Current Path Operations New Paradigm without Path SOL Future Standards that apply

Transcription

1 Runs transfer analysis studies ahead of time to determine the Path SOL. Runs transfer analysis studies ahead of time to determine the Path TTC and to determine the existence of stability limits. MOD (TOP) Pending R1. Each Transmission Operator that determines Total Flowgate Capability (TFC) or Total Transfer Capability (TTC) shall develop a written methodology (or methodologies) for determining TFC or TTC values. The methodology (or methodologies) shall reflect the Transmission Operator s current practices for determining TFC or TTC values. [Violation Risk Factor: Lower] [Time Horizon: Operations Planning] 1.1 Each methodology shall describe the method used to account for the following limitations in both the pre and post contingency state: Facility ratings; System voltage limits; Transient stability limits; Voltage stability limits; and Other System Operating Limits (SOLs). M1. Each Transmission Operator that determines TFC or TTC shall provide its current written methodology (or methodologies) or other evidence to show that its methodology contains the following: a description of the method used to account for the limits specified in part 1.1. Methods of accounting for these limits may include, but are not limited to, one or more of the following:

2 o monitoring a subset of limits; and o a statement that those limits are expected to produce the most severe results. TOP Effective 04/2017 R1. Each Transmission Operator shall have an Operational Planning Analysis that will allow it to assess whether its planned operations for the next day within its Transmission Operator Area will exceed any of its System Operating Limits (SOLs). R2. Each Transmission Operator shall have an Operating Plan(s) for next-day operations to address potential System Operating Limit (SOL) exceedances identified as a result of its Operational Planning Analysis as required in Requirement R1. Identifies the Path SOL and allocates the Path TTC among TOPs that operate Facilities on the WECC Path. Allocates the Path TTC among TOPs that have TTC Facilities on the WECC Path. MOD (TSP) Pending R2. Each Transmission Service Provider that determines Available Flowgate Capability (AFC) or Available Transfer Capability (ATC) shall develop an Available Transfer Capability Implementation Document (ATCID) that describes the methodology (or methodologies) for determining AFC or ATC values. The methodology (or

3 methodologies) shall reflect the Transmission Service Provider s current practices for determining AFC or ATC values. [Violation Risk Factor: Lower] [Time Horizon: Operations Planning] 2.1. Each methodology shall describe the method used to account for the following elements, provided such elements impact the determination of AFC or ATC: The simulation of transfers performed through the adjustment of generation, Load, or both; Transmission topology, including, but not limited to, additions and retirements; Expected transmission uses; Planned outages; Parallel path (loop flow) adjustments; Load forecast; and Generator dispatch, including, but not limited to, additions and retirements. TOP Effective 04/2017 R1. Each Transmission Operator shall have an Operational Planning Analysis that will allow it to assess whether its planned operations for the next day within its Transmission Operator Area will exceed any of its System Operating Limits (SOLs). R2. Each Transmission Operator shall have an

4 Operating Plan(s) for next-day operations to address potential System Operating Limit (SOL) exceedances identified as a result of its Operational Planning Analysis as required in Requirement R1. R3. Each Transmission Operator shall notify entities identified in the Operating Plan(s) cited in Requirement R2 as to their role in those plan(s). Monitors path flows to ensure they stay below the Path SOL. TOPs monitor Facility Ratings, voltage limits, and stability limits in the pre- and post-contingency state. TOPs ensure acceptable system performance as per the RC SOL Methodology. FAC-011 & FAC -014; Peak RC SOL Methodology (RC, TOP) TOP standards Effective 04/2017 TOP R1. Each Transmission Operator shall have an Operational Planning Analysis that will allow it to assess whether its planned operations for the next day within its Transmission Operator Area will exceed any of its System Operating Limits (SOLs). R2. Each Transmission Operator shall have an Operating Plan(s) for next-day operations to address potential System Operating Limit (SOL) exceedances identified as a result of its Operational Planning Analysis as required in Requirement R1.

5 R3. Each Transmission Operator shall notify entities identified in the Operating Plan(s) cited in Requirement R2 as to their role in those plan(s). TOP R1. Each Transmission Operator shall act to maintain the reliability of its Transmission Operator Area via its own actions or by issuing Operating Instructions. R2. Each Balancing Authority shall act to maintain the reliability of its Balancing Authority Area via its own actions or by issuing Operating Instructions. R10. Each Transmission Operator shall perform the following as necessary for determining System Operating Limit (SOL) exceedances within its Transmission Operator Area: Within its Transmission Operator Area, monitor Facilities and the status of Special Protection Systems, and Outside its Transmission Operator Area, obtain and utilize status, voltages, and flow data for Facilities and the status of Special Protection Systems. R14. Each Transmission Operator shall initiate its

6 Operating Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment. Rationale for Requirement R14: The original Requirement R8 was deleted and original Requirements R9 and R11 were revised in order to respond to NOPR paragraph 42 which raised the issue of handling all SOLs and not just a sub-set of SOLs. The SDT has developed a white paper on SOL exceedances that explains its intent on what needs to be contained in such an Operating Plan. R18. Each Transmission Operator shall operate to the most limiting parameter in instances where there is a difference in SOLs. Rationale for Requirement R18: Derived limits replaced by SOLs for clarity and specificity. SOLs include voltage, Stability, and thermal limits and are thus the most limiting factor. Makes adjustments to the Path SOL in response to real-time events. Makes adjustments to the Path TTC in response to real-time events. MOD (TOP) Pending R1.2 Each methodology shall describe the method used to account for each of the following elements, provided such elements impact the determination of TFC or TTC:

7 1.2.1 The simulation of transfers performed through the adjustment of generation, Load, or both; Transmission topology, including, but not limited to, additions and retirements; Expected transmission uses; Planned outages; Parallel path (loop flow) adjustments; Load forecast; and Generator dispatch, including, but not limited to, additions and retirements. TOP Effective 04/2017 R11. Each Balancing Authority shall monitor its Balancing Authority Area, including the status of Special Protection Systems that impact generation or Load, in order to maintain generation-load-interchange balance within its Balancing Authority Area and support Interconnection frequency. R13. Each Transmission Operator shall ensure that a Real-time Assessment is performed at least once every 30 minutes.

8 TOP Effective 04/2017 R4. Each Balancing Authority shall have an Operating Plan(s) for the next-day that addresses: 4.1 Expected generation resource commitment and dispatch 4.2 Interchange scheduling 4.3 Demand patterns 4.4 Capacity and energy reserve requirements, including deliverability capability R5. Each Balancing Authority shall notify entities identified in the Operating Plan(s) cited in Requirement R4 as to their role in those plan(s). Is responsible for mitigating Path SOL exceedances. TOPs are expected to mitigate instances of unacceptable system performance by the most appropriate or effective means such as: Internal congestion management tools, and/or Local or wide-area operating plans, procedures, or Op Guides, and/or Interconnection-wide congestion management tools administered by Peak RC. RC IRO Effective 04/2017 R5. Each Reliability Coordinator shall notify impacted Transmission Operators and Balancing Authorities within its Reliability Coordinator Area, and other impacted Reliability Coordinators as indicated in its Operating Plan, when the results of a Real-time Assessment indicate an actual or expected condition that results in, or could result in, a System Operating Limit (SOL) or Interconnection Reliability Operating Limit (IROL) exceedance within its Wide Area

9 IRO-006-WECC-2 Effective 04/2014 R1. Each Reliability Coordinator shall approve or deny a request within five minutes of receiving the request for unscheduled flow transmission relief from the Transmission Operator of a Qualified Transfer Path that will result in the calculation of a Relief Requirement. R2. Each Balancing Authority shall perform any combination of the following actions meeting the Relief Requirement upon receiving a request for relief as described in Requirement R1: Approve curtailment requests to the schedules as submitted Implement alternative actions TOP Effective 04/2017 R10. Each Transmission Operator shall perform the following as necessary for determining System Operating Limit (SOL) exceedances within its Transmission Operator Area: 10.1.Within its Transmission Operator Area, monitor Facilities and the status of Special Protection Systems, and Outside its Transmission Operator Area, obtain and utilize status, voltages, and flow data for Facilities

10 and the status of Special Protection Systems. R13. Each Transmission Operator shall ensure that a Real-time Assessment is performed at least once every 30 minutes. R14. Each Transmission Operator shall initiate its Operating Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment. R15. Each Transmission Operator shall inform its Reliability Coordinator of actions taken to return the System to within limits when a SOL has been exceeded. R18. Each Transmission Operator shall operate to the most limiting parameter in instances where there is a difference in SOLs. Has TOP-007-WECC-1 compliance responsibility when a Path SOL is exceeded for longer than 30 minutes. TOP-007-WECC-1 is retired. Compliance responsibility for SOL or IROL exceedances will be governed by NERC TOP and IRO Standards at the facility and stability limit level. Peak SOL Methodology will NOT accept Path SOLs for Paths that are not Stability Limited Paths.

11 Monitors the Path Scheduling limit as a whole to assure scheduled usage is not exceeding the Path s Scheduling Limit (TTC). TOP-007-WECC-1 is retired therefore there will not be a violation if actual flow exceeds the Schedule Limit (TTC). However, Path Schedule Use shall not exceed either the Path TTC values or the individual TOP s share of TTC. TSP:TSP Functional Model Task. 1. Receive transmission service requests and process each request for service according to the requirements of the tariff. a. Maintain commercial interface for receiving and confirming requests for transmission service according to the requirements of the tariff (e.g., OASIS). 2. Determine and post available transfer capability values. 3. Approve or deny transmission service requests. 4. Approve Arranged Interchange from transmission service arrangement perspective. 5. Allocate transmission losses (MWs or funds) among Balancing Authority Areas. TOP Effective 04/2017 R1. Each Transmission Operator shall have an Operational Planning Analysis that will allow it to assess whether its planned operations for the next day within its Transmission Operator Area will exceed any of its System Operating Limits (SOLs). R2. Each Transmission Operator shall have an Operating Plan(s) for next-day operations to address potential System Operating Limit (SOL) exceedances identified as a result of its Operational Planning

12 Analysis as required in Requirement R1. R4. Each Balancing Authority shall have an Operating Plan(s) for the next-day that addresses 4.1 Expected generation resource commitment and dispatch 4.2 Interchange scheduling 4.3 Demand patterns 4.4 Capacity and energy reserve requirements, including deliverability capability R5. Each Balancing Authority shall notify entities identified in the Operating Plan(s) cited in Requirement R4 as to their role in those plan(s). TOP Effective 04/2017 R2. Each Balancing Authority shall act to maintain the reliability of its Balancing Authority Area via its own actions or by issuing Operating Instructions. TOPs/BAs adjust existing generation (or bring on expensive alternate generation) to get under an SOL that may be ultra-conservative and may not be reflective of actual system TOP and RC monitor for pre- and post- Contingency exceedance of Facility Ratings, buts voltage limits, and actual exceedance of stability limits. Action taken only when actual system conditions indicate a need for action. FAC-011 & FAC -014; Peak RC SOL Methodology RC IRO Effective 04/2017 R5. Each Reliability Coordinator shall notify impacted

13 conditions. Transmission Operators and Balancing Authorities within its Reliability Coordinator Area, and other impacted Reliability Coordinators as indicated in its Operating Plan, when the results of a Realtime Assessment indicate an actual or expected condition that results in, or could result in, a System Operating Limit (SOL) or Interconnection Reliability Operating Limit (IROL) exceedance within its Wide Area TOP Effective 04/2017 R8. Each Transmission Operator shall inform its Reliability Coordinator, known impacted Balancing Authorities, and known impacted Transmission Operators of its actual or expected operations that result in, or could result in, an Emergency. R13. Each Transmission Operator shall ensure that a Real-time Assessment is performed at least once every 30 minutes. R14. Each Transmission Operator shall initiate its Operating Plan to mitigate a SOL exceedance identified as part of its Real-time monitoring or Real-time Assessment. Operational Planning Analysis: An evaluation of projected system conditions to assess anticipated (pre- Contingency) and potential (post-contingency)

14 conditions for next-day operations. The evaluation shall reflect applicable inputs including, but not limited to, load forecasts; generation output levels; Interchange; known Protection System and Special Protection System status or degradation; Transmission outages; generator outages; Facility Ratings; and identified phase angle and equipment limitations. After the Fact Transmission accounting for imbalance (overage) or unauthorized use After the Fact Transmission accounting for imbalance (overage) or unauthorized use Not a reliability standard issue: TSP:TSP Functional Model Task. 1. Receive transmission service requests and process each request for service according to the requirements of the tariff. a. Maintain commercial interface for receiving and confirming requests for transmission service according to the requirements of the tariff (e.g., OASIS). 2. Determine and post available transfer capability values. 3. Approve or deny transmission service requests. 4. Approve Arranged Interchange from transmission service arrangement perspective. 5. Allocate transmission losses (MWs or funds) among Balancing Authority Areas.