MEETING AGENDA. Western Area Power Administration Rocky Mountain Region. Transmission Planning Stakeholder Meeting

Transcription

1 MEETING AGENDA Western Area Power Administration Rocky Mountain Region Transmission Planning Stakeholder Meeting Western s RMR Regional Office 5555 East Crossroads Boulevard, Loveland, CO June 23, :30 pm to 3:30 pm MDT 1) 1:30 pm... Introduction of Attendees \ Finalize Agenda (Bob Easton) 2) 1:35 pm... Overview of the Western s Process for FERC Order No. 890 (Debbie Farm) 3) 1:45 pm... West Connect Transmission Update (Bob Easton) 4) 2:00 pm... Transmission Planning Studies (Jim Hirning) 5) 2.15 pm... Review of 2014 Transmission Planning Study Scope & Process (Jason Parker) 6) 2:30 pm... Big Horn Basin Area Study Results (Susan Franklin) 7) 2:45 pm... Capital Investment Plan (Susan Franklin) 8) 3:15 pm... Stakeholder Input / Open Discussion (Bob Easton) 9) 3:25 pm... Next Meeting Date (December 11, 2014) and Closing Remarks (Bob Easton) 10) 3:30 pm... Adjourn

2 Western Area Power Rocky Mountain Region Planning Stakeholder Meeting (Western OATT Attachment P) June 23, 2014

3 Meeting Purpose To inform stakeholders about Western s transmission system planning process and an opportunity for the stakeholders to provide their input Allow Western to maximize its understanding of its customers forecasted needs for Western s transmission system Review transmission plans

4 OATT Revision Order 890 issued Feb. 16, 2007 Western maintains a safe harbor OATT with FERC Not required to abide by Order 890 compliance deadlines like jurisdictional TPs Resources and projects are based on statutory or budgetary restrictions Any variances in the FERC approved OATT must be justified to customers and accepted by FERC May make modifications that are consistent with or superior to pro forma OATT provisions Western revised OATT to address Order 890 Submitted to FERC September 29, 2009 Effective Date: December 1,

5 OATT Revision Western has filed revisions to its OATT to clarify certain provisions. FERC approved April 12, 2013 OATT Revisions can be viewed through FERC s tariff viewer: Tariff documents are posted on OASIS at the following URL: Effective pdf 4

6 FERC Order 890 Planning Principles Transmission Planning: FERC requires a more inclusive transmission planning process incorporating nine principles: (1) coordination, (2) openness, (3) transparency, (4) information exchange, (5) comparability, (6) dispute resolution, (7) regional participation, (8) economic planning studies, and (9) cost allocation for new projects. 5

7 Types of Planning Studies NERC/WECC Reliability Studies meet NERC/WECC standards and coordination through CCPG. Sub-regional Coordination (CCPG) - identify congestion and overloads and address integration of new resources and loads Ten Year Transmission Study evaluates the system to ensure we can serve our customers requirements/load growth Generator Interconnection and Transmission Service Requests

8 Types of Planning Studies» Western invites the stakeholders to submit any transmission study requests for review and discussion»western s point of contact for study requests is rmrplanningmanager@wapa.gov.

9 Western s Service Territory

10 WestConnect Transmission Planning Update Bob Easton 890 Stakeholder Meeting June 23, 2014

11 WestConnect Planning Footprint Quick Facts Touches 11 Western States 9.8 Million Retail Customers 56,000 MW Demand 39,000 Miles of Transmission 1.7 Million Miles 2 2

12 Regional Planning Groups Footprint WECC Subregional Planning Groups Major Transmission Facilities ColumbiaGrid Northern Tier Transmission Group (NTTG) BC Coordinated Planning and Alberta System Operator that are not part of ColumbiaGrid or NTTG WestConnect (SWAT, CCPG & SPPG) California ISO California Transmission Planning Group that are not part of CAISO Other Facilities 3

13 Parties to WestConnect STP Project Agreement Arizona Public Service Company Basin Electric Power Cooperative Black Hills Corporation El Paso Electric Company Imperial Irrigation District Platte River Power Authority Public Service Company of CO Public Service Company of NM Sacramento Municipal Utility District Salt River Project NV Energy Southwest Transmission Cooperative Transmission Agency of Northern California Tri-State Generation & Transmission, Assoc. Tucson Electric Power Company Western Area Power Administration Los Angeles Department of Water and Power 4

14 WestConnect Subregional Planning Groups CCPG, SSPG and SWAT are technical planning work groups within the WestConnect Footprint Coordinate Information for use by all study participants operate under Charters Define subregional study plans, provide study resources, and perform studies Provide forum for coordination and peer review of planning studies and 10-year plans SSPG Sierra Subregional Planning Group SWAT Southwest Area Transmission CCPG Colorado Coordinated Planning Group 5

15 2014 SCOPE of Work Manage Annual Planning Process Update the 10-Yr Planning Documents Participate in WECC TEPPC Coordinate WestConnect-wide 10-Yr Base Case OPTIONAL Coordinate with SCG (RCG now) 6

16 2014 SCOPE of Work Attend CCPG/SWAT/SSPG Joint Meeting August Tri-State Maintain TPM Database Participate in FERC Order 1000 Filing Strike Teams Much Work on Business Practice Manual and Planning Participation Agreement 7

17 Western Interconnection Planning Process RCG Process Coordination Among STPs 8

18 WestConnect Synchronized Planning Cycle TEPPC Economic Study Results For WestConnect Footprint 2014 Planning Cycle 11/20/14 Workshop SPG Study Results Future Study Needs Planning Report Prep. 3 mo. Study Plans Dev. Publish 10 Yr Plans Approve 2014 Trans. Reports 2015 Study Plans 2/19/15 Annual Mtg 2014 Planning Cycle WestConnect Economic Study Request of TEPPC Coordination / collaboration with Regional Planning Coordination Group (RCG)

19 Western RMR Transmission Planning Stakeholder Meeting 2014 Transmission Planning Studies Jim Hirning Transmission Planner Loveland, CO June 23,

20 NERC/WECC Transmission Planning TPL-001, -002, -003, -004 Ensure system is adequate to meet present and future needs Demonstrate through assessment Planning for near and long term Cover all demand levels over range of forecast demands Include existing and planned facilities Ensure adequate reactive resources 2

21 CCPG Colorado Coordinated Planning Group Eight Member Utilities Basin Electric Power Cooperative Black Hills Corporation Colorado Springs Utilities PacifiCorp Platte River Power Authority Public Service Company of Colorado (Xcel Energy) Tri-State Generation & Transmission Assoc. Western Area Power Administration-RMR 3

22 Yellowtail CCPG Footprint Thermopolis Buffalo Wyodak Osage Lange Rapid City (DC Terminal) Riverton Casper Spence Platte Jim Bridger Dave Johnston Laramie River Stegall (DC Terminal) Archer Sidney (DC Terminal) To Ashley To Upalco To Mona Flaming Gorge Vernal Bonanza Meeker Craig Hayden Gore Pass Ault Ft. St. Vrain Pawnee Story N. Yuma Rifle Cherokee Big Sandy Burlington Malta Midway Montrose Curecanti Poncha Lost Canyon Boone Comanche Lamar (DC Terminal) Hesperus Trinidad To To San Juan To Glade

23 2011 NERC/WECC Compliance Report Performed Annually Area Studied Colorado Wyoming Western Nebraska Western South Dakota 5

24 Purpose Evaluate the steady state post-contingency response of the Integrated System Evaluate transient and voltage stability Identify problem areas due to system load growth Meet NERC/WECC Transmission Planning Standards 6

25 Study Procedure CCPG Compliance Study Cases To Be Examined 2019 Heavy Winter 2019 Light Winter 2019 Light Winter High Renewables 2025 Heavy Summer System Intact Criteria 100% Continuous Rating Loading 0.95 p.u p.u. Voltage Contingency Analysis Criteria 100% Continuous/Emergency Rating Loading 0.90 p.u p.u. Voltage 7

26 Questions Any Questions or Comments? 8

27 2014 Transmission Planning Study Jason Parker Planning Engineer June 23, 2014

28 Objectives Western will provide reliable, value driven service to preferential customers. To maintain compliance with NERC and Western standards. Evaluate the load serving capability of the integrated system while preserving TOT path capacities. Scope, schedule and prioritize Western transmission and substation system projects for inclusion in the Capital Improvement Plan (CIP).

29 Process Loads Request and receive load data from network customers Jan-March 2014 Power Flows Develop base cases March-April 2014 Projects Analyze power flow results Study solutions Report May-July 2014 Inclusion in Capital Improvement Plan Preliminary Scope and Estimates Aug-November 2014 Stakeholders Present study results at Quarterly Stakeholders Meeting December 2014

30 Process Improvements Annual Study Guidelines created and implemented for the Rocky Mountain Region and Desert Southwest Region. Coordination of study cases with the Desert Southwest, utilizing the same seed case such that all updates for DSW and RMR are in the same cases. Study Processes: Study focused on Network Customer load forecasts and scheduled system improvements. Alternate study focused on Network Customer load and no system improvements.

31 Study Criteria WECC approved cases: 2019 Heavy Summer 2024 Heavy Winter 2019 Heavy Summer case study will include post transient and transient analysis where applicable and study without scheduled system additions.

32 Study Criteria Criteria System Intact 0.95 p.u p.u. Voltage 100% Continuous Loading Rate Contingency 0.90 p.u p.u. Voltage 100% Continuous Rating or Emergency Limit Contingency Analysis N-1, N-2 Monitored integrated system and adjacent area. Transformer emergency rating-120% of normal thermal rating.

33 Study Criteria Stress Levels applied to cases: TOT 1A, WECC Path MW East-West, 2019 HS YTS 625 MW North-South, 2024 HW

34 Study Criteria Studies based on network customer projections 5 & 10 years in the future. Voltage and thermal issues that appear for the first time will be monitored for recurrence. Voltage and thermal issues that repeatedly appear may be studied as a sensitivity study and result in a change of the corrective action plan and Capital Improvement Plan.

35 Upcoming Events Analysis of studies. Compilation and ranking of proposed capital budget items. Desert Southwest and Rocky Mountain Region combined 2014 Ten Year Annual Report.

36 Questions?

37 Big Horn Basin Area Study Susan Franklin Facilities & Construction June 23, 2014

38 The Big Picture

39 The Big Horn Basin Study Area

40 Items of Interest Generation patterns from a planning perspective 69 kv voltages, high vs. low 69 kv thermal limitations 115 kv line loading for N-1 contingencies Load growth accommodation of solutions

41 Generation Patterns Generation and impact on voltage Buffalo Bill-3 units One unit active at minimum levels in winter Sprit Mountain-1 unit Seasonal when irrigation is available Shoshone-1 unit Active at minimum levels in winter Heart Mountain-1 unit Seasonal when irrigation is available Drought-minimum levels of 1 MW total 30.5 MW maximum generation

42 69 kv Voltages Studies have indicated low 69 and 115 kv voltages for many N-1 outages studied in the past three Annual Studies. Real time reports of high voltages at Heart Mountain, Lovell, and Big George 69 kv buses for system in-tact. Research existing facilities and update the power flow base case. Generation bus voltage targets Generation step up transformer taps LV and BGG 115/69 kv transformer taps YT 230/115 kv transformer taps TH 230/115 kv transformer taps Load confirmation

43 69 kv Voltage Profiles

44 What Is Impacting the V System In-tact? Generation Facilities Bus voltage targets have changed due to issues within the power plants, resulting in nominal to boosting tap settings on the generator step-up transformers Lovell and Big George 115/69 kv transformer tap settings Boosting the 69 kv voltage 2.5% Yellowtail and Thermopolis 230/115 kv transformer tap and LTC settings Boosting the 115 kv voltage 2.5% High generation and light loads result in higher voltages

45 Which Outages are Impacting the V? Outage of any of these elements result in low 69 kv voltages: Lovell 115/69 kv transformer Big George 115/69 kv transformer Lovell-Garland 69 kv Line Big George-Glendale Tap 69 kv Line Heart Mountain-Glendale Tap 69 kv Line Big George-North Cody 69 kv Line

46 69 kv Limitations Two sources: 115/69 kv 50 MVA transformers 60 MVA line capacity limits on the 69 kv system Variable 69 kv generation

47 69 kv Solutions Add a THIRD 115/69 kv Source at North Cody Existing ROW Substation space available at load center

48 69 kv Cost Estimates (Preliminary) Big George-Heart Mountain 115 kv Circuit and Heart Mountain-North Cody 115 kv Conversion Big George Substation work North Cody Transformer and Sub Work TOTAL: $4,940,000 Target In-service Date: 2016

49 115 kv Lines System in-tact-acceptable performance N-1 contingency of three outages result in an overload on the Basin- Worland Tap 115 kv line Options Studied: 2 nd Yellowtail-PACE Yellowtail 230 kv line Tie PACE Yellowtail-Sheridan 230 kv line into Crossover 230 substation as 2 nd tie to the PACE Yellowtail 230 kv system Continue Re-conductor from Lovell to Worland Tap 115 kv line

50 115 kv Cost Estimates (Preliminary) The recommendation is the continuation of the LV- BA115 kv line re-conductor, extending the project from Basin to Worland Tap, 15 miles. Basin-Worland Tap 115 kv Line Re-conductor $2,000,000 Target In-service Date: 2016

51 Yellowtail South: 625 MW to 700 MW Completion of the following projects: Lovell-Yellowtail #1 & #2 Line Rebuild Lovell-Nahne Jensen-Basin 115 kv Re-Conductor New Basin-Worland Tap 115 kv Re-Conductor Capacitor Banks for voltage support

52 Big Horn Basin Load Growth Forecasted Load Growth 69 kv System: 1-1.6% 115 kv System: % North Cody Substation and 115 kv line project accommodates expected load growth beyond the twenty year window.

53 Questions? Contact Susan Franklin

54 Western Rocky Mountain Region FY14 Major Capital Program Overview Prepared by Susan Franklin 23 June 2014

55 TRANSMISSION Pick Sloan CRSP

56 PICK SLOAN MAJOR CAPITAL TRANSMISSION PROJECTS Transmission Lines Basin-Lovell 115-kV uprate Big George-Heart Mountain 69-kV Reconductor Estes-Flatiron 115-kV Rebuild Gem City-Snowy 115-kV Rebuild Granby-Windy Gap 138/69-kV Rebuild-Trust Goshen-Torrington uprate to 115-kV Line Switch Replacements- Eastern Colorado, Wyoming, Nebraska Transmission Line Programs Lovell-Yellowtail

57 PICK SLOAN TRANSMISSION LINES Basin-Lovell 115-kV uprate Reconductor 35 miles of line with 477 ACSS and add one overhead fiber optic ground wire Estimated Project Cost: $ 6,915K ISD 2015 Big George-Heart Mountain 69-kV Reconductor Reconductor 6 miles of line with 477 ACSR Estimated Project Cost: $ 790K ISD 2014 Estes-Flatiron115-kV Rebuild 16 miles each, Double Circuit Steel or Wood-H Estimated Budget: $19,300k ISD Gem City-Snowy 115-kV Rebuild 1.2 miles, Wood H Estimated Budget: $ 750k ISD 2014

58 PICK SLOAN TRANSMISSION LINES Granby Pumping Plant-Windy Gap 138/69-kV Rebuild-TRUST 12 miles, Double Circuit Steel Estimated Budget: $18,800k ISD 2015 Goshen-Torrington Rebuild (PVVC) Rebuild 6.5 miles at 115-kV Estimated Budget: $ 2,080 ISD 2016

59 PICK SLOAN 115-KV LINE SWITCH REPLACEMENTS Wyoming Glendale Tap Estimated Budget: $625k ISD: FY14

60 LOVELL-YELLOWTAIL PROGRAM Phase 1 National Park Service (NPS)-Complete Phase 2 Area outside of the NPS and the Crow Reservation-Complete Phase 3 Crow Reservation Phase 1, 2, 3 were initiated due to age and condition 115-kV construction with 795 ACSS conductor. Line rating will be 330 MW each

61 LOVELL-YELLOWTAIL REBUILDS Phase 1 National Park Service only. Scope : Project to rebuild the LV-YT 115-kV #1 and #2 lines. Each are 15 miles (30 miles total) Estimated Budget: $14,186k ISD: FY13 Status: Complete Phase 2 Outside of the NPS and the Crow Reservation Scope : Project to rebuild the LV-YT 115-kV #1 and #2 lines. Each are 16 miles (32 miles total). Estimated Budget: $6,922k Start: FY13 ISD: FY14 Status: Complete Phase 3 Crow Reservation Scope : Project to rebuild the LV-YT 115-kV #1 and #2 lines. Each are 15 miles (30 miles total). Estimated Budget: $8,646k Start: FY14 ISD: FY Negotiations Ongoing

62 CRSP TRANSMISSION LINE PROJECTS Pleasant View 24.9-kV Line Replacement Budget: $661k FY16

63 SUBSTATION Pick Sloan CRSP

64 MAJOR PICK SLOAN SUB/SWITCHYARD PROJECTS Cheyenne Stage 4: 2 nd 230/115 kv, 200 MVA Transformer Addition Gering Substation: 115 kv, 30 MVAR Cap Bank Goshen County New 230/115 kv Substation-PVVC Laramie Substation New 115 kv, 8.1 MVAR Cap Bank Pilot Butte New 115 kv, 15 MVAR Cap Bank-Trust Stegall KV1A 230/115 kv, 167 MVA Transformer Replacement Stegall Replace 21 MAR Reactor and Breaker

65 MAJOR PICK SLOAN SUB/SWITCHYARD PROJECTS Cheyenne Stage 4: 2 nd 230/115 kv, 200 MVA Transformer Addition Install 2 nd 230/115 kv, 200 MVA Transformer Estimated Project Cost: $ 4,038K ISD 2014 Gering Substation: 115 kv, 30 MVAR Cap Bank Install single step 30 MVAR Cap bank Estimated Project Cost: $ 1,005K ISD 2015 Goshen County New 230/115 kv Substation-PVVC Install new 230/115 kv substation for PVVC Estimated Budget: $13,660k ISD 2016 Laramie Substation New 115 kv, 8.1 MVAR Cap Bank 1.2 miles, Wood H Estimated Budget: $ 814k ISD 2014

66 MAJOR PICK SLOAN SUB/SWITCHYARD PROJECTS Pilot Butte New 115 kv, 15 MVAR Cap Bank Install 2 nd 15 MVAR Cap Bank on the 115 kv Bus Estimated Project Cost: $ 1,000K ISD 2015 Stegall KV1A 230/115 kv 167 MVA Transformer Replacement Replace 100 MVA with 167 MVA Estimated Project Cost: $ 3,965K ISD 2015 Stegall Replace KW1A, KW2A, 21 MAR Reactor and Breaker Replace failed/end of life reactors and breaker on 13.8 kv tertiary Estimated Project Cost: $ 875K ISD 2015

67 MAJOR CRSP SUB/SWITCHYARD PROJECTS Archer KV1A 230/115/13.8-kV 200 MVA Transformer Replacement Ault 345 kv Breaker Replacements (692, 696, 1096)-Trust Curecanti KZ1A 230/115 kv, 150 MVA Transformer Replacement Hayden KY2A 230/115 kv, 250 MVA Transformer Replacement Waterflow Phase Shifter Replacement KU1A and KU1B

68 MAJOR CRSP SUB/SWITCHYARD PROJECTS Archer KV1A 230/115/13.8-kV 200 MVA Transformer Replacement Replace failed 167 MVA with 200 MVA Estimated Project Cost: $ 3,158K ISD 2014 Ault 345 kv Breaker Replacements (692, 696, 1096)-Trust/Joint Replace 345 kv Breakers 692, 969, 1096 Estimated Project Cost: $ 2,210K ISD 2015 Curecanti KZ1A 230/115 kv, 150 MVA Transformer Replacement Replace 75 MVA with HDN KZ2A 150 MVA Estimated Budget: $3,400k ISD 2016 Hayden KY2A 230/115 kv, 250 MVA Transformer Replacement Replace 150 MVA with a 250 MVA transformer Estimated Budget: $ 6,653k ISD 2015 Waterflow Phase Shifter Replacement KU1A and KU1B Replace failed KU1A and KU1B phase shifting transformers Estimated Budget: $ 14,275k ISD 2016

69 WESTERN RMR MAJOR CAPITAL PROGRAM FY14 Questions? Contact Susan Franklin Facilities & Construction