Table of Compliance Elements R # Time Horizon VRF Violation Severity Levels Lower VSL Moderate VSL High VSL Severe VSL R1 Operations 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 Operations 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 Operations 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.
R6 Operations Planning Lower The Transmission Operator does not provide either the technical justification or timeframe for changing generator step-up tap settings. N/A N/A The Transmission Operator does not provide the technical justification and the timeframe for changing generator step-up tap settings.
Violation Severity Levels E # Lower VSL Moderate VSL High VSL Severe VSL E.A.13 For the specified period, the Transmission Operator did not issue one of the 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. For the specified period, the Transmission Operator did not issue one of the 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. For the specified period, the Transmission Operator did not issue one of the 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. For the specified period, the Transmission Operator did not issue one of the voltage schedules listed in E.A.13 to more than 15% of the generation resources that are on-line 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. 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. The Transmission Operator provided 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. The Transmission Operator provided its data to support development of the voltage set point conversion methodology greater than 60 days but less than or equal to 90 days of a request by the Generator. Operator. The Transmission Operator provided its data to support development of the voltage set point conversion methodology greater than 90 days but less than or equal to 120 days of a request by the Generator. Operator. The Transmission Operator did not provide its data to support development of the voltage set point conversion methodology within 120 days of a request by the Generator Operator. E.A. N/A The Generator Operator did not meet the control loop specifications in .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 .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 .1 through .2 when the Generator Operator uses control loop external to the AVR to manage Mvar loading. E. Interpretations None F. Associated Documents None. 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 Directives contained in paragraphs 1858 and 1879. Revised 2 January 10 2011 Revised 3 May 9, 2012 Adopted by NERC Board of Trustees; Modified to add a WECC region variance Revised 3 June 20, 2013 FERC issued order approving VAR-001-3 Revised 3 November 21, 2013 R5 and associated elements approved by FERC for retirement as part of the Paragraph 81 project (Project 2013-02) Revised 4 February 6, 2014 Adopted by NERC Board of Trustees Revised 4 August 1, 2014 FERC issued letter order issued approving 4.1 August 25, 2015 Added “or” to Requirement R5, 5.3 to read: schedules or Reactive Power Errata 4.1 November 13, 2015 FERC Letter Order approved errata to Docket RD15-6-000 Errata 4.2 June 14, 2017 Project 2016-EPR-02 errata recommendations Errata 4.2 August 10, 2017 Adopted by NERC Board of Trustees Errata 4.2 September 26, 2017 FERC Letter Order issued approving VAR-001-4.2 Docket No. RD17-7-000. 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 margins (i.e. voltage and/or reactive power margins)." Since Order No. 693 was issued, however, several FAC and TOP standards have become enforceable to add more requirements around voltage limits. More specifically, FAC-011 and FAC-014 require that System Operating Limits (SOLs) and reliability margins are established. The NERC Glossary