1. Phil O’Donnell, Manager Operations and Planning Audits
Other TP Obligations
Phil O’Donnell, Manager Operations and Planning Audits

2. Introduction This presentation does not include TPL-001!
Each Registered TP is responsible for demonstrating compliance with Requirements applicable to that function.
That TP or another entity may perform the tasks.

3. Introduction
Compliance Responsibility can only be transferred to another entity registered as a TP.
There must be a formal agreement by both parties to transfer/accept compliance responsibility

4. The Most Important Concept!
Good Coordination between TPs and the PC such that there are no reliability gaps in the implementation of the standards!

5. The Purpose and Requirement's in this presentation are paraphrased to emphasize responsibilities and tasks.
Do not consider them complete

6. FAC-002-2 Facility Interconnection Studies
Purpose: To study the impact of interconnecting new or materially modified Facilities on the BES.
R1. Each TP and each PC shall study the reliability impact of: (i) interconnecting new generation, transmission, or electricity end-user Facilities and (ii) materially modifying existing interconnections of generation, transmission, or electricity end-user Facilities.
Conditional: Based on planned interconnections or modifications
Trigger: When TO or GO wishes to interconnect or modify facilities (FAC R3 & R4)
One party can perform a single study as long as the results satisfy the needs of the PC study and the TP studies.

7. FAC-014-2 Establish and Communicate System Operating Limits
Purpose: To ensure that System Operating Limits (SOLs) used in the reliable planning and operation of the Bulk Electric System (BES) are determined based on an established methodology or methodologies.
R4. The TP shall establish SOLs, including IROLs, for its Transmission Planning Area that are consistent with its PA’s SOL Methodology.
R5.4. The TP shall provide its SOLs (including the subset of SOLs that are IROLs) to its PA, RC, TOPs, and TSPs that work within its Transmission Planning Area and to adjacent TPs.
Note that R3 requires the PA to determine SOLs for its area. TP and PA must coordinate to ensure no gaps exist.

8. IRO-017-1 Outage Coordination
Purpose: To ensure that outages are properly coordinated in the Operations Planning time horizon and Near-Term Transmission Planning Horizon.
R3. Each PC and TP shall provide its Planning Assessment to impacted RC’s.
R4. Each PC and TP shall jointly develop solutions with its respective RC for identified issues or conflicts with planned outages in its Planning Assessment for the Near-Term Transmission Planning Horizon.

9. MOD-004-1 Capacity Benefit Margin
Purpose: To promote the consistent and reliable calculation, verification, preservation, and use of Capacity Benefit Margin (CBM) to support analysis and system operations.
Not Applicable if your TSP does not use CBM in its tariff. (we rarely see use of CBM)
CBM can be requested by a Resource Planner of Load Serving Entity.

10. MOD-020-0 Providing Interruptible Demands and DCLM Data
Purpose: Collection of data To ensure that assessments and validation of past events and databases can be performed and future system assessments can be performed to assist in proper real-time operations.
R1. The TP, and RP shall each make known its amount of interruptible demands and Direct Control Load Management (DCLM) to TOPs, BAs, and RCs on request within 30 calendar days.
Conditional: depends on a request from TOP, BA or RC

11. MOD Verification of Models and Data for Generator Excitation Control System or Plant Volt/Var Control Functions
Purpose: To verify that the generator excitation control system or plant volt/var control function model and the model parameters used in dynamic simulations accurately represent the generator excitation control system or plant volt/var control function behavior.
R1. Each TP shall provide requested information to the GO within 90 calendar days of receiving a written request
R6. Each TP shall provide a written response to the GO within 90 calendar days of receiving the model information that the model is usable or is not usable.
Who is doing the modeling? No PC here!
R2 compels the GO to provide data but must provide data compatable with TP Model (also PC and WECC models) so they “should” request what is needed.

12. MOD Verification of Models and Data for Turbine/Governor and Load Control or Active Power/Frequency Control Functions
Purpose: To verify that the turbine/governor and load control or active power/frequency control model and the model parameters, used in dynamic simulations accurately represent generator unit real power response to system frequency variations.
R1. Each TP shall provide information to the GO within 90 calendar days of receiving a written request:
R5. Each TP shall provide a written response to the GO within 90 calendar days of receiving verified R2 model information that the model is usable or is not usable.
Similar to MOD-026 but for real power

13. MOD-031-2 Demand and Energy Data
Purpose: To provide authority for applicable entities to collect Demand, energy and related data to support reliability studies and assessments and to enumerate the responsibilities and obligations of requestors and respondents of that data.
R2. Each TP identified in a data request shall provide the data requested by its PC or BA in accordance with the data request.
R4. Any TP shall, in response to a written request for the data from a PC, BA, TP or RP with a demonstrated need for such data, provide or otherwise make available that data to the requesting entity.
If you get a request you must comply for your PC and BA and “should” comply for others but some leeway allowed if external entities request data.

14. MOD-032-1 Data for Power System Modeling and Analysis
Purpose: To establish consistent modeling data requirements and reporting procedures for development of planning horizon cases necessary to support analysis of the reliability of the interconnected transmission system.
R1. Each PC and each of its TPs shall jointly develop steady-state, dynamics, and short circuit modeling data requirements and reporting procedures for the PC’s planning area...
Need to coordinate with WECC for model needs

15. NUC-001-3 Nuclear Plant Interface Coordination
Purpose: Ensure coordination between Nuclear Plant Generator Operators and Transmission Entities for the purpose of ensuring nuclear plant safe operation and shutdown.

16. NUC-001-3 Nuclear Plant Interface Coordination

17. PRC-010-2 Under Voltage Load Shedding
Purpose: To establish an integrated and coordinated approach to the design, evaluation, and reliable operation of Undervoltage Load Shedding (UVLS)Programs. R1. Each PC or TP that is developing a UVLS Program shall evaluate its effectiveness and subsequently provide the UVLS Program’s specifications and implementation schedule to the UVLS entities responsible for implementing the UVLS Program.

18. PRC-010-2 Under Voltage Load Shedding
R3. Each PC or TP shall perform an effectiveness assessment of its UVLS Programs each 60 months.
R4. Each PC or TP shall, perform an assessment within 12 months of a UVLS Event
R5. Each PC or TP that identifies deficiencies during R3 or R4 shall develop and distribute a Corrective Action Plan and Implementation schedule.
Conditional: If only if you as a TP have a UVLS Program in your area.

19. TPL-007-1 Transmission System Planned Performance for Geomagnetic Disturbance Events
Purpose: Establish requirements for Transmission system planned performance during geomagnetic disturbance (GMD) events.
R1. Each PC, in conjunction with its TP(s), shall identify the individual and joint responsibilities of the PC and TP in the PC’s planning area for maintaining models and performing the study or studies needed to complete GMD Vulnerability Assessment(s).
R2. Each TP if identified in R1, shall maintain System models and GIC System models of the responsible entity’s planning area for performing the study or studies needed to complete GMD Vulnerability Assessment(s).
Only R1 Effective now but R2 becomes effective 7/1/18

20. TPL-007-1 Transmission System Planned Performance for Geomagnetic Disturbance Events
R3 Each TP if identified in R1, shall have criteria for acceptable System steady state voltage performance for its System during the benchmark GMD event described in Attachment 1.
R4 Each TP if identified in R1, shall complete a GMD Vulnerability Assessment of the Near-Term Transmission Planning Horizon once every 60 calendar months.
R7. Each TP if identified in R1, that concludes, that their System does not meet the performance requirements of Table 1 shall develop a Corrective Action Plan addressing how the performance requirements will be met.
These requirements are not effective until 1/1/22 Additional Requirements coming for version 2

21. Questions and Contacts
Phil O’Donnell
Manager, Operations and Planning Audits
Ruben Arredondo
Senior Legal Counsel