Transmission Coordination
and Planning Committee
2016 Q1 Stakeholder
Meeting
Q1 Meeting, March 25, 2016
Sinclair Room, Little America Hotel Cheyenne
Cheyenne, WY 82001
3/25/2016
Agenda
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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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Energy Delivery 101
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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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Transmission Planning Groups
Transmission Coordination & Planning Committee (local)
• http://www.oasis.oati.com/CLPT/index.html
• Select “Transmission Planning” folder
Colorado Coordinated Planning Group (sub-regional)
• www.westconnect.com/planning_ccpg.php
WestConnect (regional)
• www.westconnect.com/planning.php
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BHE Cheyenne 115 kV System
3/25/2016
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2016 10 Year Transmission Plan
Project
ISD
Status
New Data Center 115 kV Substation & Transmission
2015
In-Service
New South Cheyenne 230:115 kV T2 Transformer
2015
In-Service
New North Range – Swan Tap – South Cheyenne
115 kV Circuit
2015
In-Service
Corlett – North Range 115 kV Line Upgrade
2015
In-Service
New King Ranch 115 kV Substation & Transmission
2018
Planned
North Range – King Ranch – Swan Tap 115 kV
Circuit Upgrade
2018
Planned
Corlett 115 kV Substation Terminal Upgrades
2018
Planned
3/25/2016
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2016 10 Year Transmission Plan…continued
Project
ISD
Status
Happy Jack 115 kV Substation Terminal Upgrades
2018
Planned
Cheyenne Prairie – Archer (WAPA) 115 kV Line
Upgrade
2019
Planned
Cheyenne Prairie – East Business Park 115 kV Line
Upgrade
2019
Planned
New Swan Ranch 115 kV Substation
2019
Planned
New Cheyenne Prairie – South Cheyenne 115 kV
Double Circuit
2023
Proposed
3/25/2016
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Cheyenne Area Resource Update
Active Large Generator Interconnection Request
• CLPT-G6 125 MW CCT at Cheyenne Prairie Generation Station
substation
• In-Service-Date January 1, 2023
• Point of Interconnection – Cheyenne Prairie 115 kV Substation
• System Impact Study in progress, completion date 4/6/2016
• CLPT-G7 102 MW Wind approximately 7 miles west of North Range
substation
• In-Service-Date December 31, 2017
• Point of Interconnection – North Range – Corlett 115 kV line
• Feasibility Study in progress, completion date 4/16/2016
3/25/2016
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2015 LTP Study Results & Recommendations
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2017HS studies indicated no performance issues based upon the projects completed
with forecast loads and resources.
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2020HS studies indicated that terminal upgrades at the Happy Jack and Corlett 115 kV
substations are required to meet the Data Center load growth. Terminal equipment
upgrade projects are planned for 2018.
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2020HS studies also indicated a through flow issue on the CLFP 115 kV system and
(WAPA) 230 kV Archer-Terry Ranch line with Wayne Child 345-230 kV in-service, until
completion of the proposed Cheyenne Prairie–Cheyenne South 115 kV project.
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2024HS studies indicated that the planned generation additions at Cheyenne Prairie
(265 MW) including CLPT-G6 can be integrated onto the system as studied. This is
based upon completion of the proposed Cheyenne Prairie-Cheyenne South 115 kV
project (ISD 2023).
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2024HS studies also indicate that Cheyenne Prairie generation is required to limit
post-contingency line loading when the Cheyenne Area load exceeds 385 MW. In
order to avoid “must run” generation further upgrades or additions to the 115 kV
transmission system are required.
3/25/2016
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2016 LTP Study Scope
2016 CCPG Compliance Analysis Cases will be used as the
benchmark cases for the this years study scenarios
2018hs Heavy Summer Case (Peak Study Year 2)
• Power Flow, Voltage & Transient Stability
2017-18lw Light Winter Case (Off-Peak Study Year 1-5)
• Power Flow, Voltage & Transient Stability
2021hw Heavy Winter Case (Peak Study Year 5)
• Power Flow, Voltage & Transient Stability as needed
2026hs Heavy Summer Case (Peak Study Year 10)
• Power Flow & Voltage Stability as needed
3/25/2016
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Sensitivities To Consider
• Cheyenne Prairie Generation – Maximum
Output and Off-Line
• Planned Transmission Upgrade Projects –
Delayed
• Data Center(s) full load build-out
• Large Load (50 MW) Addition at each load
bus on the 115 kV System with full buildout of the Data Center load
• Additional sensitivity scenarios may be
created for any of the base case scenarios
based on stakeholder input.
3/25/2016
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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/ccpg_request_form.xls
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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
3/25/2016
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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
3/25/2016
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Next Meetings
Q2 Meeting: Held only if necessary as we evaluate new bi-annual
meeting schedule
Q3 Meeting: (TBD Late October/Early November)
o Review study results, discuss project alternatives, planned
project status, other regional planning updates
Q4 Meeting: (TBD) Held only if necessary as we evaluate new biannual meeting schedule
Additional stakeholder discussions may be held as necessary
3/25/2016
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Questions
3/25/2016
Comments / Suggestions
Wes Wingen
wes.wingen@blackhillscorp.com
(605) 721-2268
Jim Farby
Transmission Planning Engineer
jim.farby@blackhillscorp.com
(605) 721-1722
3/25/2016
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