20180329PAC to Staff UT Q715SIS.pdf

PACIFICORP
TRANSMISSION
Large Generator Interconnection
System Impact Restudy Report
Completed for
("Interconnection Customer")
Q0715
Proposed Point of Interconnection
Canyon Compression-Railroad 138 kV transmission line
(Near Whitney Canyon Inlet,near to Structure #116)
February 9,2018
PAciFICORP
TRANSMISSION
System Impact Study Report
TABLE OF CONTENTS
1.0 DESCRIPTION OF THE GENERATING FACILITY.............................................l
2.0 SCOPE OF THE STUDY ....................................................1
3.0 TYPE OF INTERCONNECTION SERVICE ................................................2
4.0 DESCRIPTION OF PROPOSED INTERCONNECTION...............................................2
4.1 Other Options Considered................................................2
5.0 STUDY ASSUMPTIONS........................................................3
5.1 Energy Resource (ER)Interconnection Service..............................................4
5.1.1 Requirements 4
5.1.2 Cost Estimate 10
5.1.3 Schedule 11
5.1.4 Maximum Amount of Power that can be deliveredinto NetworkLoad,with No Transmission
Modifications(for informationalpurposes only)11
5.1.5 Additional Transmission ModificationsRequired to Deliver 100%of the Power into Network
Load (for informationalpurposes only)11
6.0 PARTICIPATION BY AFFECTED SYSTEMS.............................................11
7.0 APPENDICES ..........................................................11
7.1 Appendix 1:HigherPriority Requests .............................................13
7.2 Appendix 2:Property Requirements .............................................14
7.3 Appendix 3:Study Results................................................16
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1.0 DESCRIPTION OF THE GENERATING FACILITY
("Interconnection Customer")proposed interconnecting 120 MW of new generation to
PacifiCorp's ("Transmission Provider")Canyon Compression-Railroad 138 kV transmission line
near Whitney Canyon Inlet (near to structure #116)located in Uinta County,Wyoming.The
("Project")will consist of 60 GE 2.0-116 turbines for a total output of 120 MW.The requested
commercial operation date is October 1,2020.
This restudy is being performed due to a change in the ratings of certain facilities that were used
in the evaluation of this Project in the original system impact study.
Interconnection Customer will NOT operate this generator as a Qualified Facility as defined by
the Public Utility Regulatory Policies Act of 1978 (PURPA).
The Transmission Provider has assigned the Project "Q0715."
2.0 SCOPE OF THE STUDY
The interconnection system impact restudy shall evaluate the impact of the proposed
interconnection on the reliability of the transmission system.The interconnection system impact
study will consider Base Case as well as all generating facilities (and with respect to (iii)below,
any identified network upgrades associated with such higher queued interconnections)that,on the
date the interconnection system impact study is commenced:
(i)are directlyinterconnected to the transmission system;
(ii)are interconnected to Affected Systems and may have an impact on the interconnection
request;
(iii)have a pending higher queued interconnection request to interconnect to the transmission
system;and
(iv)have no Queue Position but have executed an LGIA or requested that an unexecuted
LGIA be filed with FERC.
This interconnection system impact restudy will consist of a short circuit analysis,a stability
analysis,and a power flow analysis.The study will state the assumptions upon which it is based;
state the results of the analyses;and provide the requirements or potential impediments to
providing the requested interconnection service,includingpreliminaryindication of the cost and
length of time that would be necessary to correct any problems identified in those analyses and
implement the interconnection.The study will also provide a list of facilities that are required as a
result of the Interconnection Request and a non-binding good faith estimate of the cost
responsibility and a non-binding good faith estimated time to construct.
Based on the engineeringjudgement,the stability results for this project are not expected to change
and hence the restudy of stability analysis was not performed.
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3.0 TYPE OF INTERCONNECTION SERVICE
The Interconnection Customer has selected Energy Resource (ER)interconnection service.
4.0 DESCRIPTION OF PROPOSED INTERCONNECTION
The Interconnection Customer's proposed Generating Facility is to be interconnected through a
new substation southwest of the Whitney Canyon Inlet point in Uinta County on the Canyon
Compression -Railroad 138 kV transmission line.Figure 1 below,is a one-line diagram that
illustrates the interconnection of the proposed Generating Facility to the Transmission Provider's
system.
Whitney
Canyon
>0.3 miles
i Canyon Compression
Q0715 POI
Substation
Point of
Interconnection
I 138 kV
Q0715 34.5 kV
Substation
Figure 1:Simplified System One Line Diagram
4.1 Other Options Considered
The followingalternative options were considered as potential Points of Interconnection
("POI")for this Project:None.
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5.0 STUDYASSUMPTIONS
All active higher priority transmission service and/or generator interconnection requests will
be considered in this study and are listed in Appendix 1.If any of these requests are materially
modified or withdrawn,the Transmission Provider reserves the right to restudy this request,
and the
Results and conclusions could significantlychange.
For study purposes there are two separate queues:
o Transmission Service Queue:to the extent practical,all network upgrades that are
required to accommodate active transmission service requests will be modeled in this
study.
o Generation Interconnection Queue:Interconnection Facilities associated with higher
queue interconnection requests with an in-service date of December 2020 or earlier will
be modeled in this study.
The Interconnection Customer's request for energy or network resource interconnection
service in and of itself does not convey transmission service.Only a Network Customer may
make a request to designate a generating resource as a Network Resource.The provision of
transmission service may require additional studies and the construction of additional
upgrades.
Under normal conditions,the Transmission Provider does not dispatch or otherwise directly
control or regulate the output of generating facilities.Therefore,the need for transmission
modifications,if any,which are required to provide Network Resource Interconnection Service
will be evaluated on the basis of 100 percent deliverability (i.e.,no displacement of other
resources in the same area).
This study assumes the Project will be integrated into the Transmission Provider's system at
agreed upon and/or proposed POI.
The Interconnection Customer will construct and own any facilities required between the Point
of Change of Ownership and the Project unless specifically identified by the Transmission
Provider.
Generatortripping may be required for certain outages.
All facilities will meet or exceed the minimum Western Electricity Coordinating Council
("WECC"),North American Electric ReliabilityCorporation ("NERC"),and the Transmission
Provider's performance and design standards.
The Energy Gateway West,Aeolus-Bridger/AnticlineD.2,is assumed to be in-service by year
end 2020.
All system improvements associated with relevant prior queued projects are in service before
Q0715.
The Midway -Jordanelle 138 kV line is assumed to be in service (2019).
The Point of Interconnection for this Project is assumed to be approximately 0.3 miles from
the Transmission Provider's WhitneyCanyon Inlet point.Movingthe Point of Interconnection
further away from this point must be approved by the Transmission Provider as the study
results could change.
This report is based on information available at the time of the study.It is the Interconnection
Customer's responsibility to check the Transmission Provider's web site regularly for
Transmission System updates at http://www.pacificorp.com/tran.html
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5.1 Energy Resource (ER)Interconnection Service
Energy Resource Interconnection Service allows the Interconnection Customer to connect its
Generating Facility to the Transmission Provider's Transmission System and to be eligible to
deliver electric output using firm or non-firm transmission capacity on an as-availablebasis.
5.1.1 Requirements
5.1.1.1 Generating Facility Modifications
Transmission Provider will require the facility to operate in voltage control mode with
the ability to deliver power output to the POI within the range of+/-0.95 power factor.
(Please see Standard Large Generator Interconnection Agreement,article 9.6.1 and
9.6.2 in OATT.)Any additional reactive compensation must be designed such that the
discrete switching of the reactive device,if required,does not cause step voltage
changes greater than ±3%at any load serving bus on the Transmission Provider's
system.
As required by NERC standard VAR-001-la,the Transmission Provider will provide
a voltage schedule for the POI.In general,GeneratingFacilities should be operated so
as to maintain the voltage at the POI,or other designated point as deemed appropriated
by Transmission Provider.The Transmission Provider may also specify a voltage
and/or reactive power bandwidth as needed to coordinate with upstream voltage control
devices such as on-load tap changers.At the Transmission Provider's discretion,these
values might be adjusted depending on operating conditions.The voltage control
settings of the GeneratingFacility must be coordinatedwith the Transmission Provider
prior to energization (or interconnection).
At low output levels,the Q0715 Project needs to ensure that it maintains the power
factor within +/-0.95 at the POI and minimize the reactive power flow towards the
transmission system to prevent high voltages.PacifiCorp has experiencedhigh voltages
in the Wyoming area when the transmission system is lightly loaded with low wind
conditions in the area.With low wind conditions the wind farms tend to supply reactive
power into the transmission system increasing the voltage.
Generating Facilities capable of operating with a voltage droop are required to do so.
Voltage droop control enables proportionate reactive power sharing among generation
facilities.Studies will be required to coordinate voltage droop settings if there are other
facilities in the area.It will be the Interconnection Customer's responsibility to ensure
that a voltage coordination study is performed,in coordination with Transmission
Provider,and implemented with appropriate coordination settings prior to unit testing.
For areas with multipleGenerating Facilities,additional studies may be required to
determine whether critical interactions,including but not limited to control systems,
exist.These studies,to be coordinated with Transmission Provider,will be the
responsibility of the Interconnection Customer.
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To facilitate collection and validation of accurate modeling data to meet NERC
modeling standards,PacifiCorp,as the Planning Coordinator,requires Phasor
Measurement Units (PMUs)at all new Generating Facilities with an individual or
aggregate nameplate capacity of 75 MVA or greater.In addition to owning and
maintaining the PMU,the Generating Facility will be responsible for collecting,storing
and retrieving data as requested by the Planning Coordinator.Data must be collected
and be able to stream to Planning Coordinator for each of the GeneratorFacility's step-
up transformers measured on the low side of the GSU at a sample rate of at least 30
samples per second and synchronized within +/-2 milliseconds of the Coordinated
Universal Time (UTC).Initially,the followingdata must be collected:
Three phase voltage and voltage angle (analog)
Three phase current (analog)
Data requirements are subject to change as deemed necessary to comply with local and
federal regulations.
All wind turbines must meet the Federal Energy Regulatory Committee (FERC)and
WECC low voltage ride-through requirements as specified in the interconnection
agreement.Each of the Interconnection Customer's step-up transformers will need to
be switched with a 138 kV circuit breaker.
As the Transmission Provider cannot submit a user written model to WECC for
inclusion in base cases,a standard model from the WECC Approved Dynamic Model
Library is required 180 days prior to trial operation.The list of approved generator
models is continuallyupdated and is available on the http://www.WECC.bizwebsite.
The Interconnection Customer is responsible for the protection of the transmission line
between the Generating Facility and the Point of Interconnection substation.In order
to provide this protection the Interconnection Customer shall construct and own a tie-
line substation to be located at the change of ownership (separate fenced facility
adjacent to the Transmission Provider's Point of Interconnection substation)and
include an Interconnection Customer owned protective device and associated
transmission line relaying/communications.The ground grids of the Transmission
Provider's Point of Interconnection substation and the Interconnection Customer's tie-
line substation will be connected to support the use of a bus differential protection
scheme which will protect the overhead bus connection between the two facilities.
5.1.1.2 Transmission System Modifications
Construct a new three breaker 138 kV POI ring bus substation southwest of the
Whitney Canyon Inlet (near to structure 116),with associated switches and line
terminations.An additional 138 kV breaker (customer-owned)will be required at
the Point of Change of Ownership (see Figure 1).
Modify the existing Naughton West RAS to integrate the Q0715 Project.If the
average of the flows on West of Naughton &West of Evanston is above 900 MW,
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Q0715 will be armed to trip for the N-2 outages of either Ben Lomond -Birch
Creek 230 kV line +Ben Lomond -Naughton or Naughton -Birch Creek 230 kV
line +Ben Lomond -Naughton 230 kV line.
o Capability to trip the Q0715 Project if necessary under N-2 outages described
above.
o Redundantcommunication from the RAS controller to the Project.
5.1.1.3 Transmission Re uirements
Construct 300 ft Loop-Inof the Canyon Compression-Railroad 138 kV Line to the
Railroad side of the Q0715 POI sub near structure 116.
Replace one shield wire with OPGW between Canyon Compression and the Q0715
POI substation for a distance of 1.38 miles.
The Interconnection Customer shall construct the tie line from the collector
substations to the tie-line substations.
The Interconnection Customer is required to build tie-line substations adjacent to the
POI substation which will house the tie-line breaker.The Transmission Provider shall
review the design of the tie-line span between the tie-line substation deadend tower
and the POI substation deadend tower.The Interconnection Customer shall coil
conductor,OPGW,shield wire,and line hardware with sufficient quantities to span
between the tie-line substation tower and the POI substation tower.
The Transmission Provider will construct the span between the tie-line substation
tower and the POI substation tower.
If any Transmission Provider lines are crossed by Interconnection Customer tie-line,
the Interconnection Customer line will cross under Transmission Provider's line with
at least NESC plus 3 foot clearance under all sag conditions of both lines.
5.1.1.4 Existing Circuit Breaker Upgrades -Short Circuit
The increase in the fault dutyon the system as a result of the addition of the Generating
Facility with 125 -GE 2.0-116 2 MW wind turbine generators fed through 60 -2,222
kVA 34.5 kV -690 V transformers with 5.75%impedance then fed through one 138 -
34.5kV 83/112/140 MVA step-up transformer with 9%impedance will not push the
fault duty above the interrupting rating of any of the Transmission Provider's existing
fault interruptingequipment.There is concern that the equipment of other customers
of the Transmission Provider at Canyon Compression substation may need to be
replaced due to the increase in fault duty at that location.Further analysis will be
performed during detailed design if this Project moves forward.
5.1.1.5 Protection Re uirements
The Interconnection Customer's tie line substation (having a sole 138kV circuit breaker
and associated equipment)will be adjacent to the Q0715 POI substation with a common
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fence between the two facilities.With this configuration the ground mats of the two
substations will be tied together.The short line segment between the tie line substation
and the Q0715 POI substation will be considered a bus section and will be protected
with redundantbus differential relay systems.The bus differential relays will be located
in the Q0715 POI substation.The Interconnection Customer will need to provide the
output from two sets of current transformers to be fed into the bus differential relays
with a maximum current transformer ratio matching the maximum CT ratio of the
breakers at the Q0715 POI substation.If a fault is detected in the short conductor
connection,both the 138kV breakers in the Q0715 POI substation and the 138kV
breaker in the Interconnection Customer's tie line substation will be tripped.
The detection and clearing of faults on the tie line between the tie line and the collector
substation will be the responsibility of the Interconnection Customer.Facilities must
be installed to detect and isolate the line if it is faulted in five cycles or less.
A relay at the Q0715 POI substation will monitor the voltage magnitude and
frequency.If the magnitude or frequency of the voltage is outside of normal range of
operation a signal will be sent over the communication system to the collector
substation.At the collector substation this signal is to trip open all of the 34.5 kV
feeder breakers to disconnect the wind turbine generators.By tripping the 34.5 kV
breakers instead of the 138kV breakers the station service to the plant is maintained
to facilitate the restoration of the generation.This relay will also have phase and
ground directional overcurrent elements set to operate for faults in the line between
the Q0715 POI substation and the collector substation and serve as a backup to the
main protection installed by the Interconnection Customer as indicated in the
previous paragraph.
The installation of protective relays for line fault detection will be required at the
Transmission Provider's Q0715 138kV POI substation for the protection of the lines to
the Interconnection Customer's collector substation and the line to Railroad substation,
where a two-terminal transmission line current differential will be implemented.The
lines from the Q0715 POI substation to Compression substation will also be protected
with a two-terminal transmission line current differential relay system.The connection
to WhitneyCanyon substation will be treated as a load for this line differential.
5.1.1.6 Data (RTU)Requirements
In addition to the need for operational data and control at the Q0715 POI substation,
data for the operation of the power system will be needed from the collector substation.
This data will be acquired by installing an Interconnection Customer owned data
concentrator at the collector substation.The data will be transferredto the RTU in POI
substation via Interconnection Customer owned fiber on the tie line from the collector
substation.
Listed below is the data that will be acquired from the collector substation,tie line
substation and Q0715 POI substation.
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From the Q0715 POI substation:
Analogs:
Net Generationreal power
Net Generator reactive power
Interchangeenergy register
From tie line substation:
Status:
138kV breaker
From the Q0715 collector substation:
Analogs:
Transformer #1 real power
Transformer #1 reactive power
Real power flow through 34.5 kV line feeder breaker 1
Reactive power flow through 34.5 kV line feeder breaker 1
Real power flow through 34.5 kV line feeder breaker 2
Reactive power flow through 34.5 kV line feeder breaker 2
Real power flow through 34.5 kV line feeder breaker 3
Reactive power flow through 34.5 kV line feeder breaker 3
Real power flow through 34.5 kV line feeder breaker 4
Reactive power flow through 34.5 kV line feeder breaker 4
Real power flow through 34.5 kV line feeder breaker 5
Reactive power flow through 34.5 kV line feeder breaker 5
A phase 138kV transmission voltage
B phase 138kV transmission voltage
C phase 138kV transmission voltage
Average Wind speed
Average Plant Atmospheric Pressure (Bar)
Average Plant Temperature (Celsius)
Status:
138 kV breaker Tl
34.5 kV collector circuit breaker 1
34.5 kV collector circuit breaker 2
34.5 kV collector circuit breaker 3
34.5 kV collector circuit breaker 4
34.5 kV collector circuit breaker 5
5.1.1.7 Substation Requirements
90715 POI Substation
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The Project will require a new 138 kV three breaker ring bus POI substation.The
substation will be approximately 170'x 300'(fence dimensions)based on the
Interconnection Customer provided facility requirements.The POI substation will be
located adjacent to the Interconnection Customer's tie line substation with a common
fence between the facilities.The ground grids for the substations will be tied together
and conduit will be installed between the substation to facilitate installation of
protection,control,and indication cables.The followingis a list of the major equipment
required for this project:
3 -138 kV Power Circuit Breakers
6 -138 kV CCVTs
3 -138 kV CT/VT Metering Units
11 -138 kV Switches
9 -138 kV Lightning Arresters
1 -138 kV SSVT
1 -Control House
5.1.1.8 Communication Requirements
Installation of fiber is required on the existing line from Canyon Compression
substation to the new Q0715 POI substation.The Interconnection Customer will need
to install OPGW fiber on the line from Q0715 collector substation to the tie line
substation where it will then connect to the Transmission Provider's communication
equipment.Fiber nodes,multiplexand fiber termination panels are required at all three
locations.At the Q0715 POI substation a 48 volt communication battery and charger
is required for protection circuits.At Canyon Compression substation the
communications are connected to the backbone via existing fiber and microwave.
Substation network is to be installed at all three locations for metering and status.
With the Naughton RAS requirements for redundant communications,a leased Tl
circuit is to be installed at the POI substation with the other end terminated at Naughton
substation.
5.1.1.9 Metering Requirements
InterchangeMetering
The interchange metering will be designed bidirectional and rated for the total net
generation of the project includingmetering the retail load (per tariff)delivered to the
customer.The Transmission Provider will specify and order all interconnection
revenue metering,includingthe instrument transformers,metering panels,junction box
and secondary metering wire.The primary metering transformers shall be combination
138 kV,500/5,RF =2,CT/VT extended range for high accuracy metering.
The metering design package will include two revenue quality meters,test switch,with
DNP real-time digital data terminated at a metering interposition block.One meter will
be designated a primary SCADA meter and a second meter will be used designated as
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backup with metering DNP data delivered to the alternate control center.The metering
data will include bidirectional KWH KVARH,revenue quantities including
instantaneous PF,MW,MVAR includingper phase voltage and amps data.
An Ethernet connection is required for retail sales and generation accounting via the
MV-90 translation system.
Station Service/Construction Power
Prior to construction,Interconnection Customer must arrange construction power with
the Transmission Provider.The metering shall conform to the Six State Electric Service
Requirements manual as the site is within the Transmission Provider's service territory.
For permanent station service load,bidirectional metering is required.Please note,prior
to back feed Interconnection Customer must arrange distribution voltage retail meter
service for electricityconsumed by the Project and arrange backup station service for
power that will be drawn from the transmission or distribution line when the Project is
not generating.Interconnection Customer must call the PCCC Solution Center 1-800-
640-2212 to arrange this service.Approval for back feed is contingent upon obtaining
station service.
5.1.2 Cost Estimate
The followingestimate represents only scopes of work that will be performed by the Transmission
Provider.Costs for any work being performed by the Interconnection Customer are not included.
Direct Assigned
Q0715 Tie Line Substation -Coordinate Relaying and Communications $364,000
Q0715 Naughton substation -Modify RAS $105,000
Q0715 POI Substation -Metering,Protection &Control and $1,414,000
Line Termination
Total Direct Assignment $1,883,000
Network Upgrades
Q0715 POI substation -Add 138 kV three-breakerring bus $6,187,000
Railroad substation -Add line relays $62,000
Canyon Compression substation -Add line relays $93,000
Canyon Compression-Railroad Loop In/Out $515,000
Total Network Upgrade $6,857,000
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Total Cost $8,740,000
*Any distribution line modifications identified in this report will require a field visit analysis in
order to obtain a more thorough understandingof the specific requirements.The estimate provided
above for this work could change substantially based on the results of this analysis.Until this field
analysis is performed the Transmission Provider must develop the project schedule using
conservative assumptions.The Interconnection Customer may request that the Transmission
Provider perform this field analysis,at the Interconnection Customer's expense,prior to the
execution of an Interconnection Agreement in order to obtain more cost and schedule certainty.
Note:Costs for any excavation,duct installation and easements shall be borne by the
Interconnection Customer and are not included in this estimate.This estimate is as accurate as
possibly given the level of detailed study that has been completed to date and approximates the
costs incurred by Transmission Provider to interconnect this GeneratorFacility to Transmission
Provider's electrical distribution or transmission system.A more detailed estimate will be
calculated during the Facilities Study.The Interconnection Customer will be responsible for all
actual costs,regardless of the estimated costs communicated to or approvedby the Interconnection
Customer.
5.1.3 Schedule
The Transmission Provider estimates it will require approximately 24 months to design,
procure and construct the facilities described in the Energy Resource sections of this report
followingthe execution of an Interconnection Agreement.The schedule will be further
developedand optimized during the Facilities Study.
Please note,the time required to perform the scope of work identified in this report appears
to result in a timeframe that does support the Interconnection Customer's requested
commercial operation date of October 1,2020.
5.1.4 Maximum Amount of Power that can be delivered into Network Load,with
No Transmission Modifications (for informational purposes only)
Zero (0)MW can be delivered on a firm basis to the Transmission Provider's network loads
without system improvements.
5.1.5 Additional Transmission Modifications Required to Deliver 100%of the
Power into Network Load (for informational purposes only)
In order to deliver 100%of the power into Network Load all improvements identified in
this report must be in service.
6.0 PARTICIPATION BY AFFECTED SYSTEMS
Transmission Provider has identified the followingaffected systems:None
7.0 APPENDICES
Appendix 1:Higher Priority Requests
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Appendix 2:Property Requirements
Appendix 3:Study Results
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7.1 Appendix1:HigherPriority Requests
All active higher priority transmission service and/or generator interconnection requests will be
considered in this study and are identified below.If any of these requests are withdrawn,the
Transmission Provider reserves the right to restudy this request,as the results and conclusions
containedwithin this study could significantlychange.
Transmission/GenerationInterconnection Queue Requests considered:
Q0720*(TSR -Q2060)*This project has been designated a network resource.
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7.2 Appendix2:Property Requirements
Property Requirementsfor Point of Interconnection Substation
Requirementsfor rights of way easements
Rights of way easements will be acquired by the Interconnection Customer in the Transmission
Provider's name for the construction,reconstruction,operation,maintenance,repair,replacement
and removal of Transmission Provider's Interconnection Facilities that will be owned and
operated by PacifiCorp.Interconnection Customer will acquire all necessary permits for the
project and will obtain rights of way easements for the project on Transmission Provider's
easement form.
Real Property Requirementsfor Point of Interconnection Substation
Real property for a POI substation will be acquired by an Interconnection Customer to
accommodate the Interconnection Customer's project.The real property must be acceptable to
Transmission Provider.Interconnection Customer will acquire fee ownership for interconnection
substation unless Transmission Provider determines that other than fee ownership is acceptable;
however,the form and instrument of such rights will be at Transmission Provider's sole
discretion.Any land rights that Interconnection Customer is planning to retain as part of a fee
property conveyance will be identified in advance to Transmission Provider and are subject to
the Transmission Provider's approval.
The Interconnection Customer must obtain all permits required by all relevantjurisdictionsfor
the planned use includingbut not limited to conditional use permits,Certificates of Public
Convenience and Necessity,California Environmental QualityAct,as well as all construction
permits for the project.
Interconnection Customer will not be reimbursed through network upgrades for more than the
market value of the property.
As a minimum,real property must be environmentally,physically,and operationally acceptable
to Transmission Provider.The real property shall be a permitted or permittable use in all zoning
districts.The Interconnection Customer shall provide Transmission Provider with a title report
and shall transfer property without any material defects of title or other encumbrances that are
not acceptable to Transmission Provider.Property lines shall be surveyed and show all
encumbrances,encroachments,and roads.
Examples of potentiallyunacceptable environmental,physical,or operational conditions could
include but are not limited to:
1.Environmental:known contamination of site;evidence of environmental
contamination by any dangerous,hazardous or toxic materials as defined by any
governmental agency;violation of building,health,safety,environmental,fire,
land use,zoning or other such regulation;violation of ordinances or statutes of
any governmental entities having jurisdiction over the property;underground or
above ground storage tanks in area;known remediation sites on property;ongoing
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mitigation activities or monitoring activities;asbestos;lead-based paint,etc.A
phase I environmental study is required for land being acquired in fee by the
Transmission Provider unless waived by Transmission Provider.
2.Physical:inadequate site drainage;proximity to flood zone;erosion issues;
wetland overlays;threatened and endangered species;archeological or culturally
sensitive areas;inadequate sub-surface elements,etc.Transmission Provider may
require Interconnection Customer to procure various studies and surveys as
determined necessary by Transmission Provider.
Operational:inadequate access for Transmission Provider's equipment and vehicles;existing
structures on land that require removal prior to building of substation;ongoing maintenance for
landscaping or extensive landscape requirements;ongoing homeowner's or other requirements or
restrictions (e.g.,Covenants,Codes and Restrictions,deed restrictions,etc.)on property which
are not acceptable to the Transmission Provider.
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7.3 Appendix3:Study Results
A Western Electricity Coordinating Council (WECC)approved 2021-22 Heavy winter case was
used to perform the power flow studies using PSS/E version 33.7.Power flow studies were
performed on both peak and off-peak load cases.The off-peak load case was chosen to demonstrate
the stress on the higher kV transmission system under light load conditions.
The local 345 kV,230 kV,138 kV and 115 kV transmission system outages were considered
during the study.Some of the local area contingencies considered for this study are listed below.
(1)N-1:Outage of the Q0715 -Railroad 138 kV line
(2)N-1:Outage of Q0715 -Canyon Compression 138 kV line
(3)N-1:Outage of Canyon Compression -Muddy Creek 138 kV line
(4)N-1:Outage of the Long Hollow -Painter 138 kV line
(5)N-1:Outage of the Painter -Railroad 138 kV line
(6)N-1:Outage of the Railroad 230/138 kV auto transformer
(7)N-1:Outage of the Birch Creek -Ben Lomond 230 kV line
(8)N-1:Outage of the Ben Lomond -Naughton 230 kV line
(9)N-1:Outage of the Naughton -Birch Creek 230 kV line
(10)N-2:Outage of the Ben Lomond -Birch Creek 230 kV line &Ben Lomond -Naughton
230 kV line
(11)N-2:Outage of the Ben Lomond -Syracuse 345 kV line &Populus -Terminal 345 kV
line
(12)N-2:Outage of the Ben Lomond -Terminal 345 kV #2 line &Ben Lomond -Syracuse
345 kV line
N-0 Results:No N-0 thermal or voltage issues were observed in the studies.
N-1 Results:No N-1 thermal or voltage issues were observed in the studies.
N-2 Results:The followingN-2 issue was observed in the studies.
The Evanston West path consists of three 230 kV lines:
Naughton -Treasureton
Naughton -Ben Lomond
Naughton -Birch Creek -Ben Lomond
For the N-2 outage of the Ben Lomond -Birch Creek 230 kV line and Ben Lomond -Naughton
230 kV line,and dependent on flow levels on the Evanston West path,an overload on the
remaining Naughton -Treasureton 230 kV line can occur.There is an existing remedial action
scheme (RAS),Naughton RAS,to drop generation for this N-2.The Q0715 Project must be
incorporated into the Naughton RAS as it will affect area flows.
Page 16 February 9,2018
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