Presentation on theme: "The Western Electricity Coordinating Council Doug Tucker of WECC & Brian Keel of SRP November 16, 2010 2010 TRD/TADS Webinar."— Presentation transcript:
The Western Electricity Coordinating Council Doug Tucker of WECC & Brian Keel of SRP November 16, TRD/TADS Webinar
WECC TRD and NERC TADS –General Overview – Brian Keel, SRP –Common Tower versus Common Corridor - Brian Keel –Phase 1 – Doug Tucker, WECC –Phase 2 – Doug Tucker –Data Correlation to PRC – Doug Tucker –Review previous submitted Qs of 2010 – Doug Tucker –Joint Ownership – Doug Tucker –Conclusion – Doug Tucker
WECC Transmission Reliability Database Started as sub group of the Reliability Subcommittee Spring 2004 WECC PCC - OC 2005, re-tool for attributes Formed TRDTF Fall 2005 WECC PCC, OC and Board approved Fall of 2006 Purposes of TRD: WECC PCC Goal WECC PCC and OC presentations over 2005 Completed with added physical attributes 3
WECC Transmission Reliability Database Purpose of the TRD Development –Transmission Outage Database PCUR, used with Performance Category Upgrade Requests Primary Use - RPEWG – monitor, evaluate and report performance to WECC, core charge of RPEWG WECC transmission line performance and tracking Facilitate probabilistic planning Provide common format for data collection, i.e., all of Western adopted for their use 4
Purpose of the TRD In a 1996 WSCC survey, 90%, criteria expanded to be more probabilistic based. PBRC Phase I development and implementation of event probabilities into Performance Table. Table S-1 Ultimate goal is to produce a more economically efficient system without sacrificing system reliability. 5
WECC TRD WECC TRD Sheets –Transmission Circuit Attribute Table Same as last year; Miles, Type, Voltage, Conductors per Phase, Overhead Ground Wires, Insulation Type, Cable Type, Structure Materials, Structure Types, Circuits per Structure, Terrain Exposure, Elevation Exposure. –Transformer Attribute Table Same as last year; High and Low Side kV, Single or Multi, Rating.
WECC Table W-1 7
WECC TRD RPEWG –Members of the RPEWG (includes WECC Staff as Members of RPEWG) only have access to raw outage data –RPEWG Members listed on the WECC website –Access to data governed by RPIC, Approved Exhibit C –Raw outage performance compared to criteria of WECC Performance Criteria Table W-1
WECC TRD and NERC TADS TADS (TRD) overview –NERC wide data collection –AC circuits >= 200kV –Transformers Low Side >= 200kV –AC/DC Back to Back Converters >= 200kV AC Voltage –DC Circuits >= +/-200kV
WECC TRD and NERC TADS TADS Forms –1.1 Non – Reporting TO Statement –1.2 Reporting TO Statement –2.1 Tie Lines and Jointly Owned AC & DC –2.2 Jointly Owned AC/DC BTB Converters –3.1 AC & DC Circuit Inventory Data –3.2 Transformer Inventory Data –3.3 AC/DC BTB Converter Inverter Data –3.4 Summary Automatic Outage Data –4.1 AC Circuit Detailed Outage Data –4.2 DC Circuit Detailed Outage Data –4.3 Transformer Detailed Outage Data –4.4 AC/DC BTB Converter Detailed Outage Data –5.0 Event Code Data –6.1 AC Circuit Non Automatic Outage Data –6.2 DC Circuit Non Automatic Outage Data –6.3 Transformer Non Automatic Outage Data –6.4 AC/DC BTB Converter Non Automatic Outage Data Indicates WECC Members fill in these NERC TADS Forms Indicates NERC data to be supplied by WECC from TRD Sheets
Transmission Availability Database - TADS TADS Metrics Calculated: –Inventory of AC & DC Equipment –Circuit & Transformer Outage F & D per outage initiation code –Circuit Sustained and Momentary Outage Metrics, Element or Other Initiated 11
TRD and TADS Differences TRD Data Differences: –Focus to Common Corridor Outages (RPEWG) –Physical Attribute Data Inputs –Circuits; Outage Rates per –Conductors per Phase –Number of Ground Wires –Insulator Type –Structure Material –Structure Type –Terrain Exposure –Elevation Range 12
13 Data Submittal & Review
NERC and WECC Databases Conclusion –WECC Specific to design Structure in place and working –NERC Displace EIA General Outage Information –Not design specific First year in 2008
Data Gathering Discussion and results Outages with the same element ID that occur within 1-5 minutes of each other need separate event IDs Joint owners – need to report only the lines you are responsible for according to form 2.1 Correlation to PRC-004 and Disturbance reports How to code Misoperation
WECC Data Handling WECC converts the TRD data into the NERC forms 3.1, 3.2, 3.4, , 5.0, 6.1, 6.2, 6.3, 6.4 Upload the data onto the NERC database WECC takes the additional data and creates the TRD report which will give us an insight on any patterns that will arise 5 th annual TRD report for CY 2010
Joint Owner Form 2.1 NERC has asked the TOs to correlate with each other on who is reporting the information for their jointly owned lines TO A and TO B must be reporting jointly owned lines on Form 2.1 and indicating who is the reporting TO even if TO B owns 1% of the line and TO A owns 99% of the line
Form 2.1 TO-SRP TO-SCE
Correlation to PRC-004 and Disturbance reports You will need to talk to your Operations department in order to get the PRC-004 Mis-operations reports and Disturbance reports Disturbance reports are also on the WECC website under Western Electricity Coordinating Council > Library > WECC Documents > Disturbance Logs and Reports > Disturbance Reports - Preliminary (Must be logged into the website in order to see the documents)Western Electricity Coordinating CouncilLibraryWECC DocumentsDisturbance Logs and Reports Disturbance Reports - Preliminary To get an account for the website you will need to go to the website and request an account. The request form is in the top right corner next to the sign in button
Misoperation Cause Codes NERC Glossary of Terms (updated 4/20/2010) defines Misoperation as; –Any failure of a Protection System element to operate within the specified time when a fault or abnormal condition occurs within a zone of protection. –Any operation for a fault not within a zone of protection (other than operation as backup protection for a fault in an adjacent zone that is not cleared within a specified time for the protection for that zone). –Any unintentional Protection System operation when no fault or other abnormal condition has occurred unrelated to on-site maintenance and testing activity. For each sample Misoperation Cause below, based on the current TADS Cause Code definitions, the following Cause Codes should be used on Form 4.x ;
Mapping of Misoperation
Definitions ( Phase II – 2010 FORM 6.x) Outage Type for Non-Automatic Outage Operational Outage (Form 6.x) A Non-Automatic Outage for the purpose of avoiding an emergency (i.e., risk to human life, damage to equipment, damage to property) OR to maintain the system within operational limits AND an outage that cannot be deferred. Planned Outage (Form 6.x) A Non-Automatic Outage with advance notice for the purpose of maintenance, construction, inspection, testing, or planned activities by third parties that may be deferred [Sustained Outage].
Definitions ( Phase II - Form 6.x continued) Planned Outage (continued) Additional Switching Outage – 30 minute exclusion An Outage of a TADS Element of 30 minutes or less duration resulting from switching steps or sequences that are performed in preparation for, or restoration of, the Planned Outage are NOT reportable. Appendix 10 Planned Outages and the 30-Minute Exclusion Examples The Planned Outage actual duration is reported in HHHH:MM even if it is 1-30 minutes in duration. Other element outages resulting from associated switching steps or outage sequences, are NOT reported unless their duration exceeds 30 minutes.
Definitions ( Phase II - Form 6.x continued) Cause Code for Non-Automatic Outage Planned Outage Cause Codes (3) Maintenance and Construction Planned Outage requests from any entity that is defined in the NERC Functional Model. Third Party Request Planned Outage requests from highway depart., Coast Guard, etc. Other Planned Outage Planned Outages for reasons not included in the above list, including human scheduling error. Operational Outage Cause Codes (4) Emergency Operational Outages that are taken for the purpose of avoiding risk to human life, damage to equipment, damage to property, or similar threatening consequences.
Definitions ( Phase II - Form 6.x continued) Operational Outage Cause Codes (continued) System Voltage Limit Mitigation Operational Outages taken to maintain voltage on the transmission system within desired levels (i.e., voltage control). System Operating Limit Mitigation, except voltage Operational Outages taken to keep the transmission system within System Operating Limits, except for System Voltage Limit Mitigation. The term System Operating Limit is defined in the NERC Glossary of Terms Used in Reliability Standards (see text box in TADS Appendix 7) Other Operational Outage Outages for reasons not included in the above list, including emergency decision human judgment errors. Does NOT include manual switching Human Error. These have no advance notice. Code these outages as Automatic Outages.
Responsibilities for Each TO TOs are responsible for data quality. Each Regional Entity Coordinator (REC) or Designated Regional Entity Coordinator (DRE) is available to assist TOs (Doug Tucker; –Form 1.1 & 1.2 contact updates & checklist of Forms –Form 2.x Multi-Owner reporting coordination –single TO is responsible for TADS reporting of outages AND inventory. –Coordinate common Event ID code for TADS Events affecting more than one TO. Enter a TADS NERC Company Event ID code. –Coordinate evaluation of AC Circuit outages on common structures when the circuits are owned by different TOs. –Prior to March 1 st, TOs should reconcile their TADS reported outages with outages to be reported in PRC and EOP required reports. –Prior to March 1 st, TOs should review their TO webTADS Reports for outage & inventory data consistency & completeness. * TADS Training Part A v5.ppt