COMMON USE SYSTEM
TRANSMISSION COORDINATION
& PLANNING COMMITTEE
Q1 MEETING
February 16, 2011
Black Hills Power Service Center
Rapid City, SD
TCPC Meeting Policies
• FERC Standards of Conduct
• Anti-Trust Policy
• Confidentiality
2
BHP Transmission Planning
Department Updates
• Transmission System Additions
– Pumpkin Buttes-Windstar 230 kV line in-service
(2010)
– Dryfork Plant commercial operation (June 2011)
– RC South 230 kV 100 MVAR capacitor online (2010)
– Second Osage 69 kV 10 MVAR capacitor online
(2010) and Osage plant operations suspended
Refer to BHBE OASIS for more information
3
BHP Transmission Planning
Department Updates
• Transmission System Additions cont….
– Wyodak 230:69 kV 100 MVA XFMR replaced existing
70 MVA unit (2010)
– Lange 230:69 kV 100 MVA transformer replaced with
a 150 MVA unit (2010)
– Whitewood-Sturgis 69 kV line rebuilt
– Sturgis-Lange 69 kV line rebuilt
– Edgemont-Westhill 69 kV line rebuilt (2010)
Refer to BHBE OASIS for more information
4
BHP Transmission Planning
Department Updates
• Generator Interconnection Requests
– BHBE-G7: 200 MW wind NR/ER at Pumpkin Buttes
230kV sub, LGIA executed, construction suspended
– BHBE-G8: 50 MW wind NR/ER on Lange-Lookout
230kV line, LGIA tendered for execution
– BHBE-G9: 250 MW wind NR on Wyodak-Osage
230kV line, SIS complete, FSA tendered
– BHBE-G10: 210 MW wind ER on SRC-Westhill 230
kV line, withdrawn
Refer to BHBE OASIS for more information
5
2010 LTP Results &
Recommendations
– At least 5 MVAR additional capacitive voltage support
at Osage 69 kV recommended prior to 2021.
– LTP recommended commissioning second existing
Belle Creek 69 kV capacitor. Dynamic voltage support
scheduled for 2012 in-service date.
– Modification of Minimum Allowable Frequency
Criterion for Wyodak area suggested (Apply Cat. C
outage criteria to Cat. B outages). Further analysis is
needed prior to implementation.
6
BHC Transmission Planning
Department Updates
• BHP 10 Year Transmission Plan (230 kV)
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Minnekhata 230:69 kV substation (2011)
St. Onge 230:69 kV substation (2014)
Teckla-Osage 230 kV line (2014)
Osage-Lange 230 kV line (2015)
TCPC Overview
• FERC Order 890 – 9 Principles
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Coordination
Openness
Transparency
Information Exchange
Comparability
Dispute Resolution
Regional Participation
Economic Planning Studies
Cost Allocation for New Projects
Local Transmission Plan (LTP) Study Cycle
Quarter
Planning Steps
Data Collection
TCPC Meetings
Q4
Study Scope, Data Collection &
Scenario Development
Open
X
Optional
Q1
X
Technical Study
Q2
X
Closed
Q3
9
Decision & Reporting
X
LTP Study Process
Data Collection, Study Scope and Scenario Development
Load and Resource
Forecast, Point-to-Point
Projections, Demand
Resources
Identify Study Objective,
Define Assumptions,
Develop Study Scope
and Scenarios
TCPC / NOC Input
TCPC = Transmission Coordination and Planning Committee
NOC = Network Operating Committee
As Requested/Needed
WECC and/or SubRegional Entities
Technical Study
Develop Base
Cases and
Perform
Simulations
Identify Mitigation
or Solutions to
Reliability Criteria
Violations
Analyze Results and
Identify Reliability
Criteria Violations
YES
Another
Scenario?
Re-Run
Simulations with
Solutions
TCPC / NOC Input
NO
Document Solutions,
ID Advantages or
Disadvantages to
Each Solution
YES
Reliability
Criteria
Met?
Analyze Results
and ID Reliability
Problems
Sub-Regional Review,
WECC Project Review
Process
NO
Decision
And
Reporting
Identify Best Solution
a.Selection Criteria
b.Advantages/Disadvantages
Prioritize Into Company
Business and Strategic
Plan
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Construction and Rate
Base Support
Trans. Planning &
Coordination
Committee / TP
Publish Report
TCPC / NOC Input
Timing of Other Public Input
Determined by TCPC / NOC
TCPC / NOC Input
Sub-Regional Review,
WECC Project Review
Process
LTP Study Scope
• 2016 (near term) and 2018/2022 (far term)
• Analyze peak and off-peak scenarios
– Power Flow
– Transient Stability
• Use NERC/WECC planning criteria
• Evaluate N-0, N-1, N-2 and N-1-1 scenarios (Category
A-C)
• Worst-case bus outages also evaluated (Category D)
• Validate committed projects/recommend additional
solutions
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COMMON USE SYSTEM
BLACK HILLS / BASIN ELECTRIC / POWDER RIVER
MONTANA
WYOMING
TONGUE
RIVER
LOOKOUT
SHERIDAN
DRYFORK
CARR
DRAW
WYODAK
HUGHES
BUFFALO
BARBER
CREEK
PUMPKIN
BUTTES
WYGEN1
WYGEN2
WYGEN3
DONKEY
CREEK
ST ONGE
(2014)
YELLOW
CREEK
OSAGE
LANGE
2015
RENO
SOUTH
RAPID
CITY
DC TIE
2014
TECKLA
MINNEKHATA
(2011)
WESTHILL
ANTELOPE
S DAKOTA
YELLOWCAKE
LATIGO
CASPER
NEBRASKA
WINDSTAR
230 KV (EXISTING)
230 KV (FUTURE)
SUBSTATION
GENERATOR
DAVE
JOHNSTON
SPENCE
M. MILE
STEGALL
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CUS
BEPW
PAC
WAPA
2016 Baseline Cases
• 2016 Heavy Summer (peak)
–Starting Case: WECC 16hs2a1p.sav
• 2016 Light Winter (off-peak)
–Starting Case: WECC 16hw2a1p.sav
13
2018 / 2022 Baseline Cases
• 2022 Heavy Summer (peak)
–Starting Case: WECC 21hs1a1p.sav
• 2018 Light Winter (off-peak)
–Starting Case: WECC 18hw1sa1p.sav
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Major BHBE Baseline Case
Projects/Additions:
• Minnekhata 230:69 kV substation (all
scenarios)
• St. Onge 230:69 kV substation (all scenarios)
• Teckla-Osage 230 kV line (all scenarios)
• Osage-Lange 230 kV line (all scenarios)
15
Major External Baseline Case
Projects/Additions:
• Energy Gateway Transmission Project
• Arrow Transmission Project (tentatively)
16
Data Collection
• Data request returned by Friday March 18, 2011
• Peak and Off-Peak Load Data by POD
– Monthly demand data for study years is critical
– Monthly demand for 10 year planning horizon is preferred
• Resource Data
– should equal the sum of your load and reserves
• Reservation Data
– Forecasted monthly transfer values on a per path basis
• Scenario Suggestions
– Significant modifications to the base case to be evaluated in uncertainty
scenarios.
– Suggestions will be considered and discussed during the Q2 TCPC meeting.
Q2 Meeting Date/Time: May 2011, TBD
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Questions
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Comments / Suggestions
Wes Wingen
wes.wingen@blackhillscorp.com
(605) 721-2268
Eric Egge
eric.egge@blackhillscorp.com
(605) 721-2646
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