1. NERC TPL-001-4 Standard Overview
Attachment K Quarter 3 Stakeholder’s Meeting
September 29, 2016

2. Overview Areas Background New NERC TPL Standard
2016 TPL Plan and Status Update
2015 Planning Assessment Results
Compliance Monitoring and Enforcement

3. Common Acronyms BES – Bulk Electric System
ERO – Electric Reliability Organization
FERC – Federal Energy Regulatory Commission
NERC – North American Electric Reliability Corporation
WECC – Western Electricity Coordinating Council
RE – Regional Entity
TPL – Transmission Planning (Standards Family)

4. Why the need of Reliability Standards?
November 9, 1965:
Northeast Blackout resulting in loss of power to 30 million people
July 13-14, 1977:
Blackout of New York City resulting in loss of power to 9 million people and widespread looting, arson and rioting
July 2-3, 1996 & August 10, 1996:
Western North American Blackouts impacting areas across Western Canada, Western United States and Northwest Mexico, resulting in loss of power to more than 7.5 million people
August 14, 2003:
Northeast/Midwest Blackout, including Ontario, Canada, resulting in loss of power to 50 million people (largest to date)

5. Actions taken after the 2003 Blackout?
2005: U.S. Energy Policy Act of 2005 creates the Electric Reliability Organization (ERO)
2006: Federal Energy Regulatory Commission (FERC) certified NERC as the ERO; Memorandum of Understanding (MOUs) with some Canadian Provinces
2007: North American Electric Reliability Council became the North American Electric Reliability Corporation (NERC); FERC issued Order 693 approving 83 of 107 proposed reliability standards; became mandatory and enforceable

6. What are the Reliability Standards?
Reliability Standards are the planning and operating rules that electric utilities follow to ensure the most reliable system possible
Standards are developed by the industry using a inclusive process managed by the NERC Standards Committee
Committee is facilitated by NERC staff and comprised of representatives from many electric industry sectors
NERC has eight Regional Entities (RE’s) across the United States and Canada
The RE’s are responsible for compliance monitoring and enforcement of the reliability standards
PacifiCorp’s RE is the Western Electricity Coordinating Council (WECC)

7. Who develops the Reliability Standards?
FERC
Approves/denies following full NERC process
NERC
Standard Action Request (SAR)
Board of Trustees (BOT) approves/denies continent wide (NERC) and regional (WECC) standards
Standard Drafting Teams (SDT)
Industry involved approval process
WECC
Oversees regional enforcement of reliability standards
Oversees the development of regional standards (more stringent than continent standards)
BOT approves regional (WECC) standards
Committee only approves Criterion
FERC
NERC
WECC

8. Who are NERC’s Regional Entities?
WECC: Western Electricity Coordinating Council
MRO: Midwest Reliability Organization
SPP: Southwest Power Pool
TRE: Texas Regional Entity
NPCC: Northeast Power Coordinating Council
RFC: ReliabilityFirst Corporation
SERC: SERC Reliability Corporation
FRCC: Florida Reliability Coordinating Council

9. Move to the new NERC TPL-001-4 Standard
NERC standard TPL refers to Transmission System Planning Performance requirements – became fully effective and enforceable on January 1, 2016
The new standard officially replaced the four individual standards previously in place – i.e., TPL , TPL-002-0b, TPL-003-0b and TPL a
TPL was for performance under normal conditions (Category A)
TPL-002-0b was for loss of a single BES element (Category B)
TPL-003-0b was for loss of two or more BES elements (Category C)
TPL-004-0a was for loss of two or more BES elements (Category D or Extreme Events)
Overall, the new standard was expanded over the previous standards with increased performance criteria and requirements – it has 65 requirements and sub-requirements
PacifiCorp is one of the first utilities in the industry to adopt the standard in its Transmission Planning Assessment performed in 2015 – results of which are summarized in another slide

10. TPL-001-004 Standard Requirements
R1 – Each Transmission Planner and Planning Coordinator shall maintain system models within its respective area for performing the studies needed to complete its Planning Assessment…
R2 – Each Transmission Planner and Planning Coordinator shall prepare an annual Planning Assessment of its portion of the BES…
R3 – For the Steady-State portion of the Planning Assessment, each Transmission Planner and Planning Coordinator shall perform studies for the Near-Term and Long-Term Transmission Planning Horizons…
R4 – For the Stability portion of the Planning Assessment, each Transmission Planner and Planning Coordinator shall perform the Contingency analysis listed in Table 1…
R5 – Each Transmission Planner and Planning Coordinator shall have criteria for acceptable Steady-State voltage limits, post-Contingency voltage deviations, and transient voltage response for its system…
R6 – Each Transmission Planner and Planning Coordinator shall define and document, within their Planning Assessment, the criteria or methodology used in the analysis to identify System instability…
R7 – Each Planning Coordinator, in conjunction with each of its Transmission Planners, shall determine and identify each entity’s individual and joint responsibilities for performing the required studies…
R8 – Each Transmission Planner and Planning Coordinator shall distribute its Planning Assessment results to adjacent Planning Coordinators and adjacent Transmission Planners…
Each Requirement has multiple Sub-Requirements – 57 in total

11. Some new requirements of TPL-001-4
Spare Equipment Strategy
R2.1.5 requires an annual study of impacts for the loss of major equipment, such as power transformers, that do not have a spare unit available and have a lead time of one year or more – studies shall be performed for the P0, P1 and P2 categories shown in Table 1 with the identified equipment out of service
Short Circuit Analysis
R2.3 requires a short circuit analysis to be conducted annually within the Near-Term Transmission Planning Horizon to determine if circuit breakers have interrupting capability for faults they would be expected to interrupt
R2.8 requires a Corrective Action Plan to address circuit breakers subject to short circuit interrupting duty levels that exceed their equipment rating
Non-consequential Load Loss
R2.7.2 cites that if situations arise that are beyond the control of the Transmission Planer or Planning Coordinator that prevent implementation of a Corrective Action Plan in the required timeframe, it is permitted to utilize Non-Consequential Load Loss and curtailment of firm Transmission Service (≤ 75 MW) to correct the situation that would normally not be permitted in Table 1 – this grace period is in place for five years from the date the standard was approved in 2015
Protection System Studies (R3.3.1)
R3.3.1 requires simulating the removal of all elements that the protection system and other automatic controls are expected to disconnect for each Contingency without operator intervention – includes RAS and other protection systems with automatic control

12. PacifiCorp’s TPL Study Schedule and Status
TPL Study Status
Study Plan draft completed March 17, 2016
Study Methodology draft completed April 22, 2016
Kickoff meeting held April 16, 2016
10 Base Cases completed for Steady-State analysis in June – four for PACE and six for PACW
PACW Bases Cases – 2017 summer peak, winter peak, summer peak, winter peak, 2018 light spring and summer peak (Long-Term)
PACE Base Cases – 2017 summer peak, 2021 summer peak, light spring and 2026 summer peak (Long-Term)
3 Base Cases for PACE and PACW to perform Stability Analysis – 2017 summer peak, 2018 light spring and 2026 summer peak (Long-Term, if necessary)
Simulations are currently being run for Steady-State base cases
Stability analysis will be performed based upon the results of the Steady-State simulations
Short-circuit study is completed – some over-duty breakers found
Analysis for extreme events, sensitivity studies and loss of major equipment without spares will proceed at the conclusion of the Steady-State analysis
Study team is targeting early November 2016 to deliver preliminary reports for PACE and PACW
PacifiCorp's 2016 NERC TPL Study Schedule
Task Name
Target Completion Dates
Duration
Develop Study Plan
3/17/2016
1 Week
Develop Study Methodology
4/8/2016
2 Weeks
Study Kickoff
4/15/2016
Review WECC Regional Performance Criteria and PacifiCorp's Thermal and Voltage Criteria
4/22/2016
Develop and Finalize Base Cases
6/21/2016
4 Weeks
Develop Contingency Definition Files
6/30/2016
Develop and Send Preliminary Contingency Description to Adjacent Utilities
Run Simulation and Summarize Results
9/1/2016
10 Weeks
Run Simulation and Summarize Results for Sensitivity and Spare Equipment, etc.
9/20/2016
Report Write-up and File Documentation
11/1/2016
Operating procedures Drafting, PRC-023 R6 Reporting
12/1/2016
8 Weeks

13. Results of the 2015 Planning Assessment
Contingency Studies Performed
Activity Description
PACE
PACW
Total
Planning Events Studied for Steady-State Analysis
465,279
46,116
511,395
Transient Stability Contingencies Studied for Planning Events
125
152
277
Extreme Events Studied for Steady-State Analysis 16 9 25
Extreme Events Studied for Stability Analysis 6 12
Sensitivity Cases Studied for Steady-State Analysis 1 3 4
Sensitivity Cases Studied for Stability Analysis 5
Results of Contingency Studies
Activity Description
Corrective Action Plans
PACE
PACW
Total
Steady-State Analysis 17 3 20
Stability Analysis 1
Extreme Events from Steady-State Analysis
Extreme Events from Stability Analysis
Sensitivity Cases from Steady-State Analysis
Sensitivity Cases from Stability Analysis
Spare Equipment Analysis
Short Circuit Studies 7
Notes:
1. Deficiencies Identified for Steady-State Analysis of P1-P7 Planning Events: 33 Total (PAVE 13, PACW 20)
2. Deficiencies Identified for Stability Analysis of Contingencies Studied for Planning Events: 1 Total (PACE 0, PACW 1)
3. Operating Procedures are put in place to address deficiencies until corrective projects are placed in service
4. PacifiCorp has a total of 38 Operating Procedures in place to address TPL issues (PACE 11, PAW 27)

14. Compliance Monitoring and Enforcement
WECC, with delegated authority from NERC, is the Regional Entity responsible for compliance monitoring and enforcement for the Western Region of the United States
WECC provides the environment for development of reliability criteria, occasional regional variances, and coordination of the operating and planning activities of its members
NERC is the driving force for developing new standards through its process of an Open Call for Standard Drafting to get team members from its Regional Entities memberships – FERC reviews and approves new and modified NERC Standards
WECC provides audit oversight for compliance with NERC Standards for Critical Infrastructure Protection and Operations and Planning Standards
NERC has a three year auditing cycle for its TPL Standards – the next audit of PacifiCorp’s TPL compliance is scheduled for 2019

15. NERC TPL-001-4 Standard Overview
Questions?