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Summary of WECC Reliability Management System

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					Summary of WECC Reliability Management System Before the WECC Market Issues Subcommittee David Lemmons Xcel Energy

Operating Reserves Operating Reserves – WECC Operating Reserve Requirement which includes Contingency Reserves and Regulating Reserves Disturbance Control Meet Disturbance Control Standard (DCS) Amendment 1 modified to require ACE to be returned to 0 or pre-contingency ACE. Control Performance Standard One (CPS1) Meet Regulating Requirement Control Performance Standard Two (CPS2) Meet Regulating Requirement Operating Transfer Capability Actual Power Flow and Net Scheduled Power flow shall not be allowed to exceed OTC limit for more than 30 minutes for thermal limits and 10 minutes for stability limits. Amendment 3 modified the time limit for stability limits from 10 minutes to 20 minutes. Generator Power System Stabilizer (PSS) and Automatic Voltage Regulator (AVR) PSS Shall be kept in service and tuned to WECC specifications. AVR shall be in service as much as possible and outages shall be coordinated. Amendment 2 Operating Limits Available to System Operators Officer of Organization must certify that OTC limits have been developed according to WECC criteria and provided to appropriate parties and system operators. Certification of Protective Relay Applications and Settings Officer of organization must certify TP has set relays and provided information to appropriate parties. Certification of Remedial Action Schemes (RAS) Officer must certify that RAS meets all WECC criteria and provided to appropriate entities.

Protective Relay and Remedial Action Scheme Misoperation If misoperation, certain steps must be taken to correct. Amendment 4 Operator Certification System operator positions must be manned by NERC-Certified System Operators. Qualified Path Unscheduled Flow Relief Participants must provide requested relief for Unscheduled Flow relief requests. Amendment 5 refines certain terms and requirements in this item. Transmission Maintenance Standard Transmission Path Operators must develop and implement a Transmission Maintenance and Inspection Plan (TMIP). Interchange Schedule Tagging 1. Submission of Tags by Load Serving Purchasing-Selling Entity a. Failure of the Load Control Area (Tag Authority) to deny a transaction for which the LSE failed to submit a tag in the prescribed timeframe/manner. 2. Load Control Area (LCA) (Tag Authority) a. LCA tagging system must be available according to NERC standards. b. LCA sets composite status to IMPLEMENT when it was been denied by a Tag Approval Entity. c. LCA set composite status to DEAD when transaction was approved by all Tag Approval Entities. d. LCA fails to implement and approved transaction. e. LCA implemented a transaction without a tag when tag is required. 3. Intermediate Control Area, Generation Control Area, Transmission Provider, or Transmission Operator (Tag Approval Entity (TAE)) a. The TAE approval service does not maintain 99.5% availability. b. The entity must actively approve at least 75% of the tags received in the month. Automatic Voltage Regulators AVR s on synchronous generators must be kept in service. Power System Stabilizers PSS on generators must be kept in service. Amendment 6 Amendment 6 removes enforceability on requirement covered by an ERO (NERC/FERC) Reliability Standard. Operator Certification Requirement expands certification requirements from that in Amendment 4.


				
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