HomeMy WebLinkAbout20170918Attachment 107A.pdfYear Project Name
Original Budgeted
capital spend
Revised Budget
capital spend Planned Completion Date Notes Scope/Justification
2017 System Transmission: Rebuild Condition (Bronx‐Sand Creek 115kV Rebuild)$3,000,000 $4,400,000 Nov‐17 Staff_PR_107 Attachment A
2017 West Plains Transmission Reinforce: Garden Springs ‐ Sunset 115kV Rebuild $600,000 $1,350,000 May‐17 Completed Staff_PR_107 Attachment A
2017 Benton‐Othello 115kV Rebuild (Phase 4)$3,000,000 $1,000,000 Jun‐19 Permitting Delay with DOE Staff_PR_107 Attachment A
2017 CDA‐Pine Creek 115kV Rebuild (Phase 1)$4,000,000 $3,650,000 Dec‐17 Staff_PR_107 Attachment A
2017 9CE‐Sunset 115kV Rebuild (Phase 2)$1,250,000 $1,350,000 Dec‐17 Staff_PR_107 Attachment A
2017 Devil's Gap‐Lind 115kV Rebuild $2,900,000 $3,200,000 Dec‐17
This is a project that is justified by the NERC Alert (LiDAR mitigation) but
was moved to this business case because of the large scope of the
rebuild.
2017 Addy‐Devil's Gap (Ford‐DG) 115kV Rebuild $25,000 $25,000 Oct‐18
Funds in 2017 are design only.
Construction is planned for
2018.
Staff_PR_107 Attachment A
Staff_PR_107 Attachment A Page 1 of 23
Engineering Project Request
Instructions: If this is a new request, save this template to your local drive, complete the form, then upload it to ENSO Sharepoint.
Project Title
(e.g. “Benewah-Moscow 230kV Rebuild”)
Benton - Othello 115 kV Transmission Line
Reconductor
Request Number
ERT_2017-X
Enterprise Project
Driver
Reason for initiating the project
Mandatory & Compliance Primary
Asset Class
Transmission
Requested By
The person filling out this form
Transmission Planning (Simrit Basrai) Project Sponsor
Director sponsoring the project
Scott Waples
Proposed In-
Service Date
Date that the project should be completed
5/1/2018 VROM
Very Rough Order of
Magnitude (Cost Estimate)
$7M
Problem Statement
Provide a brief explanation of the problem that needs to be addressed
The 2016 System Planning Assessment identified thermal capacity issues on the Avista owned segments of the Benton – Othello SS 115 kV
Transmission Line. Stations served by the Benton – Othello SS 115 kV Transmission Line are observed with low voltages during several
contingencies.
System performance analysis indicates an inability of the System to meet
the performance requirements in Table 1 of TPL-001-4 P2 and P6 categories in scenarios representing 2017 Heavy Summer and Heavy
Winter scenarios.
There are new potential violations that may occur after the project is
implemented, this project would be considered the first phase to reinforce the area. With reconductoring Benton - Othello we have increased the
power flow through the line (less impedance). After this project is complete Saddle Mountain Integration should be implemented to prevent future
potential violations
Alternatives Considered
Alt1: Status Quo
Staff_PR_107 Attachment A Page 2 of 23
Provide a list of potential
alternatives This alternative is not recommended because it does not mitigate the
expected capacity constraints, and does not adhere to NERC
Compliance regulations.
Alt2: Build new Benton – Othello No.2 115 kV Line
This alternative is not recommended due to the long lead time. To build
a second line lead time would be required for additional permitting and
vetting through the BPA interconnection process. Benton is a foreign
substation. This alternative is also not recommended because it is not
superior to the recommended alternative. The Benton – Othello No. 1
115 kV line is primarily a copper conductor that is out of date and
provides great losses to the transmission system. The existing line
needs to be addressed.
Refer to the Saddle Mountain project for more alternatives, if necessary.
Recommendation
Indicate which alternative is recommended and why. List specific project details and assets to be installed or
replaced as well as project phasing.
Transmission Planning recommends the Avista owned portion of the Benton – Othello SS 115 kV Transmission Line be reconductored to a
conductor capable of providing a minimum of 205 MVA thermal capacity at 40° C ambient temperature.
1) Reconductor Avista’s 26 mile section of the Benton – Othello Switching Station 115 kV Transmission Line with conductor capable
of providing a minimum of 205 MVA thermal capacity at 40C Ambient temperature
2) Remove switch A-131.
This alternative is the most cost effective option considered. The project
mitigates both compliance/capacity and an outdated asset replacement installation. The current line is primarily copper conductor. This alternative
mitigates deficiencies documented in the 2016 Planning Annual Assessment. The Saddle Mountains Integration project will complete the
reinforcement required in the southern Big Bend area. This alternative is the best solution for the long term.
Supporting
Documentation
Provide links to studies, lifecycle analyses, etc. that support this request.
Project Report
Benton - Othello SS Reconductor Final Report
2016 Assessment Report (Page 42)
2016 Avista System Planning Assessment.pdf
FAC-002.2 Compliance
(A Planning study will be required for interconnecting new or materially modified Facilities on the Bulk Electric System)
Will the project require a Facility Interconnect Study per FAC-002.2 Yes No Unknown
If Yes has the study been completed No Yes Attach study or have completed prior to moving to “Committed”
Staff_PR_107 Attachment A Page 3 of 23
Timeline
Date Notes
3/31/2017
Project was vetted through an internal stakeholder meeting T&D Project Scoping and Scheduling Meeting. This meeting included System Planning, Substations,
Transmission Line Design, and Compliance..
Staff_PR_107 Attachment A Page 4 of 23
Engineering Project Request
Instructions: If this is a new request, save this template to your local drive, complete the form, then upload it to ENSO Sharepoint.
Project Title
(e.g. “Benewah-Moscow 230kV Rebuild”)
Cabinet – Bronx - Sandcreek 115 kV
Transmission Line Reconductor
Request Number
ERT_2017-X
Enterprise Project
Driver
Reason for initiating the project
Mandatory & Compliance Primary
Asset Class
Transmission
Requested By
The person filling out this form
Transmission Planning (Simrit Basrai) Project Sponsor
Director sponsoring the project
Scott Waples
Proposed In-
Service Date
Date that the project should be completed
12/1/2017 VROM
Very Rough Order of
Magnitude (Cost Estimate)
$3.6M
Problem Statement
Provide a brief explanation of the problem that needs to be addressed
The 2016 System Planning Assessment identified thermal capacity issues on the Cabinet – Bronx - Sandcreek 115 kV Transmission Line. Stations
served in the north Coure d’Alene area are observed with low voltages during several contingencies.
System performance analysis indicates an inability of the System to meet the performance requirements in Table 1 of TPL-001-4 P1, P2 and P6
categories in scenarios representing 2017 Heavy Summer and Heavy Winter scenarios.
Currently this project is 80% complete, it is requested to complete the project to maximize the impact and reduce TPL-001-4 deficiencies in the
area.
Alternatives Considered
Provide a list of potential alternatives
Alt1: Status Quo
This alternative is not recommended because it does not mitigate the
expected capacity constraints, and does not adhere to NERC
Compliance regulations.
Alt2: Disconnect from BPA
Staff_PR_107 Attachment A Page 5 of 23
This alternative is not recommended as it entails loss of commercial
business with BPA. Loss of external revenue may be a burden for
Avista rate payers
Recommendation
Indicate which alternative is recommended and why. List specific project details and
assets to be installed or replaced as well as project phasing.
Transmission Planning recommends the Avista owned portion of the
Cabinet – Bronx - Sandcreek 115 kV Transmission Line be reconductored to a conductor capable of providing a minimum of 205 MVA (or 314 MVA)
thermal capacity at 40° C ambient temperature.
1.Reconductor 6.62 miles from Bronx to end of AVA ownership (1.65
miles beyond Sandpoint towards Sandcreek Substation)2.Upgrade associated equipment necessary to achieve the maximum
conductor rating.
Considering 80% of this project is complete this project is the most cost
effective option and socially responsible alternative for both Avista’s stakeholder and our neighbors. This alternative effectively mitigates
deficiencies documented in the 2016 Planning Annual Assessment. This alternative is the best solution for the long term.
Supporting Documentation
Provide links to studies, lifecycle analyses, etc. that support this request.
Project Report
Cabinet - Bronx - Sandcreek 115 kV Line Rebuild.pdf
2016 Assessment Report (Page 103)
2016 Avista System Planning Assessment.pdf
FAC-002.2 Compliance
(A Planning study will be required for interconnecting new or materially modified Facilities on the Bulk Electric System)
Will the project require a Facility Interconnect Study per FAC-002.2 Yes No Unknown
If Yes has the study been completed No Yes Attach study or have completed prior to moving to “Committed”
Staff_PR_107 Attachment A Page 6 of 23
Timeline
Date Notes
3/31/2017
Project was vetted through an internal stakeholder meeting T&D Project Scoping and Scheduling Meeting. This meeting included System Planning, Substations,
Transmission Line Design, and Compliance..
Staff_PR_107 Attachment A Page 7 of 23
Engineering Project Request
Instructions: If this is a new request, save this template to your local drive, complete the form, then upload it to ENSO Sharepoint.
Project Title
(e.g. “Benewah-Moscow 230kV Rebuild”)
Coeur d’Alene – Pinecreek 115 kV Transmission Line
Reconductor
Request Number
ERT_2017-X
Enterprise Project
Driver
Reason for initiating the project
Mandatory & Compliance Primary
Asset Class
Transmission
Requested By
The person filling out this form
Simrit Basrai
(form completed by Lamont
Miles)
Project Sponsor
Director sponsoring the project
Scott Waples
Proposed In-
Service Date
Date that the project should be completed
12/31/2019 VROM
Very Rough Order of
Magnitude (Cost Estimate)
$16,000,000
Problem Statement
Provide a brief explanation of the problem that needs to be addressed
Before May 2015 it was identified in the Annual Assessment Studies to reconductor the Coeur d’Alene – Pinecreek 115 kV line and close the normally open switch A124 at Coeur d’Alene 15th St. Substation to mitigate potential NERC TPL -001-4 Table 1 P1, P2 and P6 violations. In 2015 an
operating procedure was implemented which mitigated many of the P2 and P6 violations by utilizing consequential load loss. P1 violations were no
longer identified as the load growth has decreased, and the project addressed as a corrective action plan no longer was flagged in the annual assessment.
With the agreement between Transmission Planning and Transmission
Operations the temporary reconfiguration would only be utilized until the project is complete. The intent was to build the project and in the interim
utilize this plan so that operations would not have to drop load in a P1 state
for the next potential P6 violation that may occur under Peak RC’s recommendation. The temporary procedure implemented drops all load in Coeur d’Alene for P2 and P6 violations. The radial configuration greatly
reduces the reliability to the area.
Staff_PR_107 Attachment A Page 8 of 23
Alternatives
Considered
Provide a list of potential alternatives
Alt1: Status Quo
This alternative is not recommended because it does not mitigate the
expected capacity constraints, and does not adhere to NERC
Compliance regulations.
Alt2: Build new 230 kV Substation in Southeast Couer d’Alene
This alternative is not recommended at this time. This alternative may
be justifiable in the far future with sufficiently higher load growth.
Alt3: Maintain operational set-up as permanent solution
This alternative is not recommended because it greatly decreases
reliability in the area for P2 contingencies. This project however is a
fair cost option to maintain compliance.
Alt4: Build new Boulder – Ramsey 115 kV Transmission Line
This alternative may be considered comparable to the preferred
alternative. However this alternative is not chosen because the added
reliability for another source into Couer d’Alene is needed. Also
additional time will be needed for permitting as this is a new build and
the project is needed now. This alternative may also be considered as
a second phase to the Coeur d’Alene reinforcement project.
Alt5: Reconductor Boulder – Ramsey 115 kV Transmission Line
This alternative may be considered comparable to the preferred
alternative. However this alternative is not chosen because the added
reliability for another source into Couer d’Alene is needed. The limiting
conductor of this line should be addresses in the copper replacement
program. This alternative may also be considered as a second phase
to the Coeur d’Alene reinforcement project.
Alt5: Rebuild Rathdrum 115 kV Substation to BAAH or DBDB
This alternative is not recommended as the preferred alternative
however will be assessed as a second phase. This project does
mitigate the double transformer outage however mitigates other P2
violations. Also for consideration, Rathdrum substation has 166 MW’s
of generation at risk for a single node outage.
Another project would still be needed to mitigate P6 violations (CDA-
PIN 115 kV recondcutor is sufficient).
Alt5: Build a 115 kV Switching station
This alternative is to build a 115 kV Switching station close to where
Boulder – Rathdrum 115 kV line and Post Falls – Prairie 115 kV Lines
come together in Post Falls. This alternative will be assessed as
another project to mitigate existing overloads in the system after Couer
d’Alene – Pinecreek 115 kV line is implemented. This alternative may
Staff_PR_107 Attachment A Page 9 of 23
reinforcement project.
Recommendation
Indicate which alternative is recommended and why. List specific project details and assets to be installed or
replaced as well as project phasing.
Transmission Planning recommends reconductoring the approximately 30 mile Coeur d’Alene 15th St – Pine Creek 115 kV Transmission Line to 795 ACSR conductor with minimum thermal capacity rating of 150 MVA at 40C
and operating the transmission line normally closed. This alternative is recommended as it mitigates several transmission performance issues in the area. Operating the transmission line normally closed provides an
additional source into the Coeur d’Alene area. The additional source supports the remaining transmission system following bus outages at Rathdrum Station.
Rebuilding the transmission line also accommodates the installation of fiber
optic shield wire allowing for communication aided protection schemes and the potential addition of SCADA to Blue Creek and Mission Stations.
Supporting
Documentation
Provide links to studies, lifecycle analyses, etc. that
support this request.
Project Report
Couer d'Alene - Pinecreek 115 kV Line Rebuild.pdf
2016 Assessment Report (Page 107)
2016 Avista System Planning Assessment.pdf
FAC-002.2 Compliance
(A Planning study will be required for interconnecting new or materially modified Facilities on the Bulk Electric System)
x
ORIGINAL DATE
DESIGN: SYSTEM PLANNING
PLANNING APPROVAL
SPOKANE, WASHINGTON
Project Diagram: SP-0235 MAR 08, 2012
DATE: BY DATENO.REVISION
1
2
PROJECT SCOPE UPDATEREVISION NOTES
03-08-2012
INITIALS
0 Created Project Diagram EER
INITIALS
All work to be completed by ASAP
COEUR D’ALENE 15TH ST – PINE CREEK 115 kV
RECONDUCTOR
CdA 15TH St 115 kV
Pine Creek 115 kV
115 kV to Blue Creek
115 kV to Mission
A2
9
0
A51
6
A51
5
A42
9
A42
8
A1
2
4
556 AAC
556 AAC
556 AAC
250 CU
250 CU
397 ACSR
397 ACSR
250 CU
250 CU
250 CU
556 AAC
1 1 Reconductor the CdA 15th St – Pine Creek 115 kV Transmission Line to 795 ACSR conductor with a minimum thermal summer capacity of 150 MVA and operate the transmission line normally closed.
Notes:1) Refer to 2013 Coeur d’Alene Area Planning Assessment and Coeur d’Alene Reinforcement Feasibility Study from Transmission Planning for detailed justification of project.
Conductor Size
0.03 mi
2.59 mi
0.49 mi
2.67 mi
0.31 mi
7.38 mi
0.76 mi
16.46 mi
0.51 mi
10.17 mi
0.08 mi
Brief Project Introduction: Thermal overloads observed in steady state contingency analysis point to an inadequate number of transmission lines serving the city of Coeur d’Alene for the forecasted load in the 20 year planning horizon. Rathdrum Station serves as the primary source to the area; therefore, contingencies causing loss of two or more transmission lines from Rathdrum Station leaves very weak sources to support the remaining transmission system. Operating the Coeur d’Alene – Pine Creek 115 kV Transmission Line normally closed with increase thermal capacity provides an additional source to the area.
Updated per 2013 project study report JRG 09-09-2013
Staff_PR_107 Attachment A Page 10 of 23
If Yes has the study been completed No Yes Attach study or have completed prior to moving to “Committed”
Staff_PR_107 Attachment A Page 11 of 23
Timeline
Date Notes
Staff_PR_107 Attachment A Page 12 of 23
Engineering Project Request
Instructions: If this is a new request, save this template to your local drive, complete the form, then upload it to ENSO Sharepoint.
Project Title
(e.g. “Benewah-Moscow 230kV Rebuild”)
Ford-Devil’s Gap 115kV Reconductor Request Number
ERT_2017-X
Enterprise
Project Driver
Reason for initiating the project
Mandatory & Compliance Primary Asset
Class
Transmission
Requested By
The person filling out this form
Simrit Basrai
(form completed by Lamont Miles)
Project Sponsor
Director sponsoring the project
Scott Waples
Proposed In-
Service Date
Date that the project should be completed
12/31/2025 VROM
Very Rough Order of Magnitude (Cost Estimate)
$3,000,000
Problem Statement
Provide a brief explanation of the problem that needs to be addressed
The Ford – Long Lake Tap segment of the Addy – Devil’s Gap 115 kV
Transmission Line fails to meet performance requirements for the outage of Airway Heights – Devil’s Gap and Devil’s Gap – Nine Mile 115 kV transmission
lines. System performance analysis indicates an inability of the System to meet the performance requirements in Table 1 of NERC TPL-001-4 for P6
contingencies in the 2017 Heavy Summer Low Hydro scenario. However in the interim period, operational actions may be performed after the first N-1 occurs to
reduce generation at Little Falls generating station. (The interpretation used here is operational plans may not be used indefinitely). This project is driven by the
local generation in the area.
Alternatives
Considered
Provide a list of potential alternatives
Alt1: Status Quo
This alternative is not recommended because it does not mitigate the
expected capacity constraints, and does not adhere to NERC Compliance
regulations.
Alt2: Implement hard cap on Generation in the area
Staff_PR_107 Attachment A Page 13 of 23
Loss of Avista generation. (Ask Power supply how much this costs for the
company).
Recommendation
Indicate which alternative is recommended and why. List specific project details
and assets to be installed or replaced as well as project phasing.
Transmission Planning recommends the rebuild and reconductor of
approximately 6 miles of the Addy-Devil’s Gap 115kV transmission line from Ford to Devil’s Gap in 2018. This project is small scale and fits into the work plan for
Transmission Engineering better in the near-term than in the long-term. There is also an Asset Condition project for this line to replace worn out spar arms (pole-
style crossarms) that will be taken care of by completing this reconductor project.
ADDY - DEVIL’S GAP 115 kV RECONDUCTOR
Project Diagram: SP-0229
Devils Gap East 115 kV
Addy 115 kV
1
1 Reconductor 1.84 miles of 266.8 ACSR conductor and 2.8 miles of 397.5 ACSR conductor on the Addy – Devils Gap 115 kV Transmission Line south of Ford Substation with 556 AAC and a thermal capacity of 120 MVA at 40C Ambient temperature.
115 kV to Chewelah
115 kV to Valley
115 kV to Ford
115 kV to Long Lake
266.8 ACSR
B1
1
3
7
A4
6
8
A4
6
6
A4
6
5
A4
6
3
A4
6
2
A4
6
0
A7
7
3
A5
2
1
Conductor Size
556 AAC
397 ACSR
556 AAC
37.34 mi
1.84 mi
2.8 mi
1.33 mi
Brief Project Introduction: Thermal overloads are observed on the Addy – Devils Gap 115 kV Transmission Line for the outage of the Airway Heights – Devils Gap and Devils Gap – Nine Mile 115 kV Transmission Line.
Revised Justification and Scope EER 07-15-2013
Staff_PR_107 Attachment A Page 14 of 23
Supporting
Documentation
Provide links to studies, lifecycle analyses, etc. that support this request.
Project Report
Addy - Devils Gap 115 kV Reconductor Study Report.pdf
2016 Assessment Report (Page 40)
2016 Avista System Planning Assessment.pdf
FAC-002.2 Compliance
(A Planning study will be required for interconnecting new or materially modified Facilities on the Bulk Electric System)
Will the project require a Facility Interconnect Study per FAC-002.2 Yes No Unknown
If Yes has the study been completed No Yes Attach study or have completed prior to moving to “Committed”
Staff_PR_107 Attachment A Page 15 of 23
Timeline
Date Notes
Staff_PR_107 Attachment A Page 16 of 23
Engineering Project Request
Instructions: If this is a new request, save this template to your local drive, complete the form, then upload it to ENSO Sharepoint.
Project Title
(e.g. “Benewah-Moscow 230kV Rebuild”)
Garden Springs 230 kV Station Integration – Phase
1
Request Number
ERT_2017-X
Enterprise Project
Driver
Reason for initiating the project
Mandatory & Compliance Primary
Asset Class
Transmission
Requested By
The person filling out this form
Transmission Planning Project Sponsor
Director sponsoring the project
Scott Waples
Proposed In-
Service Date
Date that the project should be completed
12/31/2023 VROM
Very Rough Order of
Magnitude (Cost Estimate)
$11,200,000
Problem Statement
Provide a brief explanation of the problem that needs to be addressed
The west side of Spokane has transmission system performance deficiencies caused by lack of redundancy and capacity with the existing
infrastructure. System performance analysis indicates an inability of the System to meet the performance requirements in Table 1 of NERC TPL-
001-4 in scenarios representing 2021 Heavy Summer scenarios for P2 and P6 events if the Ninth & Central 230 kV Integration project is constructed.
The deficiencies will occur sooner if the Ninth & Central 230 kV Integration project is not constructed. In 2033, a P2.1 event (Ninth & Central – Sunset
115 kV open at Ninth & Central Station does not meet performance criteria and shedding non-consequential load is not allowed. An Operating
Procedure to shed non-consequential load following a P2 event of the second event of a P6 event can be used (and is allowed) until 2035 to mitigate system deficiencies.
Alternatives Considered
Provide a list of potential alternatives
Alt1: Status Quo
This alternative is not recommended because it does not mitigate the expected capacity constraints, and does not
Staff_PR_107 Attachment A Page 17 of 23
Procedures can be used to defer the System Deficiencies.
Alt2: Garden Springs 230 kV Station
Constructing a new 230 kV station at the existing Garden
Springs property to connect the existing 115 kV transmission
lines passing through the property into the station was
considered. The 230 kV station would be sourced through a
new 230 kV transmission line interconnected with the Bonneville Power Administration. The 115 kV portion of the
new station is a part of the West Plains Transmission
Reinforcement Plan. All system deficiencies identified will be
mitigated.
Alt3: Airway Height – Westside 115 kV Transmission Line
Constructing a new 9.5 mile 115 kV transmission line from
Airway Heights to Westside was considered as an alternative.
Outages at the Westside station including the P6 outage of
both 230/115 kV transformers and P7 outage of the 230 kV
double circuit into Westside continue to cause performance issues. A new 230 kV source to the Spokane area provides a
more robust long term solution.
Alt4: Garden Springs 230 kV Station with Garden Springs –
Westside 230 kV Transmission Line
Constructing a 7.9 mile 230 kV transmission line from Westside to the new Garden Springs station was considered instead of
the proposed Bluebird – Garden Springs 230 kV Tranmission
Line. Performance issues are not fully mitigated with the
alternative. Specifically, the P7 outage of the 230 kV double
circuit into Westside continue and right-of-way events between Westside and Garden Springs stations do not meet
performance criteria.
Alt5: No New 230 kV Infrastructure
Rebuilding several 115 kV transmission lines in the Spokane
area instead of constructing any new 230 kV infrastructure was considered. The alternative does not provide the necessary
redundancy but instead creates a higher dependence on
existing facilities.
Recommendation
Indicate which alternative is
recommended and why. List specific project details and
Alternative 2: Garden Springs 230 kV Station is the recommended solution
to the stated problem. Project scope includes the following:
Phase 1: 115 kV station at existing Garden Springs property to be breaker
Staff_PR_107 Attachment A Page 18 of 23
assets to be installed or
replaced as well as project phasing.
transmission line integration work including rebuilding the Garden Springs –
Sunset section of the existing Sunset – Westside 115 kV Transmission Line – Energize in 2023
Phase 2: 230 kV station with single 250 MVA 230/115 kV transformer and new 230 kV transmission line from new 230 kV station to BPA corridor.
Interconnection with BPA will require BPA to construct new 230 kV station. – Energize in 2026
The recommended alternative has been broken into two Engineering Round Table project requests. Two project requests allows for the construction of
the 115 kV portion of the project justifiably ahead of the 230 kV portion of the project.
Supporting
Documentation
Provide links to studies, lifecycle analyses, etc. that support this request.
Garden Springs Integration Feasibility Study - Rev 0.pdf
West Spokane Transmission Plan - Rev 0.pdf
West Plains Reinforcement Plan - Rev B.pdf
2016 Avista System Planning Assessment.pdf
FAC-002.2 Compliance
(A Planning study will be required for interconnecting new or materially modified Facilities on the Bulk Electric System)
Will the project require a Facility Interconnect Study per FAC-002.2 Yes No Unknown
If Yes has the study been completed No Yes Attach study or have completed prior to moving to “Committed”
Staff_PR_107 Attachment A Page 19 of 23
Timeline
Date Notes
3/31/2017 Project re-vetted at ERT Planning offsite meeting and ERT form created.
Staff_PR_107 Attachment A Page 20 of 23
Engineering Project Request
Instructions: If this is a new request, save this template to your local drive, complete the form, then upload it to ENSO Sharepoint.
Project Title
(e.g. “Benewah-Moscow 230kV Rebuild”)
Ninth and Central - Sunset Transmission Line Rebuild Request Number
ERT_2017-X
Enterprise Project
Driver
Reason for initiating the project
Mandatory & Compliance Primary
Asset Class
Transmission
Requested By
The person filling out this form
Transmission Planning Project Sponsor
Director sponsoring the project
Scott Waples
Proposed In-
Service Date
Date that the project should be completed
12/31/2023 VROM
Very Rough Order of
Magnitude (Cost Estimate)
$1,300,000
Problem Statement
Provide a brief explanation of the problem that needs to be addressed
An outage of the Garden Springs – Westside 115 kV Transmission Line (created with completion of the 115 kV phase of the Garden Springs 230 kV Station Integration project) combined with another outage of Metro – Post Street, Metro – Sunset, or Post Street – Third & Hatch 115 kV transmission
lines causes the Ninth & Central – Sunset 115 kV Transmission Line to exceed its applicable facility rating. System performance analysis indicates
an inability of the System to meet the performance requirements in Table 1
of NERC TPL-001-4 in scenarios representing 2021 Heavy Summer scenarios for the P6 events.
Alternatives Considered
Provide a list of potential alternatives
Alt1: Status Quo
This alternative is not recommended because it does not mitigate the expected capacity constraints, and does not
adhere to NERC Compliance regulations. Operating
Procedures can be used to defer the System Deficiencies.
Staff_PR_107 Attachment A Page 21 of 23
Rebuild
Replace the 795 AAC conductor on the Ninth & Central – Sunset 115kV Transmission Line with 795 ACSS with E3X coating to match the rest of the
line, and upgrade the related transmission switches and bus work at the Southeast Station. All System deficiencies are mitigated.
Alt3: Garden Springs 230 kV Station Integration
The proposed Garden Springs 230 kV Station Integration project could be advanced in the schedule. The project has its own Engineering Round
Table project request. All System deficiencies are mitigated.
Recommendation
Indicate which alternative is recommended and why. List specific project details and
assets to be installed or replaced as well as project phasing.
Alternative 2, replace the 795 AAC conductor on the Ninth & Central –
Sunset 115kV Transmission Line with 795 ACSS with E3X coating to match the rest of the line, and upgrade the related transmission switches and bus
work at the Southeast Station is the recommended alternative.
$800,000 – Transmission
$500,000 – Substation
Supporting
Documentation
Provide links to studies, lifecycle analyses, etc. that
support this request.
Under development.
FAC-002.2 Compliance
(A Planning study will be required for interconnecting new or materially modified Facilities on the Bulk Electric System)
Will the project require a Facility Interconnect Study per FAC-002.2 Yes No Unknown
If Yes has the study been completed No x Yes Attach study or have completed prior to moving to “Committed”
Staff_PR_107 Attachment A Page 22 of 23
Timeline
Date Notes
3/31/2017 Project re-vetted at ERT Planning offsite meeting and ERT form created.
Staff_PR_107 Attachment A Page 23 of 23