wapa rmr stakeholder meeting agenda june2010 - oati · transmission planning stakeholder meeting...
TRANSCRIPT
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 29, 2010 – 10:00 am to 12:00 pm MDT
1) 10:00 am .......................................... Introduction of Attendees \ Finalize Agenda (Bob Easton)
2) 10:05 am ................. Overview of the Western’s Process for FERC Order No. 890 (Debbie Farm)
3) 10:15 am ........................................................... West Connect Transmission Update (Bob Easton)
4) 10:30 am ............................................................... Transmission Planning Studies (Jim Hirning)
5) 11:00 am ............... Review of 2010 Transmission Planning Study Scope & Process (Jon Fidrych)
6) 11:30 am ................................................................... Capital Improvement Plan (Roy Gearhart)
7) 11:45 am ...................................................... Stakeholder Input / Open Discussion (Bob Easton)
8) 11:55 am ............................................... Next Meeting Date and Closing Remarks (Bob Easton)
9) 12:00 pm ....................................................................................................................... Adjourn
Western Rocky Mountain Region Planning
Stakeholder Meeting(Western OATT Attachment P)
June 29, 2010
Reason For Today’s Meeting• Help Western achieve its transmission
planning process objectives as well as to adhere to the mandates of the Federal Energy Regulatory Commission Order No. 890
Meeting Purpose• Allow Western to maximize its understanding of its
customers’ forecast needs for Western’s transmission system
• Opportunity for our customers to be informed about Western’s transmission system planning process and provide input
• Review transmission plans
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, 2009
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OATT Revision• Information regarding OATT Revision is
posted at the following URL: http://www.wapa.gov/transmission/oatt.htm
• Tariff documents are posted on OASIS at the following URL: http://www.oatioasis.com/WAPA/WAPAdocs/WAPA-Tariff-Docs.htm
• Tariff REDLINE Documents: http://www.oatioasis.com/WAPA/WAPAdocs/WAPA-OATT-REDLINE-Effective-2009-1201.pdf
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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.
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Planning Process
• Types of Studies Performed
• NERC/WECC Reliability Studies
• Sub-regional Coordination (CCPG)
• 2010 Ten Year Capital Program
• Generator Interconnection & Transmission Service Requests
Western’s Service Territory
Types of Planning Studies» Reliability Studies – Meet NERC/WECC standards and
coordinate through CCPG
» Sub-regional Coordinated Studies – identify congestion and overloads and address integration of new resources and loads
» Western invites the submittal of transmission study requests from stakeholders for review and discussion
» Western’s point of contact for study requests is [email protected].
June 29, 2010
WestConnect Transmission Planning Update
Bob Easton890 Stakeholder Meeting
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WECCSubregional Planning GroupsMajor Transmission Facilities
ColumbiaGrid
Northern Tier Transmission Group (NTTG)
Northwest Transmission Assessment Committee (NTAC) that are not part of ColumbiaGrid or NTTG
WestConnect (SWAT, CCPG & Sierra)
California ISO
California Transmission Planning Group that are not part of CAISO
Other Facilities
WestConnect Planning Footprint
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Parties to WestConnect STP Project Agreement
Arizona Public Service Company
Basin Electric Power Cooperative
Black Hills Corporation
El Paso Electric Company
Imperial Irrigation District
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
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WestConnect Subregional Planning Groups
ColoradoCoordinated
PlanningGroup
SouthwestArea
Transmission
CCPG
SWAT
SSPGSierra Subregional Planning Group
CCPG, SSPG and SWAT are technical planning work groups within the WestConnect Footprint•Coordinate Information for use by all study participants
•Define subregional study plans, provide study resources, and perform studies
•Provide forum for coordination and peer review of planning studies and 10-year plans
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2010 SCOPE of Work
Manage Annual Planning Process
Update the 10-Yr Planning Documents
Coordinate Annual TTC/ATC Workshop
Partipcate in WECC TEPPC
Coordinate WestConnect-wide 2020 HS Base Case
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2010 SCOPE of Work
Coordinate with SCG (Result of DOE FOA)
Attend CCPG/SWAT/SSPG Joint Meeting
Maintain TPM Database
Re-Issue RFP for Consultant Services
Budget of $393,000
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Western Interconnection Planning Process
Coordination Among STPs
SCG Process
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ColoradoCoordinated
PlanningGroup
SouthwestArea
Transmission
CCPG
SWAT
SSPGSierra Subregional
Planning Group
Planning Coordination
Stakeholder Study
Request
PMC
Subregional Planning
WCSC
WestConnect Steering
Committee
Inte
rnal
TEPPC / TAS and
Neighboring SPGs
Ext
ern
al
3 mo.
WestConnect Synchronized Planning Cycle
2010 Planning Cycle Planning Report Prep.
2011 Planning CycleStudy Plans Dev.
TEPPC Economic Study ResultsFor WestConnect Footprint
WestConnect Economic Study Request of TEPPC
11/10/10 Workshop
• STPG Study Results• Future Study Needs
2/16/11 Annual Mtg
• Publish 10 Yr Plans• Approve
– 2010 Trans. Reports – 2011 Study Plans
Commence coordination / collaboration with Subregional Planning Coordination Group (SCG)
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Western RMR TransmissionPlanning Stakeholder Meeting
2009 Transmission Planning Studies
Jim HirningTransmission Planner
Loveland, CO
June 29, 2010
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
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CCPG
Colorado Coordinated Planning Group
Eight Member Utilities
• Basin Electric Power Cooperative• Black Hills Corporation• Colorado Springs Utilities• PacifiCorp• Platte River Power Authority• Publice Service Company of Colorado (Xcel
Energy)• Tri-State Generation & Transmission Assoc.• Western Area Power Adminstration-RMR
CCPG Footprint
Sidney(DC Terminal)
Stegall(DC Terminal)
Rapid City(DC Terminal)
Yellowtail
Dave Johnston
Laramie River
Pawnee
Archer
Jim Bridger
Craig
Comanche
Thermopolis
Buffalo
CasperRiverton
Wyodak
Ft. St. Vrain
Ault
Story
Flaming Gorge
Lost Canyon
Hesperus
Lamar(DC Terminal)
Hayden
Meeker
Rifle
Bonanza
Vernal
Osage
Lange
Spence
Platte
MontroseCurecanti
Cherokee
N .Yuma
Trinidad
Burlington
To Shiprock
To San Juan To Glade Tap
Midway
Big Sandy
Boone
Gore Pass
Poncha
Malta
To Ashley
To Upalco
To Mona
2009 NERC/WECC Compliance Report
Performed Annually
Area Studied Colorado
Wyoming
Western Nebraska
Western South Dakota
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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
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Study Procedure
Cases Examined 2013-2014 Light Winter 2013-2014 Heavy Winter 2019-2020 Heavy Winter
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 p.u. – 1.10 p.u. Voltage
Results
2014 Heavy Winter Dave Johnston Tap-South to
Refinery Tap 115 kV line• Overload upon Casper (PACE)
230/115 kV Transformer Outage
Bridgeport, Gering, McGrew, Wildcat and Emigrant• Low voltage ( < 0.90 p.u.) for Stegall
115 kV Bus Outage
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Results (cont’d)
2020 Heavy Winter
Craig-Rifle 230 kV Line• Overload upon Craig-Ault and Craig-
CB Tap 345 kV lines tripping
Torrington Substation• Low Voltage upon Stegall 230 kV Bus
outage
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Results (cont’d)
2020 Heavy Winter (cont’d)
Bridgeport, Gering, McGrew Wildcat and Emigrant• Low voltage for Stegall 115 kV Bus
Outage
Cheyenne 230/115 kV Transformer• Overload for Archer 115 kV Main Bus
Outage
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Future Plans
2010 NERC/WECC Compliance Report Cases:
• 2014 Light Autumn
• 2015 Heavy Summer
• 2020 Heavy Summer
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Questions
Any Questions or Comments?
Overview ofRocky Mountain Region’s
Capital ProgramPrepared by
Roy Gearhart, J5640June 29, 2010
Capital Investment Plan
The purpose of the Capital Investment Program Plan (CIP) is to present RMR’s capital investment plan, to provide a mechanism for customer collaboration, and to clearly describe challenges, goals, strategies, and measurements for the Plan.
Capital Investment Plan
The CIP contains all known capital projects in RMR covering a ten year period starting with the current fiscal year.
The CIP was first published in FY2004.
Capital Investment Plan
All Capital projects involving RMR are included regardless of funding source or power system.
Funding Sources include appropriations, trust, reimbursable, advanced customer funding and revolving.
Capital Investment PlanHow frequently is the CIP updated?
The CIP is published twice a year. In November, the DRAFT (FY20XX.1) is published
and distributed both internally and to RMR’s customers soliciting feedback and input.
In March, the Final (FY20XX.2) is published and distributed both internally and to RMR’s customers
Capital Investment Plan
What is the process for creating the CIP each year?
In October the CIP group sends a notice to all RMR managers requesting information on new projects and updates to existing projects.
This information is used to update the CIP documents.
Capital Investment PlanWhat is the process for creating the CIP
each year?
By late October, the documents are internally reviewed and adjusted.
The Rates office is provided a copy to perform analysis of the Transmission Rate projections.
By mid November, the first distribution occurs.
Capital Investment PlanWhat is the process for creating the CIP
each year?
Customer comments are requested by mid January.
In mid January, the CIP group begins editing the final version including customer comments
Capital Investment Plan
What is the process for creating the CIP each year?
Mid February, the final CIP is provided to the Finance office for budget formulation
March - Final distribution!
Capital Investment PlanHow is the CIP used?
The CIP is used by RMR managers and Finance personnel for managing project budgets and execution.The Capital Investment Committee uses the CIP to review and adjust the region’s capital program priorities on a monthly basis.
Capital Investment Plan
How is the CIP used?
RMR Finance Office uses the CIP to formulate the budget.
The Rates office uses the CIP to update Transmission Rates studies.
Capital Investment PlanHow is the CIP used?
The RMR customers use the CIP to gauge the region’s performance and accomplishments.The Program managers use the CIP as the primary tool to ensure efficient execution of the capital program for the Region.
On GoingMajor Capital Projects
Cheyenne-Miracle Mile Rebuild & Ault-Cheyenne Rebuild & 230-kV Subs
Ault Stage 07 – transformer installationFront Range Transmission Improvements
Erie-Hoyt RebuildDixon Creek – Horse ToothLongmont NW - Fordham
Granby-Windy Gap Rebuild
On GoingMajor Capital Projects
Hayden KZ1A transformer replacement
Green Mountain control building
Granby Pumping Plant Transformer rebuilds
OPGW (fiber) projects
Platte Valley Voltage Conversion
The objective of the Platte Valley Voltage Conversion Project is to convert the operating voltage of the 34.5-kV transmission lines and related facilities between Lingle Substation and Gering Substation to 69-kV.
The lines were rebuilt in the early 90’s to 69-kV standard.
Platte Valley Voltage Conversion
Scope:Lingle Substation: Install a 115/69-kV 40 MVA transformer and associated equipment.
Torrington Substation: Install a 69/34.5-kV 50 MVA transformer and associated equipment.
Sievers Rural Tap: Install a 69/34.5-kV 25 MVA transformer and associated equipment.
Construct eleven miles of new 69-kV line between East Morrill Tap and Sievers Rural Tap.
Platte Valley Voltage Conversion
Scope (cont):Torrington Rural Tap: Replace transformer and rebuild high side for 69-kV.
Henry Tap: Replace transformer and rebuild high side for 69-kV.
Village of Morrill Tap: Make necessary modifications to operate existing dual winding transformer at 69-kV.
Connect the Town of Lingle Tap to the Limestone-Lingle 34.5-kV line.
Platte Valley Voltage Conversion
Scope (cont):
Planned ISD: FY2015
Current Status: Not planned to start until FY2012. System Studies updated every two years. Preliminary study and planning to begin in 2011.
Lovell-Yellowtail Rebuilds
• Scope: Project to rebuild to LV-YT 115-kV #1 and #2 lines. Each are 47 miles long.
– Initiated due to age and condition
– RMR intends to increase capacity across Yellowtail South constraint path.
– Goal to have sufficient capacity to carry entire Yellowtail generation on either line.
Lovell-Yellowtail Rebuilds
Scope: Project to rebuild to LV-YT 115-kV #1 and #2 lines. – The lines will be rebuild at 115-kV with 795
ACSS conductor.
– Line rating will be 330 MW each
– Project to be constructed in two Phases
Lovell-Yellowtail Rebuilds
• Scope: Project to rebuild to LV-YT 115-kV #1 and #2 lines.
– Project Start: 2007
– Environmental EA: 2010
– Design: 2010
– Phase 1 construction contract award: 2011
– Phase 2 construction contract award: 2012
– Construction completion: 2013 or early 2014
Central Wyoming Transmission Improvement Project - CWTIP
The CWTIP consist of six 115-kV transmission lines to be rebuild due to address age and condition issues.
– The six lines are: Alcova-Miracle Mile West, Alcova-Miracle Mile East, Alcova-Casper North, Alcova-Casper South (PACE), Casper-Glendo North (to the DJ tap), and Casper (PACE)-Glendo South (to the DJ tap)
– Five of the six lines have exceeded the expected 40-year life span with the sixth line reaching 40 years of service in 2011.
Central Wyoming Transmission Improvement Project - CWTIP
The CWTIP consist of six 115-kV transmission lines to be rebuild due to address age and condition issues. (cont.)
– Old wood pole structures have rising rejection rates
– Maintenance can no longer climb some poles due to shell rot. Almost all work is done by bucket truck.
– Ever increasing maintenance effort is required, increasing O&M costs
– Concern of increase outages with age.
Central Wyoming Transmission Improvement Project - CWTIP
The project would be constructed in six phases.
• Phase I : Construct 24.1-mile Alcova-Miracle Mile West transmission line. Construction planned for 2015.
• Phase II : Construction 28.6-mile Alcova-Casper South transmission line. Construction planned for 2016
• Phase III: Construct 28-mile Casper-Glendo South transmission line. Construction planned for 2017.
• Phase IV: Construct 36.1-mile Casper-Glendo North transmission line. Construction planned for 2018.
• Phase V : Construct 28.6-mile Alcova-Casper North transmission line. Construction planned for 2019.
• Phase VI : Construct 24.1-mile Alcova-Mile East transmission line. Construction planned for 2020.
Future Transformer Projects
• Lusk KX1A – 5 MVA – 2011
• Weld KV2A – 150 MVA – 2012
• Cheyenne KV2A – 250 MVA -2014
• Hayden KZ2A - 250 MVA - 2014.
• Curecanti KZ2A addition - 2016
• Flaming Gorge KY2B - 250 MVA – 2018
Fort Morgan West Substation115-kV Shunt Capacitor Bank
Project will remove the current mobile shunt capacitor bank and install a permanent 15MVAR 115-kV Shunt with 115-kV bay addition.
Estimated Cost : $1.3M
Planned ISD: 3rd Qtr FY2011
Current Status: Design in progress; purchasing equipment
Frenchman Creek Substation -115-kV Shunt Capacitor Banks
Project Scope: Install a permanent 8.1 MVAR 115-kV Shunt Capacitor Bank with 115-kV breaker addition.
• Estimated Cost : $1.3M
• Planned ISD: 3rd Qtr FY2011
• Current Status: Design in progress; purchasing equipment
Sidney Substation -115-kV Shunt Capacitor Banks
Project Scope: Install a permanent 15 MVAR 115-kV Shunt Capacitor Bank with 115-kV breaker addition.
• Estimated Cost : $1.3M
• Planned ISD: 3rd Qtr FY2011
• Current Status: Design in progress; purchasing equipment
Estes-FlatironProject Scope:
This project is to rebuild the two 115-kV lines, about 16 miles each, between the Estes and Flatiron Switchyards.
• Rebuild due to age and condition
• Improve the ROW to help with vegetation management criteria.
• Improve Maintenance access to structures.
Current Status: Preliminary scoping
Craig-Rifle 230-kV
Project Scope: Increase current limit on line to a minimum of 1600 amps.
• Replace 230-kV disconnect switches and jumpers at Rifle Substation.
• Reconductor four spans of t-line into Rifle.• Reconductor two spans of t-line into Craig. • Replace CT’s at Craig.
• Planned ISD: 3rd Qtr FY2012• Current Status: Preliminary Planning
Thank You
Any Questions