1. Common Use System
Q1 Meeting, April 06, 2016 Black Hills Power Service Center Rapid City, SD
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Welcome to the first Transmission Coordination and Planning Committee stakeholder meeting of 2016.
Meeting materials will be available online, including the presentation, following the meeting. More information on that later in presentation.
9/17/2018

2. 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
I would like to go around the room and have folks introduce themselves and the entity they represent, if any. Then phone.

3. 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.
SOC: 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.
ATP: 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.

4. 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

5. 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”)
Select “Transmission Planning” folder

6. Common Use System and Study Area
WYGEN1
WYGEN2
WYGEN3
S DAKOTA
NEBRASKA
WYOMING
MONTANA
BUFFALO
CASPER
DAVE
JOHNSTON
LOOKOUT
LANGE
WESTHILL
RENO
SHERIDAN
TECKLA
STEGALL
YELLOWCAKE
SOUTH RAPID CITY
YELLOWCREEK
HUGHES
DC TIE
CARR
DRAW
BARBER
CREEK
OSAGE
TONGUE
RIVER
SPENCE
PUMPKIN
BUTTES
DONKEY
WYODAK
WINDSTAR
DRYFORK
MINNEKHATA
ANTELOPE
230 KV (EXISTING)
230 KV (FUTURE)
SUBSTATION
GENERATOR
CUS PAC
BEPW WAPA
LATIGO
BILL DURFEE
(2016)
(2018)
(2019)
9/17/2018

7. 2016 10 Year Transmission Plan
Project
ISD
Status
Teckla-Osage 230kV Line (BHP)
2016
In Construction
Osage-Lange 230kV Line (BHP)
Second Yellow Creek 230/69kV Transformer (BHP)
2018
Planned
Bill Durfee 230kV Substation (PREC)
South Rapid-West Hill 230kV Line Rebuild (BHP)
2019
Wyodak Transformation
TBD
Conceptual
Osage Transformation
Bill Durfee likely in service by the time of meeting.
9/17/2018

8. 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
-Lange Transformer #1 (100MVA) OL occurs following the loss of either Lange Xmrs and the Lange-South Rapid 230kV line
-#T2 OL (150MVA), 25HS 113%, 19HW 112%
-South Rapid Transformer OL (150MVA) occurs following the loss of both Lange 230/69kV transformers
(Both 230/69kV transformer OLs can be mitigated by RC gen)
9/17/2018

9. 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
No scenarios identified overloads on the South Rapid-West Hill 230 kV line following a single N-1-1 outage in the 2015 study cycle. A runback on the RCDC tie to 0MW has been implemented in the new RAS (08/06/2015) mitigating overloading the line. However, the line is tentatively scheduled to be rebuilt in 2019 due to age, and should continue as planned.
The Extreme Event transient stability analysis did show instability following a 15 cycle, 3-phase breaker-failure on adjacent 230kV substations to the Wyodak and Donkey Creek 230kV substations. This was previously identified in the 2014 LTP and Out-of-Step relaying recommended for the Wyodak area generators. Other than the previously mentioned instability issue, there were no other performance violations identified in the transient stability analysis.
9/17/2018

10. 2016 LTP Study Scope 2018HS (Peak Study, Year 2)
Power Flow, Voltage & Transient Stability
LW (Off-Peak Study, Year 1-5)
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
No appreciable changes occurred in BHP to necessitate a Short Circuit Study. Short Circuit Studies will be performed when Wyodak & Osage transformation studies define the solution option.
9/17/2018

11. Sensitivities To Consider
2018HS (Peak Study, Year 2)
Increase RC Load Linearly 10%
Bidirectional stress RCDC Tie
LW (Off-Peak Study, Year 1-5)
Load Reduction Linearly from SCADA Data
2021HW (Peak Study, Year 5)
Retire Wyodak
Delay Planned Projects
2026HS (Peak Study, Year 10)
Stress the RCDC Tie in Both Directions
Identify additions that may be necessary for the new RCDC RAS
The impact of delaying planned projects beyond the 5-year outlook will also be considered.
“Environmental policies are a significant source of uncertainty to future transmission system performance and impacts so we need to ensure we study a variety of generation resource and retirement scenarios”
9/17/2018

12. 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

13. 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
Data request and associated deadline is for network and PTP transmission customers
9/17/2018

14. 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
9/17/2018

15. 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.
Review comments to draft LTP report, preferred project alternatives, planned project status, other regional planning updates
Additional stakeholder discussions may be held as necessary
Meetings will continued to be held via web conference at the BHP Service Center.
Q4 meeting to be held Mid November or early December.
9/17/2018

16. Questions
9/17/2018

17. Comments / Suggestions
Wes Wingen (605) Michael Lundy (605)
Suggestions to make process more useful?
Suggestions for potential stakeholders?
9/17/2018