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MEETING AGENDA
Western Area Power Administration Rocky Mountain Region
Transmission Planning Stakeholder Meeting
Western’s RMR Regional Office 5555 East Crossroads Boulevard, Loveland, CO 80538
June 25, 2013 – 1:00 pm to 3:00 pm MDT
1) 1:00 pm ............................................ Introduction of Attendees \ Finalize Agenda (Bob Easton)
2) 1:05 pm ................... Overview of the Western’s Process for FERC Order No. 890 (Debbie Farm)
3) 1:15 pm ............................................................. West Connect Transmission Update (Bob Easton)
4) 1:30 pm ................................................................. Transmission Planning Studies (Jim Hirning)
5) 1:45 pm ............... Review of 2013 Transmission Planning Study Scope & Process (Jason Parker)
6) 2:00 pm ............................................................ Capital Investment Plan (Randy Medicine Bear)
7) 2:30 pm ........................................................ Stakeholder Input / Open Discussion (Bob Easton)
8) 2:45 pm ......................... Next Meeting Date (December 3rd) and Closing Remarks (Bob Easton)
9) 3:00 pm ......................................................................................................................... Adjourn
Western Area Power Rocky Mountain RegionRocky Mountain Region
Planning Stakeholder Meeting(Western OATT Attachment P)
June 25, 2013
Meeting PurposeMeeting Purpose• To inform stakeholders about Western’s transmission
system planning process and an opportunity for thesystem 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 systemtransmission system
• Review transmission plansReview transmission plans
OATT RevisionOATT Revision• Order 890 issued Feb. 16, 2007
Western maintains a safe harbor OATT ith FERC• 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, 2009Effective Date: December 1 2009– Effective Date: December 1, 2009
3
OATT RevisionOATT Revision• Western has filed revisions to its OATT to clarify
certain provisions FERC approved April 12 2013certain provisions. FERC approved April 12, 2013
• OATT Revisions can be viewed through FERC’s tariff gviewer: http://etariff.ferc.gov/TariffList.aspx
• Tariff documents are posted on OASIS at the following URL: http://www.oasis.oati.com/WAPA/WAPAdocs/WAPA-OATT-http://www.oasis.oati.com/WAPA/WAPAdocs/WAPA OATTEffective-2013-0513.pdf
4
FERC Order 890 – Planning Principles• Transmission Planning: FERC requires a more
inclusive transmission planning process incorporatinginclusive transmission planning process incorporating nine principles:– (1) coordination,– (2) openness,– (3) transparency,– (4) information exchange,( ) g ,– (5) comparability,– (6) dispute resolution,
(7) regional participation– (7) regional participation,– (8) economic planning studies, and– (9) cost allocation for new projects.
5
Types of Planning StudiesTypes of Planning Studies
• NERC/WECC Reliability Studies – meet yNERC/WECC standards and coordination through CCPG.S C (CC G) f• 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 RequestsService Requests
Types of Planning StudiesTypes of Planning Studies
» Western invites the stakeholders to submit any» Western invites the stakeholders to submit any transmission study requests for review and discussion
»Western’s point of contact for study requests is [email protected].
Western’s Service Territory
W tC tWestConnect Transmission Planning Updateg p
Bob Easton890 Stakeholder Meeting
June 25 2013June 25, 2013
WestConnect Pl i F t i t
WECCWECC
Planning FootprintWECCWECC
Subregional Planning GroupsSubregional Planning GroupsMajor Transmission Facilities Major Transmission Facilities
ColumbiaGridNorthern Tier Transmission Group (NTTG)BC Coordinated Planning and Alberta System yOperator that are not part of ColumbiaGrid or NTTGWestConnect (SWAT, CCPG & SPPG)California ISOCalifornia ISOCalifornia Transmission Planning Group that are not part of CAISOOther Facilities
2
Parties to WestConnect STP P j t A tSTP Project Agreement
Arizona Public Service C
Salt River Project Company
Basin Electric Power Cooperative
NV Energy
Southwest Transmission Cooperativep
Black Hills Corporation
El Paso Electric Company
Cooperative
Transmission Agency of Northern Californiap y
Imperial Irrigation District
Platte River Power Authority
Tri-State Generation & Transmission, Assoc.
T El t i Py
Public Service Company of CO
Public Service Company of NM
Tucson Electric Power Company
Western Area Power
3
p y
Sacramento Municipal Utility District
Administration
Los Angeles Department of Water and Power
WestConnect S b i l Pl i GSubregional Planning Groups
CCPG SSPG and SWAT areCCPG, SSPG and SWAT are technical planning work groups within the
CCPGCCPGSSPGSSPG
WestConnect Footprint•Coordinate Information for use by all study participants
ColoradoCoordinated
PlanningGroup
Sierra Subregional Planning Group
y p p
•Define subregional study plans, provide study resources, and perform studies
SouthwestArea
Transmission
SWATSWAT•Provide forum for coordination and peer review of planning studies and 10-year plans
4
2013 SCOPE of Work
Manage Annual Planning Processg g
Update the 10-Yr Planning Documents
Coordinate Annual TTC/ATC WorkshopWorkshop
Participate in WECC TEPPC
Coordinate WestConnect-wide 10-Yr Base Case - OPTIONAL
5
Base Case - OPTIONAL
2013 SCOPE of Work
Coordinate with SCG
Attend CCPG/SWAT/SSPG Joint M tiMeeting
Maintain TPM DatabaseMaintain TPM Database
Participate in FERC Order 1000 Filing Strike Teams – October 2012; May 2013; July 2013 Filings
6
Western Interconnection Pl i PPlanning Process
SCG Process
Coordination Among STPs
7
WestConnect S h i d Pl i C lSynchronized Planning Cycle
TEPPC Economic Study ResultsFor WestConnect Footprint
2013 Planning Cycle Pl i R t P
For WestConnect Footprint
• Publish 10 Yr Plans• Approve
2013 T R t
3 mo.
Planning Report Prep.
11/19/13 Workshop
d l
2/20/14 Annual Mtg
– 2013 Trans. Reports – 2014 Study Plans
2013 Planning CycleStudy Plans Dev.• SPG Study Results• Future Study Needs
WestConnect Economic Study Request of TEPPC
Coordination / collaboration withCoordination / collaboration with Subregional Planning Coordination Group (SCG)
Western RMR TransmissionPlanning Stakeholder MeetingPlanning Stakeholder Meeting
2013 Transmission Planning Studies
Jim HirningJim HirningTransmission Planner
Loveland, CO
June 25, 2013
1
,
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• Include existing and planned facilities• Ensure adequate reactive resources
2
CCPG
Colorado Coordinated Planning Group
Eight Member Utilities
B i El t i P C ti• Basin Electric Power Cooperative• Black Hills Corporation• Colorado Springs Utilities• PacifiCorp• PacifiCorp• Platte River Power Authority• Public Service Company of Colorado (Xcel
Energy)gy)• Tri-State Generation & Transmission Assoc.• Western Area Power Adminstration-RMR
3
CCPG
Yellowtail
Buffalo WyodakCCPG Footprint
Rapid City(DC Terminal)
Thermopolis
Buffalo Wyodak
Osage
Lange
Stegall(DC Terminal)
Dave Johnston
Laramie River
Jim Bridger
CasperRiverton
Spence
Platte
Sidney(DC Terminal)
Archer
Jim Bridger
AultFlaming Gorge Hayden
VernalT A hl
Pawnee
CraigFt. St. Vrain
Story
Meeker
Rifle
Bonanza
Vernal
Cherokee
N .Yuma
BurlingtonBig Sandy
Gore Pass
To Ashley
To Upalco
To Mona
Lost
Lamar(DC Terminal)
MontroseCurecanti
Midway
Boone
Poncha
Malta
ComancheCanyon
Hesperus
Trinidad
To Shiprock
To San Juan To Glade Tap
2011 NERC/WECC Compliance Report
Performed Annually Area Studied Colorado Wyoming Western NebraskaWestern Nebraska Western South Dakota
5
Purpose
Evaluate the steady state post-contingency response of the Integrated Systemresponse of the Integrated System
Evaluate transient and voltage stability Identify problem areas due to system load Identify problem areas due to system load
growth Meet NERC/WECC Transmission Planning
St d dStandards
6
Study Procedure
CCPG Compliance Study
Cases To Be Examined• 2018 Heavy Summer• 2018 Light Autumn• 2018 Light Autumn
System Intact Criteria100% C ti R ti L di• 100% Continuous Rating Loading
• 0.95 p.u. – 1.05 p.u. Voltage
C ti A l i C it i Contingency Analysis Criteria• 100% Continuous/Emergency Rating Loading• 0.90 p.u. – 1.10 p.u. Voltage
7
Study Procedure
CCPG LRPG Study
Cases To Be Examined• 2023 Heavy Summer• 2023 24 Heavy Winter• 2023-24 Heavy Winter• 2023 Light Autumn
System Intact Criteria System Intact Criteria• 100% Continuous Rating Loading• 0.95 p.u. – 1.05 p.u. Voltage
Contingency Analysis Criteria• 100% Continuous/Emergency Rating Loading
0 90 1 10 V lt
8
• 0.90 p.u. – 1.10 p.u. Voltage
Questions
Any Questions or Comments?
9
2013 Transmission Planning Studyg S y
Jason ParkerPlanning Engineer
June 20, 2012
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 Evaluate the load serving capability of the integrated system while preserving TOT path capacities.
S h d l d i i i W Scope, schedule and prioritize Western transmission and substation system projects for inclusion in the Capital Improvement Plan (CIP).Plan (CIP).
Process
Loads
•Request and receive load data from network customers•Jan‐March 2013
•Request and receive load data from network customers•Jan‐March 2013
Power Flows
•Develop base cases•March‐April 2013•Develop base cases•March‐April 2013
Projects
•Analyze power flow results•Study solutions•ReportM J l
•Analyze power flow results•Study solutions•ReportM J l j •May‐July 2013•May‐July 2013
Inclusion in
•Preliminary Scope and Estimates•Aug‐November 2013•Preliminary Scope and Estimates•Aug‐November 2013
Capital Improvement Plan
g 3g 3
•Present study results at Quarterly Stakeholders Meeting•Present study results at Quarterly Stakeholders Meeting
Stakeholders
g•December 2013
g•December 2013
Process IImprovementsAnnual Study Guidelines created and i l d f h R k M i R i d 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 Study focused on Network Customer load
forecasts and scheduled system improvements.
Alternate study focused on Network Customer load and no system Customer load and no system improvements.
Stud CriteriaStudy CriteriaCases selected to study a shoulder season and a heavy/light summer.
WECC approved cases:pp 2016 Light Spring 2018 Heavy Winter 2023 Heavy Summer
2016 Light Spring case study will include post transient and transient analysis where applicable and study without scheduled system additions.
Stud CriteriaStudy CriteriaCriteria
System Intact0.95 p.u. – 1.05 p.u. Voltage100% Continuous Loading Rateg
Contingency0.90 p.u. – 1.10 p.u. Voltage100% Continuous Rating or Emergency 100% Continuous Rating or Emergency Limit
Contingency Analysis N‐1, N‐2
Monitored integrated system and adjacent area.
Transformer emergency rating‐120% of normal Transformer emergency rating 120% of normal thermal rating.
Stud CriteriaStudy CriteriaStress Levels applied to cases:
TOT 3, WECC Path 36
1680 MW North to South‐2016 LS Only
TOT 5, WECC Path 39
1675 MW West to East 2018 HW Only 1675 MW West to East – 2018 HW Only
TOT 2A, WECC Path 31
690 MW North to South‐2023 HS Only
Stud CriteriaStudy CriteriaStudies 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 b di d i i i d d appear may be studied as a sensitivity study and
result in a change of the corrective action plan and Capital Improvement Plan.p p
Stud CriteriaStudy CriteriaSensitivity Studies and areas of interest:
Big Horn Basin 115 & 69 kV system Fort Morgan area Midway area Midway area
Upcomin E entsUpcoming Events Analysis of studies. Analysis of studies.
Compilation and ranking of proposed capital budget items.capital budget items.
Desert Southwest and Rocky Mountain Region combined 2013 Ten Year Annual Region combined 2013 Ten Year Annual Report.
Sensitivity Studies Sensitivity Studies
Questions?
WesternWesternRocky Mountain Region
FY13FY13Capital Transmission Line
Program OverviewPrepared by
Randy Medicine Bear25 June 2013
og a O e e
PICK SLOAN MAJOR CAPITAL TRANSMISSION PROJECTS
Transmission Lines
•Basin-Lovell 115-kV uprate•Beaver Creek-Sterling 115-kV Rebuild•Box Butte-Dunlap 115-kV Rebuild•Estes-Flatiron 115-kV Rebuild•Gem City-Snowy 115-kV Rebuildy y•Granby-Windy Gap 138/69-kV Rebuild-Trust•Lusk-Podolak 69-kV rebuild•Line Switch Replacements- Eastern Colorado, Wyoming, Nebraska•Sidney-Peetz-Sterling 115-kV Rebuild•South Woodrow Tap 115-kV line switch replacementp p•Torrington-Goshen uprate to 115-kV•Wray-Wray Tap•Yellowtail Power Plant Tie Lines Reroute
•Transmission Line Programsg•Central Wyoming Infrastructure Improvement Program (CWIP)•Lovell-Yellowtail
PICK SLOAN TRANSMISSION LINESPICK SLOAN TRANSMISSION LINES
• Basin-Lovell 115-kV uprateR d t 35 il f li ith 477 ACSS d dd h d fib ti g d i• Reconductor 35 miles of line with 477 ACSS and add one overhead fiber optic ground wire
• Estimated Project Cost: $ 4,000K ISD 2014
• Gem City-Snowy 115-kV Rebuild1 2 miles Wood H Rebuild @115 kV• 1.2 miles, Wood H Rebuild @115-kV
• Estimated Budget: $ 565k ISD 2014
• Lusk-Podolak (Lusk Rural) 69-kV Rebuild• 3 miles Wood Rebuild @ 69-kV• 3 miles, Wood Rebuild @ 69-kV
• Estimated Budget: $3,900k ISD 2014
• Granby Pumping Plant-Windy Gap 138/69-kV Rebuild12 il D bl Ci i S l• 12 miles, Double Circuit Steel
• Estimated Budget: $18,800k ISD 2015
PICK SLOAN TRANSMISSION LINESPICK SLOAN TRANSMISSION LINES
• Estes-Flatiron115-kV Rebuild16 il h D bl Ci it St l W d H R b ild @115 kV• 16 miles each, Double Circuit Steel or Wood-H Rebuild @115-kV
• Estimated Budget: $19,300k ISD 2016
• Goshen-Torrington Rebuild (PVVC)• Rebuild 6 5 miles at 115-kV• Rebuild 6.5 miles at 115-kV
• Estimated Budget: $ 2,080 ISD 2016
• Box Butte-Dunlap 115-kV Rebuild• 16 miles, Wood H Rebuild @115-kV
• Estimated Budget: $1,7000k ISD 2017
• Beaver Creek-Sterling 115-kV Rebuild
• 36 miles Wood H Rebuild @ 230-kV operate @ 115-kV• 36 miles, Wood H, Rebuild @ 230-kV, operate @ 115-kV• Estimated Budget: $16,600k ISD 2017
PICK SLOAN TRANSMISSION LINESPICK SLOAN TRANSMISSION LINES
• Sidney-Peetz-Sterling 115-kV Rebuild40 il W d H R b ild @230 kV t @ 115 kV• 40 miles, Wood H Rebuild @230-kV, operate @ 115-kV
• Estimated Budget $17,450k ISD FY18
PICK SLOANPICK SLOAN115-KV LINE SWITCH REPLACEMENTS
•Eastern Colorado Western Nebraska•Eastern Colorado, Western Nebraska•Julesburg, Kersey Tap, Chappell
•Estimated Budget: $1,305k ISD FY13
•South Woodrow TapSouth Woodrow Tap•Estimated Budget: $350k ISD FY13
•Wyoming•Guernsey Rural, Worland, Refinery, Morrill Countyy , , y, y
•Estimated Budget: $1,538k ISD: FY13
CENTRAL WYOMING IMPROVEMENT PROGRAM OVERVIEWCENTRAL WYOMING IMPROVEMENT PROGRAM OVERVIEW
Alleviate TOT 4B ConstraintsConstraints Load growth in the
Badwater area Accommodate Network
Resource at the DJ esou ce at t e Jcutplane to serve Cheyenne Customer transmission
service request (load) + 150 MW + 150 MW
Reliability >10% poles rejection
rate in the last two pole test reports
R b ild Rebuild Transmission
Dave Johnston-Casper-Alcova-AlcovaMiracle Mile
CENTRAL WYOMING IMPROVEMENT PROGRAM SUMMARYCENTRAL WYOMING IMPROVEMENT PROGRAM SUMMARY
6 Rebuilds: Alcova-Miracle Mile
West: Build 230-kV Transmission Line, operate at 115-kV $22,300k ISD FY16 ROW exists
East: Re-Build 115-kV Transmission Line $19,400k ISD FY20East: Re Build 115 kV Transmission Line $19,400k ISD FY20
Alcova-Casper Rebuild North 230- kV $22,300k ISD FY20 Rebuild South 115-kV $27,500k ISD FY17
Casper (PACE)-DJ Tap North Rebuild 115-kV $16,900k ISD FY19
Casper -DJ Tap South Rebuild 115-kV $14,750k ISD FY19
TOTAL $122.8M*Beyond the rate window
115-KV PLATTE VALLEY VOLTAGE CONVERSION SUMMARY115 KV PLATTE VALLEY VOLTAGE CONVERSION SUMMARY
Goshen Substation 230/115-kV (DJ-Stegall) $11,595k ISD FY15 Rebuild Goshen to Torrington line at 115-kV $ 2,080k ISD FY16
LOVELL-YELLOWTAIL PROGRAMLOVELL YELLOWTAIL PROGRAM
Phase 1 –National Park Service (NPS) Phase 2 – Area outside of the NPS and the Crow Reservation Phase 3 – Crow ReservationPhase 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 eachg
LOVELL-YELLOWTAIL REBUILDSLOVELL 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: FY13Status: Tline Construction Complete Evaluation of access road reclamation ongoing Status: Tline Construction Complete. Evaluation of access road reclamation ongoing
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: FY14g $ , Status: The #2 line has been rebuilt and is in-service. Contractors recently began wrecking-
out the #1 line.
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: FY15 Negotiations Ongoing
CRSP TRANSMISSION LINE PROJECTSCRSP TRANSMISSION LINE PROJECTS
Pleasant View 24.9-kV Line Replacement Budget: $1,556k FY15 Hayden-Vernal 115-kV Uprate Budget: $8,987k FY16