COMMON USE SYSTEM
TRANSMISSION COORDINATION
& PLANNING COMMITTEE
NETWORK OPERATING COMMITTEE
Q2 MEETING
August 16, 2011
Black Hills Power Service Center
Rapid City, SD
TCPC Meeting Policies
• FERC Standards of Conduct
• Anti-Trust Policy
• Confidentiality
2
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.
3
BHC Transmission Planning
Department Updates
• BHP 10 Year Transmission Plan (230 kV+)
–
–
–
–
4
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)
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
5
CUS
BEPW
PAC
WAPA
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
6
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
2011 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 Category D outages evaluated
• Validate committed projects/recommend additional
solutions
7
2016 Summer Peak Baseline Case
•
•
•
•
Starting Case: WECC 16hs2a1p.sav
CUS Load: 996.9 MW*
CUS Generation: 1399 MW*
CUS Power Injections: -398.7 MW
*Includes generating plant station service load
**Gross output at plant terminals
8
2016 Winter Off-Peak Baseline Case
•
•
•
•
Starting Case: WECC 16hw2a1p.sav
CUS Load: 779 MW*
CUS Generation: 1209 MW**
CUS Power Injections: -422.7 MW
*Includes generating plant station service load
**Gross output at plant terminals
9
2022 Summer Peak Baseline Case
•
•
•
•
10
Starting Case: 2022HS DEEP Study Case
CUS Load: Unavailable
CUS Generation: Unavailable
CUS Power Injections: Unavailable
2018 Winter Off-Peak Baseline Case
•
•
•
•
Starting Case: WECC 18hw1sa1p.sav
CUS Load: 779.3 MW*
CUS Generation: 1235 MW**
CUS Power Injections: -447.7 MW
*Includes generating plant station service load
**Gross output at plant terminals
11
Steady State Study Plan
• Simulate typical scenarios:
 RCDC Tie: 200 MW in both directions & blocked
Prior + Forced Outages
69 kV system normal open configurations
• Validate planned projects
 St. Onge substation addition
 Lookout-Spearfish-Yellowcreek 69 kV rebuild
 Lookout-Sundance Hill #1 69 kV rebuild
 Sundance Hill-Whitewood 69 kV rebuild
Osage reactive voltage support requirements
12
Dynamic Stability Study Plan
• Simulate typical scenarios:
 RCDC Tie: 200 MW in both directions & blocked
Worst Case Prior + Forced Outages
69 kV system normal open configurations as
necessary
• Validate proposed frequency deviation criteria
changes
13
Questions
14
Comments / Suggestions
Wes Wingen
wes.wingen@blackhillscorp.com
(605) 721-2268
Eric Egge
eric.egge@blackhillscorp.com
(605) 721-2646
15