmission Operator did not provide a voltage schedule reference point for more than 5% but less than or equal to 10% of the generation resources in the Transmission Operator Area. The Transmission Operator did not a voltage schedule reference point for more than 10% but less than or equal to 15% of the generation resources in the Transmission Operator Area. The Transmission Operator did not provide a voltage schedule reference point for more than 15% of the generation resources in the Transmission Operator Area. E.A.1 The Generator Operator provided its voltage set point conversion methodology greater than 30 days but less than or equal to 60 days of a request by the Transmission Operator. The Generator Operator provided its voltage set point conversion methodology greater than 60 days but less than or equal to 90 days of a request by the Transmission Operator. The Generator Operator provided its voltage set point conversion methodology greater than 90 days but less than or equal to 120 days of a request by the Transmission Operator. The Generator Operator did not provide its voltage set point conversion methodology within 120 days of a request by the Transmission Operator. E.A.1 The Transmission Operator provided its data to support development of the voltage set point The Transmission Operator provided its data to support development of the voltage set point The Transmission Operator provided its data to support development of the voltage set The Transmission Operator did not provide its data to support development of the voltage set point
conversion methodology than 30 days but less than or equal to 60 days of a request by the Generator Operator. conversion methodology greater than 60 days but less than or equal to 90 days of a request by the Generator. Operator. point conversion methodology greater than 90 days but less than or equal to 120 days of a request by the Generator. Operator. conversion methodology within 120 days of a request by the Generator Operator. E.A.1 N/A The Generator Operator did not meet the control loop specifications in EA1.2 when the Generator Operator uses control loop external to the AVR to manage Mvar loading. The Generator Operator did not meet the control loop specifications in EA1.1 when the Generator Operator uses control loop external to the AVR to manage Mvar loading. The Generator Operator did not meet the control loop specifications in EA1.1 through EA1.2 when the Generator Operator uses control loop external to the AVR to manage Mvar loading. E. Interpretations None. F. Associated Documents None. Guidelines and Technical Basis For technical basis for each requirement, please review the rationale provided for each requirement. Rationale: During development of this standard, text boxes were embedded within the standard to explain the rationale for various parts of the standard. Upon BOT approval, the text from the rationale text boxes was moved to this section. Rationale for R1: Paragraph 1868 of Order No. 693 requires NERC to add more "detailed and definitive requirements on “established limits” and “sufficient reactive resources”, and identify acceptable
Rationale for R5: The new requirement provides transparency regarding the criteria used by the TOP to establish the voltage schedule. This requirement also provides a vehicle for the TOP to use appropriate granularity when setting notification requirements for deviation from the voltage or Reactive Power schedule. Additionally, this requirement provides clarity regarding a “tolerance band” as specified in the voltage schedule and the control dead-band in the generator’s excitation system. Voltage Schedule tolerances are the bandwidth that accompanies the voltage target in a voltage schedule, should reflect the anticipated fluctuation in voltage at the Generation Operator’s facility during normal operations, and be based on the TOP’s assessment of N‐1 and credible N‐2 system contingencies. The voltage schedule’s bandwidth should not be confused with the control dead‐band that is programmed into a Generation Operator’s automatic voltage regulator’s control system, which should be adjusting the AVR prior to reaching either end of the voltage schedule’s bandwidth. Rationale for R6: Although tap settings are first established prior to interconnection, this requirement could not be deleted because no other standard addresses when a tap setting must be adjusted. If the tap setting is not properly set, then the amount of VARs produced by a unit can be affected. Version History Version Date Action Change Tracking 0 April 1, 2005 Effective Date New 1 August 2, 2006 BOT Adoption Revised 1 June 18, 2007 FERC approved Version 1 of the standard. Revised 1 July 3, 2007 Added “Generator Owners” and “Generator Operators” to Applicability section. Errata 1 August 23, 2007 Removed “Generator Owners” and “Generator Operators” to Applicability section. Errata 2 August 5, 2010 Adopted by NERC Board of Trustees; Modified to address Order No. 693 Revised