Crosswalk for Retirement

TOP-007-WECC-1

Regional Business Practice

This crosswalk is prepared in anticipation of filing a Standard Authorization Request (SAR) to retire TOP-007-WECC-1,

Background

TOP-007-WECC-1 Requirement
R1.When the actual power flow exceeds an SOL for a Transmission path, the Transmission Operators shall take immediate action to reduce the actual power flow across the path such that at no time shall the power flow for the Transmission path exceed the SOL for more than 30 minutes. [Violation Risk Factor: High] [Time Horizon: Real-time Operations] / FAC-014-2
R2. The Transmission Operator shall establish SOLs (as directed by its Reliability Coordinator) forits portion of the Reliability Coordinator Area that are consistent with its ReliabilityCoordinator’s SOL Methodology
R5.2. The Transmission Operator shall provide any SOLs it developed to its ReliabilityCoordinator and to the Transmission Service Providers that share its portion of theReliability Coordinator Area.
Peak RC SOL Methodology version 7.0
  • Item #2, page 6 – “If any of the acceptable pre- or post-contingency system performance criteria stipulated in this Methodology are not being met, an SOL is being exceeded.”
  • Item #3, page 6 – Pre-Contingency : Acceptable system performance for the pre-contingency state in the Operations Horizon is characterized by the following [NERC Standard FAC-011-2 R2.1]:
  1. The BES shall demonstrate transient, dynamic and voltage stability.
  2. All Facilities shall be within their continuous Facility Ratings and thermal limits (Refer to illustration in Appendix II).
  3. All Facilities shall be within their pre-contingency voltage limits.
  4. All Facilities shall be within their stability limits.
  • Item #4, page 7 – Post-Contingency [SCs]: Acceptable system performance for the post-contingency state for Single Contingencies (SC) in the Operations Horizon is characterized by the following (NERC Standard FAC-011-2 R2.2):
  1. The BES shall demonstrate transient, dynamic and voltage stability.
  2. All Facilities shall be within their applicable short-term Facility Ratings and thermal limits. (Refer to illustration in Appendix II).
  3. All Facilities shall be within their post-contingency voltage limits.
  4. All Facilities shall be within their stability limits.
  5. Cascading or uncontrolled separation shall not occur.
  • Item #8, page 8 – Conditions that expose the system to unacceptable BES performance cannot be allowed to continue indefinitely. As such, when the system is experiencing unacceptable pre- or post-contingency performance, the system must be adjusted as soon as practicable to prepare for the next Contingency.
  • Item #9, page 9 – When system studies conducted throughout the Operations Horizon (including Real-time Assessments) indicate that any of the acceptable post-contingency system performance criteria are not being met, the TOP shall take pre-contingency actions to achieve acceptable performance. These actions may include, at a minimum, the following: [NERC Standard FAC-011-2 R2.4]
  1. Commit and redispatch generation.
  2. Make adjustments to the uses of the transmission system (e.g., schedule curtailments/adjustments).
  3. Make changes to system topology.
  • Item #47, page 18 – TOPs and the RC shall identify the subset of SOLs that qualify as IROLs consistent with this SOL Methodology. When a TOP identifies an SOL that qualifies as an IROL, the TOP shall communicate the results of its analysis with impacted TOPs and the Peak RC. The Peak RC shall make the final determination whether the identified SOL shall be declared an actual IROL.
  • Item #48. Page 18 – SOLs qualify as IROLs when impact containment cannot be demonstrated as described in the ‘Impact Containment and IROL Load Impact’ section below or when studies indicate that instability, Cascading, or uncontrolled separation may occur resulting in uncontrolled interruption of load equal to or greater than 1000 MW.
IROL-009-1
R3. When an assessment of actual or expected system conditions predicts that an IROL in its Reliability Coordinator Area will be exceeded, the Reliability Coordinator shall implement one or more Operating Processes, Procedures or Plans (not limited to the Operating Processes, Procedures, or Plans developed for Requirements R1) to prevent exceeding that IROL. (Violation Risk Factor: High) (Time Horizon: Real-time Operations)
R4. When actual system conditions show that there is an instance of exceeding an IROL in its Reliability Coordinator Area, the Reliability Coordinator shall, without delay, act or direct others to act to mitigate the magnitude and duration of the instance of exceeding that IROL within the IROL’s Tv. (Violation Risk Factor: High ) (Time Horizon: Realtime Operations)
PRC-004-WECC-1
R2.3. If the Protection System or RAS has a Security-Based or Dependability-Based
Misoperation and a FEPS and FERAS is not in service to ensure BES reliability,
Transmission Owners or Generator Owners shall repair and place back in service
within 22 hours the Protection System or RAS that misoperated. If this cannot be
done, then Transmission Owners and Generator Owners shall perform the following.
[Violation Risk Factor: High] [Time Horizon: Same-day Operations]
R2.3.1. When a FEPS is not available, the Transmission Owners shall remove the
associated Element from service.
R2.3.2. When FERAS is not available, then
2.3.2.1. The Generator Owners shall adjust generation to a reliable
operating level, or
2.3.2.2. Transmission Operators shall adjust the SOL and operate the
facilities within established limits.
TOP-004-2
R1. Each Transmission Operator shall operate within the Interconnection Reliability OperatingLimits (IROLs) and System Operating Limits (SOLs).
R4. If a Transmission Operator enters an unknown operating state (i.e. any state for which validoperating limits have not been determined), it will be considered to be in an emergency andshall restore operations to respect proven reliable power system limits within 30 minutes.
R5. Each Transmission Operator shall make every effort to remain connected to the Interconnection. If the Transmission Operator determines that by remaining interconnected, it is in imminent danger of violating an IROL or SOL, the Transmission Operator may take such actions, as it deems necessary, to protect its area.
R6. Transmission Operators, individually and jointly with other Transmission Operators, shall develop, maintain, and implement formal policies and procedures to provide fortransmission reliability. These policies and procedures shall address the execution andcoordination of activities that impact inter- and intra-Regional reliability, including:
R6.1. Monitoring and controlling voltage levels and real and reactive power flows.
R6.2. Switching transmission elements.
R6.3. Planned outages of transmission elements.
R6.4. Responding to IROL and SOL violations.
TOP-007-0
R1. A Transmission Operator shall inform its Reliability Coordinator when an IROL or SOL hasbeen exceeded and the actions being taken to return the system to within limits.
R2. Following a Contingency or other event that results in an IROL violation, the TransmissionOperator shall return its transmission system to within IROL as soon as possible, but notlonger than 30 minutes.
R3. A Transmission Operator shall take all appropriate actions up to and including shedding firmload, or directing the shedding of firm load, in order to comply with Requirement R2.
R4. The Reliability Coordinator shall evaluate actions taken to address an IROL or SOL violationand, if the actions taken are not appropriate or sufficient, direct actions required to return thesystem to within limits.
TOP-008-1
R1. The Transmission Operator experiencing or contributing to an IROL or SOL violation shalltake immediate steps to relieve the condition, which may include shedding firm load.
R2. Each Transmission Operator shall operate to prevent the likelihood that a disturbance, action,or inaction will result in an IROL or SOL violation in its area or another area of the
Interconnection. In instances where there is a difference in derived operating limits, the
Transmission Operator shall always operate the Bulk Electric System to the most limiting
Parameter
VAR-001-2
R10.Each Transmission Operator shall correct IROL or SOL violations resulting from reactiveresource deficiencies (IROL violations must be corrected within 30 minutes) and completethe required IROL or SOL violation reporting.
R2. The Transmission Operator shall not have the Net Scheduled Interchange for power flow overan interconnection or Transmission path above the path’s SOL when the TransmissionOperator implements its real-time schedules for the next hour. For paths internal to a
Transmission Operator Area that are not scheduled, this requirement does not apply. [ViolationRisk Factor: Medium] [Time Horizon: Real-time Operations]
R2.1. If the path SOL decreases within 20 minutes before the start of the hour, theTransmission Operator shall adjust the Net Scheduled Interchange within 30 minutesto the new SOL value. Net Scheduled Interchange exceeding the new SOL duringthis 30-minute period will not be a violation of R2. / NERC Reliability Functional Model Version 5 defines the TOP tasks that are in conflict with R2. The Functional Model assigns the Interchange Arrangement to Transmission Service provider.
TOP Functional Model Task.
1. Monitor and provide telemetry (as needed) of all reliability-related parameters
within the reliability area.
2. Monitor the status of, and deploy, facilities classed as transmission assets, which
may include the transmission lines connecting a generating plant to the
transmission system, associated protective relaying systems and Special Protection
Systems.
3. Develop system limitations such as System Operating Limits and Total Transfer
Capabilities, and operate within those limits.
4. Develop and implement emergency procedures.
5. Develop and implement system restoration plans.
6. Operate within established Interconnection Reliability Operating Limits.
7. Perform reliability analysis (actual and contingency) for the Transmission Operator Area.
8. Adjust flow control devices within the transmission area to maintain reliability.
9. Deploy reactive resources to maintain transmission voltage within defined limits.
TSP Functional Model Task.
1. Receive transmission service requests and process each request for serviceaccording to the requirements of the tariff.
a. Maintain commercial interface for receiving and confirming requests fortransmission 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.
INT-006-3
R1.2. Each involved Transmission Service Provider shall confirm that the transmissionservice arrangements associated with the Arranged Interchange have adjacentTransmission Service Provider connectivity, are valid and prevailing transmissionsystem limits will not be violated.
INT-003-3
R1. Each Receiving Balancing Authority shall confirm Interchange Schedules with the SendingBalancing Authority prior to implementation in the Balancing Authority’s ACE equation.(Violation Risk Factor: Medium)
R1.1. The Sending Balancing Authority and Receiving Balancing Authority shall agree onInterchange as received from the Interchange Authority, including: (Violation Risk
Factor: Lower)
R1.1.1. Interchange Schedule start and end time. (Violation Risk Factor: Lower)
R1.1.2. Energy profile
Note
The North American Electric Reliability Corporation (NERC) retained five industry experts, theIndependent Experts Review (IER),to independently reviewthe NERC Reliability Standards, IER recommended retiring INT-006-3, per paragraph 81, project 2008-12. The IER believed theINT-006-3 R1.2 retirement is due to a guideline that exists in the functional specification for electronic tagging.

INT-006-4
The content of INT-006-4 has been revised and expanded in the following manner:
R1 was created by revising R1 from INT-006-3. This requirement ensures thatBalancing Authorities involved in an Arranged Interchange actively approve ordeny the transition to Confirmed Interchange. The requirement also lists criteriato determine when a Balancing Authority must deny the transition.
R2 was created by revising R1 from INT-006-3. This requirement ensures that
Transmission Service Providers involved in an Arranged Interchange activelyapprove or deny the transition to Confirmed Interchange. The requirement alsolists criteria to determine when a Transmission Service Provider must deny thetransition.
R3 was created by revising R1 from INT-006-3. This requirement ensures that
Balancing Authorities who receive a Reliability Adjustment Arranged
Interchange actively approve or deny the transition to Confirmed Interchange

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