Common Use System
Q1 Meeting, April 06, 2016
Black Hills Power Service Center
Rapid City, SD
6/27/2016
TCPC Meeting Overview
•Introductions
•Meeting Policies
•Background
•10 Year Transmission Plan
•Review 2015 Study Results
•2016 Study Scope & Data Request
•Stakeholder Input and Questions
•Next Steps
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TCPC Meeting Policies
FERC Standards of Conduct
• The FERC Standards of Conduct state that Transmission Function Employees
are prohibited from disclosing non-public Transmission Information unless
they disclose it on the OASIS. Also, Transmission Function Employees and
Shared Employees are expressly prohibited from disclosing non-public
information to Energy or Marketing Affiliates.
Anti-Trust Policy
• It is the committee’s policy to comply with all state and federal anti-trust laws.
One objective of the TCPC is top promote or enhance competition. Careful
attention should be paid to any discussions regarding you or your competitors
prices, allocation of markets, customers, or products, limiting production, and
excluding dealings with other companies.
Confidentiality
• Certain information may be protected as confidential due to Standards of
Conduct concerns or because it is classified as Critical Energy Infrastructure
Information. Otherwise, it should be on the OASIS. Committee members
agree not to share committee activities with the press and do not discuss
ideas or concerns other than your own in a public forum.
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Background: Transmission Planning
• The process of evaluating the transmission system to identify transmission
facilities required to deliver existing and future generating resources to existing
and future customer loads while balancing reliability, societal impact and cost.
Major inputs to the process:
• Time frame of interest (5, 10, 20+ years)
• Load forecasts (existing + future growth scenarios)
• Generation levels (serve local load vs. off-system sales)
• Generation types (thermal, hydro, wind, solar, etc.)
• Planned projects (local and regional)
• System disturbances (consider all relevant outages)
• Reliability criteria (the measuring stick for adequate transmission system
performance)
• Transmission system commitments (capacity availability)
• Local, state, and federal regulatory requirements
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Background: TCPC
Transmission Coordination & Planning Committee (“TCPC”)
• Facilitated by BHP Transmission Planning Dept.
• Primary focus on the CUS and surrounding transmission system
• Coordinates efforts with CCPG
• FERC 890, reliability, project evaluation
• Annual study cycle
• Open to all interested stakeholders
• Publishes Local Transmission Plan (“LTP”)
• http://www.oatioasis.com/BHBE/index.html
− Select “Transmission Planning” folder
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Common Use System and Study Area
MONTANA
WYOMING
SHERIDAN
TONGUE
RIVER
DRYFORK
CARR
DRAW
WYODAK
BUFFALO
BARBER
CREEK
PUMPKIN
BUTTES
WYGEN1
WYGEN2
WYGEN3
BILL DURFEE
YELLOW
CREEK
HUGHES
DONKEY
CREEK
LOOKOUT
OSAGE
SOUTH
RAPID
CITY
RENO
TECKLA
LANGE
MINNEKHATA
DC TIE
WESTHILL
ANTELOPE
S DAKOTA
NEBRASKA
YELLOWCAKE
LATIGO
CASPER
SPENCE
WINDSTAR
230 KV (EXISTING)
230 KV (FUTURE)
SUBSTATION
GENERATOR
DAVE
JOHNSTON
STEGALL
6/27/2016
CUS
BEPW
PAC
WAPA
6
2016 10 Year Transmission Plan
Project
ISD
Status
Teckla-Osage 230kV Line (BHP)
2016
In Construction
Osage-Lange 230kV Line (BHP)
2016
In Construction
Second Yellow Creek 230/69kV Transformer
(BHP)
2018
Planned
Bill Durfee 230kV Substation (PREC)
2016
In Construction
South Rapid-West Hill 230kV Line Rebuild
(BHP)
2019
Planned
Wyodak Transformation
TBD
Conceptual
Osage Transformation
TBD
Conceptual
6/27/2016
7
2015 LTP Results &
Recommendations
Yellow Creek Transformer Overload
 Planned project to continue win an
expected ISD of 2018
Wyodak Transformer Overload
 Solution options continue to be
evaluated/discussed
Osage Transformer Overload
 Study to investigate solution options is in
progress
Lange and South Rapid Transformer
Overloads
 Continue to monitor transformer loading
 Independent study to be initiated in 2016
6/27/2016
8
2015 LTP Results & Recommendations
Continued
Lange-South Rapid, Lookout-Lange, and Wyodak-Osage 230kV
lines cannot support the Rapid City load with the RCDC Tie at
200MW W-E following N-1-1 contingencies.
 Revise RCDC tie RAS to include identified N-1-1 contingencies.
Wyodak Area Generator Instability (Under Extreme Events)
 Discuss options for implementing Out-of-Step relaying
New RCDC RAS
 Independent study to be completed in 2016
6/27/2016
9
2016 LTP Study Scope
2018HS (Peak Study, Year 2)
• Power Flow, Voltage & Transient Stability
2017-2018LW (Off-Peak Study, Year 1-5)
• Power Flow, Voltage & Transient Stability
2021HW (Peak Study, Year 5)
• Power Flow, Voltage & Transient Stability
as needed
2026HS (Peak Study, Year 10)
• Power Flow & Voltage Stability as
needed
Observe NERC/WECC planning criteria
Evaluate P0 thru P7 Contingencies
6/27/2016
10
Sensitivities To Consider
2018HS (Peak Study, Year 2)
• Increase RC Load Linearly 10%
− Bidirectional stress RCDC Tie
2017-2018LW (Off-Peak Study, Year 1-5)
• Load Reduction Linearly from SCADA
Data
− Bidirectional stress RCDC Tie
2021HW (Peak Study, Year 5)
• Retire Wyodak
− Delay Planned Projects
– Bidirectional stress RCDC Tie
2026HS (Peak Study, Year 10)
• Stress the RCDC Tie in Both Directions
− Identify additions that may be necessary
for the new RCDC RAS
6/27/2016
11
Requesting Scenarios &
Alternatives
Use CCPG Request Form at any time
Ensures all stakeholder suggestions are
considered
Form will be submitted to CCPG and
directed to the appropriate group
All requests will be acknowledged and
responded to
• http://www.westconnect.com/filestorage/c
cpg_request_form.xls
12
Data Collection
Requested data due: Friday May 02, 2016
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
• Demand requirement + reserves
Reservation Data
• Forecasted monthly transfer values on a
per path basis, including rollover rights
6/27/2016
13
Next Steps
•Approve 2016 study scope
•Complete data requests for load and
resource projections, transmission usage,
study scenario alternatives, etc.
•Compile 2016 study cases and scenarios
•Begin analyses
6/27/2016
14
Next Meetings
Q2 Meeting: Held only if necessary as we evaluate new bi-annual
meeting schedule
Q3 Meeting: Held only if necessary as we evaluate new bi-annual
meeting schedule
Q4 Meeting: (TBD) 9:30-10:30 a.m.
o Review comments to draft LTP report, preferred project
alternatives, planned project status, other regional planning
updates
Additional stakeholder discussions may be held as necessary
6/27/2016
15
Questions
6/27/2016
Comments / Suggestions
Wes Wingen
wes.wingen@blackhillscorp.com
(605) 721-2268
Michael Lundy
Michael.Lundy@blackhillscorp.com
(605) 721-2471
6/27/2016
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