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2007 NERC Standards and Changes

Kevin Goolsby Engineer III, Compliance. 2007 NERC Standards and Changes . 2007 NERC Standards and Changes. Objectives . Explain the standards format List how many standards apply to each function Cover the monitored NERC standards Changes in the standards Highlights of the standards.

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2007 NERC Standards and Changes

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  1. Kevin Goolsby Engineer III, Compliance 2007 NERC Standards and Changes

  2. 2007 NERC Standards and Changes

  3. Objectives • Explain the standards format • List how many standards apply to each function • Cover the monitored NERC standards • Changes in the standards • Highlights of the standards

  4. NERC Standard • Title - General description • Number • Purpose – What the standard is to address • Applicability – What functions does it apply to • Effective Date – When does it become active • Requirements – What to do • Measurements – How to measure compliance • Compliance – Levels of Non-Compliance • Regional Differences – Any approved variances from standard

  5. What Standards are Monitored in 2007? • NERC picks the standards that are to be monitored and reported for each year • 2007 – 47 standards will be monitored • 6 – standards only apply to Reliability Coordinators • Standards will be monitored using: • Self-certification • Field Reviews • Quarterly surveys • Spot checks • Investigations • Self reporting

  6. How many standards apply to my company?

  7. Resource and Demand Balancing (BAL) • BAL-001-0 Real Power Balancing Control Performance (CPS1 & 2) • BAL-002-0 Disturbance Control Performance (DCS) • Automatic Reserve Sharing Group • Warning letters are currently sent for non-performance for an event • BAL-003-0 Frequency Response and Bias • Frequency bias calculation for ACE

  8. Critical Infrastructure Protection (CIP) • 9 CIP standards • Survey will be sent July 1 to self-certify progress with the standards • CIP-001-1 Sabotage Reporting • CIP-002-1 Critical Cyber Asset Identification • Key CIP standard for 2007 • Must have a documented process for selecting Critical Assets • Physical • Cyber • CIP-003 thru -009 depend on the outcome of -002

  9. Communications (COM) • COM-001-1 Telecommunications • Requirements are the same • General - communication paths with BA/TOP/RC • NERC completed the standard by adding measures, compliance, data retention, non-compliance • Became effective January 2007

  10. Emergency Preparedness and Operations • EOP-001-0 Emergency Operations Planning Highlights • applies to BA/TOP • Operating agreements with adjacent BA/TOP • Load reduction plans for identified IROLs on system • SPP performs the study to identify IROLs in SPP’s footprint • Documented plans for: • Loss of Generation • Loss of Transmission • Load shedding • System restoration

  11. Emergency Preparedness and Operations • EOP-001-0 Emergency Operations Planning Highlights (continued) • Plans shall include: • Communication protocols • List of controlling actions – Load reduction included • Tasks for coordination with adjacent BA/TOP • Staffing levels required for emergencies • ***Annually review and update plans • Attachment 1 with 15 items • These items have to be addressed in the plans • Create a place holder for those items that are not applicable to your company

  12. Emergency Preparedness and Operations • EOP-003-1 Load shedding Plans • R2 & R8 currently have non compliance levels • R2 - Must have plans for Under Frequency and Under Voltage conditions • Can state UVLS is not necessary for your system but it must be backed by proof • R8 – Must have a manual load shed plan for operator-controlled manual load shedding to respond to real-time emergencies • If your company does not control load, you need to document this fact in your load shedding plan

  13. Emergency Preparedness and Operations • EOP-005-1 System Restoration Plans • Becomes effective May 2007 • Requirements were rearranged and new ones added • Changes: • TOP verify the number and size of Blackstart units needed to meet the Regional Blackstart plan. • Confirmation Letter being sent to members in the SPP Blackstart plan • Document cranking path of blackstart restoration plan • Simulation or Test of blackstart plan every 5 years • Must address the 9 items in attachment 1 • If an item is not applicable, just document that in the plan

  14. Emergency Preparedness and Operations • EOP-008-0Plans for Loss of Control Center Functionality 8 items • The contingency plan shall not rely on data or voice communicationfrom the primary control facility to be viable. • The plan shall include procedures and responsibilities for providing basic tie line control and procedures and for maintaining the status of all inter-area schedules, such that there is an hourly accounting of all schedules. • The contingency plan must address monitoring and control of critical transmission facilities, generation control, voltage control, time and frequency control, control of critical substation devices, and logging of significant power system events. The plan shall list the critical facilities.

  15. Emergency Preparedness and Operations • EOP-008-0 continued 4. The plan shall include procedures and responsibilities for maintaining basic voice communication capabilities with other areas. 5. The plan shall include procedures and responsibilities for conducting periodic tests, at least annually, to ensure viability of the plan. 6. The plan shall include procedures and responsibilities for providing annual training to ensure that operating personnel are able to implement the contingency plans. 7. The plan shall be reviewed and updated annually. 8. Interim provisions must be included if it is expected to take more than onehour to implement the contingency plan for loss of primary control facility.

  16. Emergency Preparedness and Operations • EOP-009-0 Documentation of Blackstart Generation Unit Test Results • For GO / GOP • Test data for identified Blackstart Units • References EOP-007 minimum of 1/3 blackstart units per year • If you own 1 – every year • If you own 2 – every other year

  17. Facilities Design, Connections and Maintenance • FAC-003-1 Vegetation Management Program • Applies to Transmission Owners • 200kV and greater transmission lines • Any lower voltage line on SPP’s Critical Facility list • Standard was completely updated • Requires a transmission vegetation management plan • Requires an implementation plan to cover lines with preferred method identified • All Critical Facility [operated at 100kv+] contacts are to be reported to SPP during the quarterly survey • Reporting form is included with survey

  18. Facilities Design, Connections and Maintenance • FAC-008-1 Facility Ratings Methodology • GO / TO must document facility rating method • SPP members generally use the SPP Criteria 12 • But list any variances from the criteria • Wind speed • Other special factors on the system

  19. Facilities Design, Connections and Maintenance • FAC-009-1 Establish and Communicate Facility Ratings • Verify that the facility rating method is followed • Ratings are sent to others who need the data • Reliability Coordinator • Balancing Authority • Planning Authority • Transmission Planner • Transmission Operator • This includes sending in model updates to regions • Operational changes • Planning changes

  20. Personnel Performance, Training, and Qualifications • PER-002-0 Operating Personnel Training • Each Transmission Operator and Balancing Authority shall be staffed with adequately trained operating personnel. • Each Transmission Operator and Balancing Authority shall have a training program for all operating personnel that are in: • Positions that have the primary responsibility, either directly or through communications with others, for the real-time operation of the interconnected Bulk Electric System. • Positions directly responsible for complying with NERC standards.

  21. Personnel Performance, Training, and Qualifications • PER-002-0 Operating Personnel Training continued • Training program meeting the following criteria: • A set of training program objectives must be defined, based on NERC and Regional Reliability Organization standards, entity operating procedures, and applicable regulatory requirements. Requirements to normal, emergency, and restoration conditions. • Initial and continuing training. That plan shall address knowledge and competencies required for reliable system operations. • Training time • Training staff must be identified • At least five days per year of training and drills using realistic simulations of system emergencies, in addition to other training (32hrs)

  22. Personnel Performance, Training, and Qualifications • PER-003-0 Operating Personnel Credentials • Each Transmission Operator, Balancing Authority, and Reliability Coordinator shall staff all operating positions that meet both of the following criteria with personnel that are NERC-certified for the applicable functions: • Positions that have the primary responsibility, either directly or through communications with others, for the real-time operation of the interconnected Bulk Electric System. • Positions directly responsible for complying with NERC standards.

  23. Protection and Control • PRC-004-1 Analysis and Mitigation of Trans. & Gen. Protection System Misoperations • Transmission owners shall have a process for analyzing misoperations of protection system and create plan to correct and prevent further misoperations • Generation owners shall have a process for analyzing misoperations of protection system and create plan to correct and prevent further misoperations • Must report misoperations to the region • SPP uses the quarterly survey • We will add generators this year

  24. Protection and Control • PRC-005-1 Trans. & Gen. Protection System Maintence and Testing • Maintence and Testing Program must contain: • Documentation of Maintenance and testing intervals and their basis. • Summary of maintenance and testing procedures. • Schedule for system testing. • Schedule for system maintenance. • Date last tested/maintained. • Records: • Evidence Protection System devices were maintained and tested within the defined intervals. • Date each Protection System device was last tested/maintained.

  25. Protection and Control • PRC-008-0 Implementation and Documentation of UFLS Maintenance Program • Same as PRC-005-1 • Most companies have the UFLS included in their regular maintenance program • Note: being behind on UFLS relays can be a double violation (PRC-005 & PRC-008)

  26. Protection and Control • PRC-010-0 Technical Assessment of Design and Effectiveness of UVLS Program • The Load-Serving Entity, Transmission Owner, Transmission Operator, and Distribution Provider that owns or operates a UVLS program shall periodically (at least every five years or as required by changes in system conditions) conduct and document an assessment of the effectiveness of the UVLS program. This assessment shall be conducted with the associated Transmission Planner(s) and Planning Authority(ies). • This assessment shall include, but is not limited to: • Coordination of the UVLS programs with other protection and control systems in the Region and with other Regional Reliability Organizations, as appropriate. • Simulations that demonstrate that the UVLS programs performance is consistent with Reliability Standards TPL-001-0, TPL-002-0, TPL-003-0 and TPL-004-0. • A review of the voltage set points and timing. • The Load-Serving Entity, Transmission Owner, Transmission Operator, and Distribution Provider that owns or operates a UVLS program shall provide documentation of its current UVLS program assessment to its Regional Reliability Organization and NERC on request (30 calendar days).

  27. Protection and Control • PRC-011-0 UVLS System Maintenance and Testing • The Transmission Owner and Distribution Provider that owns a UVLS system shall have a UVLS equipment maintenance and testing program: • Relays. • Instrument transformers. • Communications systems, where appropriate. • Batteries. • Documentation of maintenance and testing intervals and their basis. • Summary of testing procedure. • Schedule for system testing. • Schedule for system maintenance. • Date last tested/maintained. • Owners of a UVLS system shall provide documentation of its UVLS equipment maintenance and testing program and the implementation of that UVLS equipment maintenance and testing program upon request

  28. Protection and Control • PRC-016-0 Special Protection System Misoperations • The Transmission Owner, Generator Owner, and Distribution Provider that owns an SPS shall analyze its SPS operations and maintain a record of all misoperations • The Transmission Owner, Generator Owner, and Distribution Provider that owns an SPS shall take corrective actions to avoid future misoperations. • The Transmission Owner, Generator Owner, and Distribution Provider that owns an SPS shall provide documentation of the misoperation analyses and the corrective action plans to its Regional Reliability Organization and NERC on request

  29. Protection and Control • PRC-0017 SPS Maintenance and Testing • The Transmission Owner and Distribution Provider that owns a SPS system shall have a SPS equipment maintenance and testing program: • Relays. • Instrument transformers. • Communications systems, where appropriate. • Batteries. • Documentation of maintenance and testing intervals and their basis. • Summary of testing procedure. • Schedule for system testing. • Schedule for system maintenance. • Date last tested/maintained. • Owners of a SPS system shall provide documentation of its SPS equipment maintenance and testing program and the implementation of that SPS equipment maintenance and testing program upon request

  30. Protection and Control • PRC-021-1 UVLS Program Data • Each Transmission Owner and Distribution Provider that owns a UVLS program to mitigate the risk of voltage collapse or voltage instability in the BES shall annually update its UVLS data to support the Regional UVLS program database: • Size and location of customer load, or percent of connected load, to be interrupted. • Corresponding voltage set points and overall scheme clearing times. • Time delay from initiation to trip signal. • Breaker operating times. • Any other schemes that are part of or impact the UVLS programs such as related generation protection, islanding schemes, automatic load restoration schemes, UFLS and Special Protection Systems. • Shall provide data upon request

  31. Transmission Operations • TOP-003-0 Planned Outage Coordination • Shall supply planned outage information to TOP • TOP shall supply outages to RC • Shall coordinate outages of voltage regulating equipment. • Shall coordinate outages of telemetering and control equipment and associated communication channels between the affected areas. • RC are to solve any coordination issues

  32. Transmission Operations • TOP-004-1 Transmission Operations • Effective October 2007 • TOP-004-0 Transmission Operations • Each Transmission Operator shall operate within the Interconnection Reliability Operating Limits (IROLs) and System Operating Limits (SOLs) • If a Transmission Operator enters an unknown operating state (i.e. any state for which valid operating limits have not been determined), it will be considered to be in an emergency and shall restore operations to respect proven reliable power system limits within 30 minutes. • Each Transmission Operator shall make every effort to remain connected to the Interconnection. • Transmission Operators, individually and jointly with other Transmission Operators, shall develop, maintain, and implement formal policies and procedures to provide for transmission reliability. • Equipment ratings. • Monitoring and controlling voltage levels and real and reactive power flows. • Switching transmission elements. • Planned outages of transmission elements. • Development of IROLs and SOLs. • Responding to IROL and SOL violations.

  33. Transmission Operations • TOP-005-1 Operational Reliability Information • Supply data requested by Reliability Coordinator • SPP Criteria Appendix 7 list the required data

  34. Transmission Operations • TOP-007-0 Reporting System Operating Limit (SOL) and Interconnection Reliability • A Transmission Operator shall inform its Reliability Coordinator when an IROL or SOL has been exceeded and the actions being taken to return the system to within limits. • Following a Contingency or other event that results in an IROL violation, the Transmission Operator shall return its transmission system to within IROL as soon as possible, but not longer than 30 minutes. • A Transmission Operator shall take all appropriate actions up to and including shedding firm load, or directing the shedding of firm load, in order to comply with Requirement R2. • The Reliability Coordinator shall evaluate actions taken to address an IROL or SOL violation and, if the actions taken are not appropriate or sufficient, direct actions required to return the system to within limits.

  35. Transmission Planning • TPL-001-0 System Performance Under Normal Conditions • TPL-002-0 System Performance Following Loss of Single BES Element • TPL-003-0 System Performance Following Loss of Two or More BES Elements • TPL-004-0 System Performance Following Extreme BES Events • Must perform studies to satisfy Table 1 • Performed annually • Short term 1-5 years, Long term 6 + years

  36. Voltage and Reactive • VAR-001-1 Voltage and Reactive Control • Each Transmission Operator, individually and jointly with other Transmission Operators, shall ensure that formal policies and procedures are developed, maintained, and implemented for monitoring and controlling voltage levels and Mvar flows within their individual areas and with the areas of neighboring Transmission Operators. • Each Transmission Operator shall acquire sufficient reactive resources within its area to protect the voltage levels under normal and Contingency conditions. • The Transmission Operator shall specify criteria that exempts generators from compliance with the requirements • Each Transmission Operator shall maintain a list of generators in its area that are exempt from following a voltage or Reactive Power schedule. • For each generator that is on this exemption list, the Transmission Operator shall notify the associated Generator Owner.

  37. Voltage and Reactive • VAR-001-1 Voltage and Reactive Control (cont.) • Each Transmission Operator shall specify a voltage or Reactive Power schedule at the interconnection between the generator facility and the Transmission Owner's facilities to be maintained by each generator. • The Transmission Operator shall know the status of all transmission Reactive Power resources, including the status of voltage regulators and power system stabilizers. • When notified of the loss of an automatic voltage regulator control, the Transmission Operator shall direct the Generator Operator to maintain or change either its voltage schedule or its Reactive Power schedule.

  38. Voltage and Reactive • VAR-001-1 Voltage and Reactive Control (cont.) • The Transmission Operator shall be able to operate or direct the operation of devices necessary to regulate transmission voltage and reactive flow. • Each Transmission Operator shall operate or direct the operation of capacitive and inductive reactive resources within its area – including reactive generation scheduling; transmission line and reactive resource switching; and, if necessary, load shedding – to maintain system and Interconnection voltages within established limits.

  39. Voltage and Reactive • VAR-001-1 Voltage and Reactive Control (cont.) • Each Transmission Operator shall maintain reactive resources to support its voltage under first Contingency conditions. • Each Transmission Operator shall disperse and locate the reactive resources so that the resources can be applied effectively and quickly when Contingencies occur. • Each Transmission Operator shall correct IROL or SOL violations resulting from reactive resource deficiencies (IROL violations must be corrected within 30 minutes) and complete the required IROL or SOL violation reporting. • After consultation with the Generator Owner regarding necessary step-up transformer tap changes, the Transmission Operator shall provide documentation to the Generator Owner specifying the required tap changes, a timeframe for making the changes, and technical justification for these changes. • The Transmission Operator shall direct corrective action, including load reduction, necessary to prevent voltage collapse when reactive resources are insufficient.

  40. Kevin Goolsby Engineer III, Compliance501-614-3275questions@spp.org

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