Transmission Planning Attachment K Public Input Meeting FERC
Transmission Planning Attachment K Public Input Meeting FERC Order 1000, 2018 -19 Biennial Planning Cycle Quarter 3 Meeting September 13, 2018
Agenda Pacific Time Topic 9: 00 – 9: 05 • Greetings and Introductions • Explain the Planning Process o Discuss status of the local planning process and any interim iterations of the draft Local Transmission Plan; Jamie Austin 9: 15 – 9: 30 • TPL Study Process Scott Beyer 9: 30 – 9: 40 • Status of Ongoing Area Planning Studies Scott Beyer, Jake Barker 9: 40 – 9: 55 Five Year Studies • PACW Area, Kickoff Studies: o Coos Bay Study • PACE Area, Kickoff Studies: o Montpelier Study 9: 55 – 10: 00 • Adam Lint, Larry Frick Sachith Abayakoon Q&A PAGE 2 9: 05 – 9: 15 Presenter
The Planning Process Jamie Austin
3 rd Quarter Deliverables Process – Discuss status of the local planning process and interim iterations of the draft Transmission System Plan: 4 Technical Studies – for designing a reliable system Economic Studies - economic analysis to identify transmission congestion – Pacifi. Corp has been Providing quarterly updates to Stakeholders on local transmission studies (5 -yrs studies; reliability assessment studies) – Current plan includes posting a draft TSP in Q 4, 2018 – Review of the Transmission System Plan Outline PAGE 4 4
– – – – INTRODUCTION FERC ORDER 8901000, ATTACHMENT K, LOCAL TRANSMISSION PLANNING PROCESS DISCUSSION THAT TIES THIS WORK TO OUR EXISTING PLANNING LOCAL PLANNING OBJECTIVES OF THE TRANSMISSION SYSTEM PLAN SUB-REGIONAL & REGIONAL COORDINATION PLANNING PROCESS AND TIMELINE TRANSMISSION SYSTEM PLAN INPUTS AND COMPONENTS ASSUMPTIONSDATABASES GENERAL DESCRIPTION OF PACIFICORP’S TRANSMISSION SYSTEM 4 Pacifi. Corp East Balancing Area – Description 4 Pacifi. Corp West Balancing Area – Description LOAD AND RESOURCE PROCESS RELIABILITY ASSESSMENT AREA PLANNING STUDIES 10 -YEAR PLANNING HORIZON ECONOMIC STUDIES COST ALLOCATION PAGE 5 Transmission System Plan Outline
Economic Planning Studies Background PAGE 6 – The Economic studies identify “significant and recurring” congestion. – Stakeholders can submit study requests through the OASIS process. – No study requests were submitted in Q 1 – Next chance to submit requests will be in Q 5
Pacifi. Corp 8 Quarter Process PAC BIENNIAL TRANSMISISON PLANNING CYCLE 2018 -2019 Quarter Date Technical Studies Economic Studies Activities Q 1 Data Collection for Jan - Mar Economic Studies Q 2 Reference Case Apr - Jun Development Q 3 Technical Studies to Economic Studies to Jul - Sep determine System Identify Congestion Adequacy Q 4 Oct - Dec Draft Reporting Q 5 Data Collection for Re. Draft Report on System Study Adequacy Re-Study Requests Jan - Mar Economic Study Second Year Requests Q 6 Q 7 Q 8 Apr - Jun Jul - Sep Oct - Dec Draft Report Review Draft Re-Study Review Final Report and Review Final Transmission Plan approval PAGE 7 Year 2 - 2019 Year 1 -2018 Time Line
NERC TPL-001 -4 Standard Overview Scott Beyer
Overview Areas PAGE 9 – Background – NERC TPL-001 -4 Standard – 2018 TPL Plan and Status Update – 2017 Planning Assessment Results – Compliance Monitoring and Enforcement 9
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) PAGE 10 – – – – 10
– 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) PAGE 11 Why the need of Reliability Standards? 11
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 PAGE 12 – 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 12
What are the Reliability Standards? – Reliability Standards are the planning and operating rules that electric utilities follow to ensure the most reliable system possible 4 4 Standards are developed by the industry using a inclusive process managed by the NERC Standards 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 4 The RE’s are responsible for compliance monitoring and enforcement of the reliability standards Pacifi. Corp’s RE is the Western Electricity Coordinating Council (WECC) PAGE 13 4 13
Who develops the Reliability Standards? – FERC 4 Approves/denies following full NERC process – NERC 4 4 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 FERC NERC 4 4 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 WECC 14 PAGE 14 – WECC
WECC: Western Electricity Coordinating Council MRO: Midwest Reliability Organization SPP: Southwest Power Pool TRE: Texas Regional Entity NPCC: Northeast Power Coordinating Council RFC: Reliability. First Corporation PAGE 15 Who are NERC’s Regional Entities? 15
Development of NERC TPL-001 -4 Standard – NERC standard TPL-001 -4 refers to Transmission System Planning Performance requirements – became fully effective and enforceable on January 1, 2016 – The TPL-001 -4 standard revision officially replaced the four individual standards previously in place – i. e. , TPL-001 -0. 1, TPL-002 -0 b, TPL-003 -0 b and TPL- 004 -0 a 4 4 TPL-001 -0. 1 was for performance under normal conditions (Category A) TPL-002 -0 b was for loss of a single BES element (Category B) TPL-003 -0 b was for loss of two or more BES elements (Category C) TPL-004 -0 a was for loss of two or more BES elements (Category D or Extreme Events) PAGE 16 – Overall, the new standard was expanded over the previous standards with increased performance criteria and requirements – it has 65 requirements and subrequirements 16
– R 1 – Each Transmission Planner and Planning Coordinator shall maintain system models within its respective area for performing the studies needed to complete its Planning Assessment… – R 2 – Each Transmission Planner and Planning Coordinator shall prepare an annual Planning Assessment of its portion of the BES… – R 3 – 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… – R 4 – For the Stability portion of the Planning Assessment, each Transmission Planner and Planning Coordinator shall perform the Contingency analysis listed in Table 1… – R 5 – 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… – R 6 – 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… – R 7 – 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… – R 8 – 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 – 17 57 in total PAGE 17 TPL-001 -004 Standard Requirements
Example sub-requirements of TPL-001 -4 Spare Equipment Strategy 4 – Short Circuit Analysis 4 4 – R 2. 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 R 2. 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 4 – R 2. 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 P 0, P 1 and P 2 categories shown in Table 1 with the identified equipment out of service R 2. 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 (R 3. 3. 1) 4 R 3. 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 18 PAGE 18 –
Pacifi. Corp’s TPL Study Schedule and Status TPL Study Status • Study Plan draft completed April 24, 2018 • Study Methodology draft completed May 31, 2018 • 10 Base Cases completed for Steady-State analysis in June 2018 – four for PACE and six for PACW § PACW Bases Cases – 2019 summer peak, 2019 -2020 winter peak, 2020 light spring, 2023 summer peak, 2023 -2024 winter peak, and 2028 summer peak (Long-Term) § PACE Base Cases – 2019 summer peak, 2020 light spring, 2023 summer peak and 2028 summer peak (Long-Term) • 2 Base Cases for PACE and PACW to perform Stability Analysis – 2023 summer peak, 2020 light spring • 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 • Study team is targeting November 2018 to deliver preliminary reports for PACE and PACW 19 PAGE 19 • Analysis for extreme events, sensitivity studies and loss of major equipment without spares will proceed at the conclusion of the Steady-State analysis
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 4 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 PAGE 20 – NERC has a three year auditing cycle for its TPL Standards – the next audit of Pacifi. Corp’s TPL compliance is scheduled for 2019 20
NERC TPL-001 -4 Standard Overview PAGE 21 Questions? 21
Local Area Studies Update - PACW Scott Beyer
Time-line 5 -yr studies - West State Existing Study Completion Date Update Study Status Comments Crescent City CA Feb-17 Grants Pass OR Dec-15 Hood River OR Nov-15 Pendleton/Hermiston/Enterprise OR May-17 Walla/Wallula WA Dec-09 85% Roseburg OR Sep-10 40% Portland OR Mar-11 Dalreed/Arlington/Sherman County OR Mar-11 100% Completed May 2018 Klamath Falls OR May-11 Lakeview/Alturas OR May-11 Coos Bay OR Aug-11 North Oregon Coast OR Sep-17 Yakima WA Dec-11 95% Medford OR Sep-12 Willamette Valley OR Dec-12 Junction City/Cottage Grove OR Dec-12 Central Oregon OR Mar-13 Yreka CA Dec-14 Attachment K Kick-Off September 2018 PAGE 23 Study Area
Attachment-K Q 3 Public Meeting Coos Bay Area Transmission Planning Study Kickoff PAGE 24 Area Planner: Adam Lint Presented by Larry Frick September 13, 2018
Sub-Transmission Planning Studies 4 Pacific Power study plan Service Area is divided into 17 study areas 8 The studies are designed to predict the future electrical system requirements about 5 -7 years out. 8 The goal is to update each about every 36 months. PAGE 25 8 25
PAGE 26 Pacific Power Study Areas 26
Inputs to a Planning Study 4 New load requests (L&R) 4 Customer transmission & substation data 4 Generation increases and operations plans 4 Potential system modification data 4 Two restrictions to public access Maintaining confidential customer information 8 Maintaining FERC & WECC codes of conduct PAGE 27 8 27
Coos Bay Area Topology Main Grid Sources 4 230 k. V 8 8 Alvey-Fairview Dixonville-Fairview Common Corridor Fairview-Isthmus 4 115 k. V Tahkenitch-Fairview 4 Coos-Curry system downstream via BPA Rogue and BPA Bandon 28 PAGE 28 8
Coos Bay Area Topology Northern Portion 4 230 -115 k. V Isthmus source 4 Distribution substations Coos River Lockhart State Street South Dunes Empire Jordan Point 8 8 8 29 At Empire facing State Street, switch 2 C 14 At Lockhart facing Red Dike Tap, breaker 2 C 6 Both SCADA controlled Normal Open Points PAGE 29 4 Normal open points
Coos Bay Area Topology Southern Portion 4 Pacific Power subs Coquille Myrtle Point Norway Tie Bandon (Pac. portion) Fairview Norway Bandon CCEC subs 30 PAGE 30 4 Foreign subs
Coos Bay Area Loads (Pacific Power) 4 Based on most recent load projections Summer ~ 94 MW 8 Winter ~ 150 MW 8 Overall growth rate 0. 2% 8 Winter limited 8 Overall load factor 51% PAGE 31 8 31
Coos Bay Area Transmission Planning Study PAGE 32 4 Expected completion 2019 Q 2 4 Questions or Input requests? 32
Local Area Studies Update – PACE Jake Barker
Time-line 5 -yrs studies – East State Last Studied Update Ogden UT Aug-14 65% Complete Utah (Southwest) UT Dec-14 90% Complete Pavant UT Feb-15 95% Complete Goshen ID Jun-15 WY Nov-15 Montpelier ID Feb-16 Utah Valley UT Apr-16 Honeyville/Malad UT May-16 Grace ID Jul-16 Smithfield ID Jul-16 Price UT Jul-16 Utah (Southeast) UT Jun-16 Vernal UT Nov-16 Sigurd UT Feb-17 Presented Q 5 North Salt Lake UT Feb-17 Presented Q 5 Wyoming (Southern) WY Mar-17 Presented Q 5 Salt Lake Valley UT May-17 Presented Q 6 Tooele UT Jun-17 Presented Q 6 Wyoming (West) WY Oct-17 Presented Q 8 Park City/Midway UT Oct-17 Presented Q 8 Big Horn WY Nov-17 Presented Q 8 Nebo UT Apr-18 Presented Q 2 Powder River Completed PAGE 34 Study Area
Sachith Abayakoon PAGE 35 MONTPELIER, IDAHO STUDY
MONTPELIER, IDAHO AREA STUDY – 4 4 Sachith Abayakoon Ovid – 138 -69 k. V • 138 k. V source from Oneida • Reactive Support to the Area Sage – 69 -46 k. V • 69 k. V source from Naughton Generation • Serves 46 k. V Loads • 15 area substations in three different states: Idaho, Utah and Wyoming. The total area is approximately 1, 900 square miles. Includes Bear Lake recreational area. PAGE 36 Primary Sources
Load Growth – Area Loading Summer of 2017 area loading was at 29 MW 4 Winter of 2016 - 17 area loading was at 22 MW 4 – Growth Average area growth has been about 2. 1% PAGE 37 4
Sachith Abayakoon POWDER RIVER, WYOMING STUDY PAGE 38 No changes to previous study identified.
Attachment K 2018 -19 Biennial Planning Cycle Q 4 Public Meeting December, 2018 Pacifi. Corp
Q & A Session Contact Information – Link to Pacifi. Corp OASIS: http: //www. oasis. oati. com/ppw/index. html PAGE 40 For Attachment K related commentsquestions, address your requests to: Transmission. Planning. Proposal@Pacifi. Corp. com
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