20180307PAC to Staff UT Q715FEAS.pdf

PACIFICORPTRANSMISSION
Large Generator Interconnection
Feasibility Study Report
Completed for
("Interconnection Customer")
Q0715
Proposed Point of Interconnection
Canyon Compression-Railroad 138 kV transmission line
(At Whitney Canyon Tap Structure #121)
April 18,2016
PACIFICORPTRANSMISSION
Feasibility Study Report
TABLE OF CONTENTS
1.0 DESCRIPTION OF THE GENERATING FACILITY ..............................................................1
2 .0 SCOPEOFTHESTUDY ...............................................................................................................1
3.0 TYPE OF INTERC ONNE CTION SERVICE ..............................................................................1
4.0 DE SCRIP TION OF PROPOSED INTERC ONNE CTION.........................................................1
5.0 OTHER OPTIONS CONSIDERED (NERC REQUIREMENT)...............................................3
6.0 STUDY A SSUMPT I ONS ...............................................................................................................3
7.0 ENERGY RESOURCE (ER)INTERCONNECTION SERVICE..............................................4
7.1 REQUIREMENTS................................................4
7.1.1 Generating Facility Modifications.........................................4
7.1.2 Transmission System Modifications............................................6
7.1.3 Existing Circuit Breaker Upgrades -Short Circuit.........................................6
7.1.4 Protection Requirements.........................................6
7.1.5 Data (RTU)Requirements .......................................7
8.0 COSTEST IM ATE ..........................................................................................................................8
9.0 SCHEDULE .....................................................................................................................................9
9.1.1 Maximum Amount o Power that can be delivered into Network Load,with No Transmission
Modifications(or in ormational purposes only)...........................................................................9
9.1.2 Additional Transmission ModificationsRequired to Deliver 100%o the Power into Network Load
or in ormational purposes only)..............................................9
10.0 NETWORK RESOURCE (NR)INTERCONNECTION SERVICE .......................................10
11.0 REQUIREMENTS........................................................................................................................10
11.1.1 Generating Facility Modifications.........................................10
11.1.2 Transmission System Modifications.........................................10
11.1.3 Cost Estimate ............................................11
1 2 .0 SCHEDULE ...................................................................................................................................11
13.0 PARTICIPATION BY AFFECTED SYSTEMS........................................................................11
1 4.0 APPEND ICES ...............................................................................................................................11
14.1 APPENDIX 1:HIGHER PRIORITY REQUESTS..............................................12
14.2 APPENDIX 2:PROPERTYREQUIREMENTS.............................................13
14.3 APPENDIX 3:STUDY RESULTS .............................................15
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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
at Whitney Canyon Tap (Structure #121)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 July 1,2017.
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 Feasibility Study ("Study")report shall provide the followinganalyses for
the purpose of identifying any potential adverse system impacts that would result from the
interconnection of the GeneratingFacility as proposed:
preliminaryidentification of any circuit breaker short circuit capability limits exceeded as
a result of the interconnection;
preliminary identification of any thermal overload or voltage limit violations resulting
from the interconnection;and
preliminary description and non-binding estimated cost of facilities required to
interconnect the Generating Facility to the Transmission Provider's Distribution or
Transmission System and to address the identified short circuit and power flow issues.
3.0 TYPE OF INTERCONNECTION SERVICE
The Interconnection Customer has elected to have the interconnection studied as an Energy
Resource (ER)and a Network Resource (NR).The Interconnection Customer will select NR or
ER prior to the facilities study.
4.0 DESCRIPTION OF PROPOSED INTERCONNECTION
The Interconnection Customer's proposed Generating Facility is to be interconnected through a
new substation at the WhitneyCanyon Tap point in Uinta Countyon the Canyon Compression -
Railroad 138 kV transmission line.Figure 1 below,is a one-line diagram that illustrates the
interconnection of the proposed GeneratingFacility to the Transmission Provider's system.
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Whitney
Canyon
i Canyon Compression
Q0715 POI
Substation
Pointof
Interconnection
138 kV
I
Railroad
Changeof
Ownership 6 Miles
34.5 kV84/112/140 MVA138-34.5kV
Q0715 34.5 kV
Substation
Figure 1:Simplified System One Line Diagram
A new 138 kV substation will be required with four new line terminations and installation of four
new 138 kV circuit breakers along with associated switches.The Interconnection Customer will
own and operate a six-mile 138 kV transmission line from the collector system up to the Point of
Interconnection ("POI").Based on the one-line provided by the Interconnection Customer,the
six-mile line will also have a 138 kV circuit breaker at the collector substation.The Project
consists of one 84/112/140 MVA (ONAN/ONAFl/ONAF2)138/34.5 kV step-up transformer
with 9%impedance at the collector substation.The Project has sixty (60)2.0 MW GE wind
turbines,each turbine with a 2.3 MVA,34.5/0.69 kV,5.75%impedance generator step-up (GSU)
transformer.The total maximum output of the Project shall not exceed 120 MW.
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5.0 OTHER OPTIONS CONSIDERED(NERC REQUIREMENT)
The followingalternative options were considered as potential Points of Interconnection for this
Project:None.
6.0 STUDY ASSUMPTIONS
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
withdrawn,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 submitted prior to the
Interconnection Customer's generation interconnection request will be modeled in this
study.
o Generation Interconnection Queue:Interconnection Facilities associated with higher
queue interconnection requests 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 generatingresource as a Network Resource.Because the queue
of higher priority transmission service requests may be different when a Network Customer
requests Network Resource designation for this Generating Facility,the available capacity or
transmission modifications,if any,necessary to provide Network Resource Interconnection
Service may be significantly different.Therefore,the Interconnection Customer should
regard the results of this study as informational rather than final.
Under normal conditions,the Transmission Provider does not dispatch or otherwise directly
control or regulate the output of generation 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 Transmission Provider's system at the
proposed POI of WhitneyCanyon Tap (Structure 121).
The Interconnection Customer will construct and own any facilities required between the POI
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 Reliability Corporation ("NERC"),and the
Transmission Provider's performance and design standards.
A synchronous condenser at Standpipe Substation is planned to be in service in June 2016
and is assumed to be in service for this study.
The Energy Gateway West (2024)and Energy Gateway South (2024)projects are assumed to
be in service;the Dave Johnston to Amasa (future)to Heward (future)to Aeolus (future)230
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kV line is assumed to be rebuilt as part of the Gateway projects.Note that these dates are
inconsistent with the Q0715 project planned in-service date.
A Remedial Action Scheme (RAS)that will drop up to 600 MW of generation for the
followingoutages is assumed to be in service:
o Aeolus -Anticline 500 kV line
o Anticline -Populus 500 kV line
o Aeolus -Clover 500 kV line
o Clover 500/345 kV auto transformer
All system improvements associated with the prior queued projects are in service before
Q0715.
Based on the Federal Energy Regulatory Commission's proposed revisions to the Pro Forma
Large Generator Interconnection Agreement (Docket No RM16-1-000),the followingpower
factor requirement was assumed for the Project:
"9.6.1 Power Factor Design Criteria.Interconnection Customer shall design the
Large Generating Facility to maintain a composite power deliveryat continuous rated
power output at the Point of Interconnection at a power factor within the range of
0.95 leading to 0.95 lagging,unless Transmission Provider has established different
requirements that apply to all generators in the Control Area on a comparable basis.
Non-synchronous generators shall only be required to maintain the above power
factor when their output is above 10 percent of the Generating Facility Capacity."
The Railroad -Croyden -Silver Creek 138 kV line is assumed to be in service.
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
7.0 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-available basis.
Energy Resource Interconnection Service in and of itself does not convey transmission service.
7.1 REQUIREMENTS
7.1.1 Generating FacilityModifications
The Generating Facility and associated Interconnection Facilities owned by the
Interconnection Customer are required to operate under automatic voltage control with
the voltage sensed electricallyat the POI.Transmission Provider will require the facility
to operate in voltage control mode with the ability to deliver 100%of the power 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.)
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As required by NERC standard VAR-001-la,the Transmission Provider will provide a
voltage schedule for the POI.In general,Generating Facilities should be operated so as to
maintain the voltage at the POI,or other designated point as deemed appropriate by
Transmission Provider,between 1.00 pu to 1.04 pu.At the Transmission Provider's
discretion,these values might be adjusted depending on operating conditions.The
voltage control settings of the Generating Facility must be coordinated with the
Transmission Provider prior to energization (or interconnection).The reactive
compensation must be designed such that the discreet switching of the reactive device (if
required by the Interconnection Customer)does not cause step voltage changes greater
than +/-3%on the Transmission Provider's system.
At low output levels,the 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.Transmission Provider 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 Generating
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 multiple Generating Facilities,additional studies may be required to
determine whether or not 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.
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 backfeed.The list of approved generator models is continually
updated and is available on the http://www.WECC.bizwebsite.
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7.1.2 Transmission System Modifications
Construct a new four-breaker 138 kV POI ring bus substation at the Whitney Canyon
Tap (structure 121),with associated switches and line terminations (see Figure 1).
Reconductor the existing Silver Creek -Snyderville -Cottonwood 138 kV line.
o Rebuild approximately 2.5 miles of transmission line and jumpers that restrict the
line rating to 500 AAC conductor limits.
Modify the existing Naughton West RAS to integrate the Q0715 Project.If the
average of the flows on West of Naughton and West of Evanston is above 900 MW,
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 Q0715 Project if necessary under N-2 outages described above.
o Redundant communication from the RAS controller to the Project.
7.1.3 ExistingCircuit Breaker Upgrades -Short Circuit
The increase in the fault duty on 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
interrupting equipment.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.An inquiry is being made as to the capability of
the Interconnection Customer's equipment,therefore assumptions of equipment may
change.
7.1.4 Protection Requirements
The installation of protective relays for line fault detection will be required at the
Transmission Provider's new 138 kV POI substation for the protection of the lines to the
Interconnection Customer's collector substation and the lines to Railroad,Canyon
Compression,and Whitney Canyon substations.Transmission line current differential
relay systems will be implemented on the lines to the collector substation and Railroad
and Canyon Compression substations.The Transmission Provider will supply a panel
containing line relays that will be installed at the collector substation.The relays in this
panel will communicate with the relays at the POI substation over an optical fiber cable.
This optical fiber cable will need to be installed on the transmission line between the POI
and the collector substations.The line relays at Railroad and Canyon Compression
substations on the line positions to the POI substation will need to be replaced to be
compatible with the relays at the POI substation.Non pilotstep distance line relaying will
be applied for the Whitney Canyon substation line.The Interconnection Customer will
need to provide the outputs from two sets of current transformers on the transformer 138
kV breaker at the collector substation.These currents will be fed into the line relays.A
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three phase set of 138 kV voltage transformers will also be required at the collector
substation for the line relays.
Elements in the line relays at the POI substation will monitor the voltage on the line to
the collector substation.These elements will operate for under/over voltage and
over/under frequency.If the voltage,magnitude or frequency,is outside of the normal
operation range,these relays will send a transfer trip signal.The line relays at the
collector substation will receive the transfer trip signal and trip open all of the
Interconnection Customer's 34.5 kV line breakers at the collector substation.
The existing Naughton West RAS,located at Naughton substation,will be modified to
add another action function for the loss of the 230 kV transmission lines west of
Naughton substation.The new function will send a transfer trip signal to the POI
substation.The receipt of the transfer trip signal will cause the tripping of the two 138 kV
breakers for the tie line to the collector substation.
7.1.5 Data (RTU)Requirements
The installation of an RTU is required at the Transmission Provider's new POI
substation.With this RTU the Transmission Provider will remotely monitor and operate
the POI substation.Data for the operation of the power system will also be needed from
the collector substation.An RTU will also need to be installed in the collector substation.
In addition to the control and indication of the 138 kV breakers in the POI substation the
followingdata will be acquired through the RTU.Also listed is the data that will be
acquired from the collector substation.
From the POI substation:
Analogs:
Net GenerationMW
Net GeneratorMVAR
Interchangemetering kWH
A phase 138 kV transmission voltage
B phase 138 kV transmission voltage
C phase 138 kV transmission voltage
From the Q0715 collector substation:
Analogs:
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
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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
Average Plant Wind speed
Average Plant Atmospheric Pressure (Bar)
Average Plant Temperature (Celsius)
Status:
138 kV breaker
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
Line relay alarm
8.0 COST ESTIMATE
The following estimate 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.
Interconnection -Direct AssignmentFacilities
Q0715 collector substation -Add metering,RTU,line relays $621,000
Q0715 POI substation -Add metering $674,000
Sub-total Direct AssignmentCosts $1,295,000
Interconnection -Network Upgrade Costs
POI substation -Add 138 kV ring bus with four breakers $9,933,000
Canyon Compression substation -Replace relays $169,000
Naughton substation -Add Modify RAS $132,000
Railroad substation -Replace relays $259,000
Silver Creek -Snyderville -Cottonwood 138 kV line -Reconductor $4,307,000
Sub-total Network Upgrade Costs $14,800,000
Total Cost -ER Interconnection Service -Interconnection Only $16,095,000
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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 Generator Facility to Transmission
Provider's electrical distribution or transmission system.A more detailed estimate will be
calculated during the System Impact Study.The Interconnection Customer will be responsible
for all actual costs,regardless of the estimated costs communicated to or approved by the
InterconnectionCustomer.
9.0 SCHEDULE
Please note that the requirement that the Transmission Provider's Gateway project be complete
prior to interconnection of the Interconnection Customer's Project does not support the
Interconnection Customer's requested commercial operation date of July 1,2017.
9.1.1 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.
9.1.2 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,the followingtransmission
modifications are necessary:
The Energy Gateway projects must be in service.
Remedial Action Scheme (RAS)to drop up to 600 MW of generation in Wyoming
for the Gateway outages (this project may be included).
The system improvements associated with the prior queued projects must in service.
Construct a new four breaker 138 kV point of interconnection ring bus substation at
the Whitney Canyon Tap (structure 121)with associated switches and line
terminations (see Figure 1).
Reconductor the existing Silver Creek -Snyderville -Cottonwood 138 kV line.
a.Rebuild approximately 2.5 miles of transmission line and jumpers that restricts
the line rating to 500 AAC conductor limits.
Modify the existing Naughton West RAS to integrate the Q0715 Project.If the
average of the flows on West of Naughton and West of Evanston is above 900 MW,
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.
Capability to trip Q0715 Project if necessary under N-2 outages described above.
Redundant communication from the RAS controller to the Project.
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10.0 NETWORK RESOURCE(NR)INTERCONNECTION SERVICE
Network Resource Interconnection Service allows the Interconnection Customer to integrate its
large Generating Facility with the Transmission Provider's Transmission System in a manner
comparable to that in which the Transmission Provider integrates its generating facilities to serve
native load customers.The Transmission System is studied at peak load,under a variety of
severely stressed conditions.
11.0 REQUIREMENTS
11.1.1 Generating FacilityModifications
Refer to Section 6.1.1
11.1.2 Transmission System Modifications
In order to deliver 100%of the power into Network Load,the followingtransmission
modifications are necessary:
The Energy Gateway projects must be in service.
Remedial Action Scheme (RAS)to drop up to 600 MW of generation in Wyoming
for the Gateway outages (this project may be included).
The system improvements associated with the prior queued projects must in service.
Construct a new four breaker 138 kV ring bus substation at the WhitneyCanyon Tap
point(Structure 121).
a.Land for the construction of the new substation will be required.
b.Four new 138 kV breakers along with the associated switches and line
terminations (Figure 1).
Reconductor the existing Silver Creek -Snyderville -Cottonwood 138 kV line.
a.Rebuild approximately 2.5 miles of transmission line and jumpers that restricts
the line rating to 500 AAC conductor limits.
Modify the existing Naughton West RAS to integrate the Q0715 Project.If the
average of the flows on West of Naughton and West of Evanston is above 900 MW,
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 Q0715 Project if necessary under N-2 outages described above.
Additionally,while not the responsibility of the Q0715 Project,it is noted that mitigation
of the following credible N-2 outages must be in service prior to interconnection:
o Ben Lomond -Syracuse 345 kV line +Populus -Terminal 345 kV line
These outages cause overload on the Ben Lomond -Warren 138 kV line.This is an
existing issue and the addition of the Q0715 exacerbates the thermal overload observed
on the line by 3%of its emergency rating.
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The N-2 outage of Ben Lomond -Terminal #2 345 kV line +Ben Lomond -Syracuse
345 kV line causes overload on the following138 kV line segments:
Ben Lomond -Warren 138 kV line
Warren -West Ogden 138 kV line
West Ogden -Midline 138 kV line
Midline -Clinton East Tap 138 kV line
Clinton East Tap -Syracuse 138 kV line
This is an existing issue and the addition of the Q0715 exacerbates the thermal overload
observed on these segments by 3%of its emergency rating.
Should this issue not be resolved by previously queued customers or should the
Interconnection Customer wish to move forward on a faster timeline that the previous
queued customers,then mitigation of this issue will be the responsibility of the
Interconnection Customer.
11.1.3 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.
If all assumed modifications have been completed (includingthe Transmission Provider's
Energy Gateway projects),all modifications for previously queued generation
interconnection projects are complete,all modifications identified in section 6.0 are
complete,and all necessary transmission capacity is available to provide Network
Resource Interconnection Service is in place,then no additional costs are expected.
12.0 SCHEDULE
Please note that the requirement that the Transmission Provider's Gateway project be complete
prior to interconnection of the Interconnection Customer's Project does not support the
Interconnection Customer's requested commercial operation date of July 1,2017.
13.0 PARTICIPATION BY AFFECTED SYSTEMS
Transmission Provider has identified the followingas Affected Systems:None
14.0 APPENDICES
Appendix 1:Higher Priority Requests
Appendix 2:Property Requirements
Appendix 3:Study Results
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14.1 APPENDIX 1: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:
Q0199 (200 MW)
Q0200 (100 MW)
Q0201 (100 MW)
Q0290 (252 MW)
Q0306-A (48.3 MW)
Q0335 (49.6 MW)
Q0375 (230 MW)
Q0409 (320 MW)
Q0706 (250 MW)
Q0707 (250 MW)
Q0708 (250 MW)
Q0712 (750MW)
Q0713 (350 MW)
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14.2 APPENDIX 2:PROPERTYREQUIREMENTS
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 point of interconnection 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 relevant jurisdictions for
the planned use including but not limited to conditional use permits,Certificates of Public
Convenience and Necessity,California Environmental Quality Act,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 potentially unacceptable 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
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any governmental entities having jurisdiction over the property;underground or
above ground storage tanks in area;known remediation sites on property;ongoing
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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14.3 APPENDIX 3:STUDY RESULTS
A Western Electricity Coordinating Council (WECC)approved 2015 Heavy Summer 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 lightload conditions.
The study was performed assuming the Energy Gateway Projects are in-service.The local 500
kV,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.
A complete list of contingencies studied for this Project can be found in Appendix 3A.
N-0 Results:Assuming Energy Gateway and the system improvements associated with the prior
queued projects are in service,no N-0 thermal or voltage issues were observed in the studies.
N-1 Results:Assuming Energy Gateway and the system improvements associated with the prior
queued projects are in service,the followingN-1 issues were observed in the studies:
The outage of the Ben Lomond -Birch Creek 230 kV line results in the overload of the
Silver Creek -Snyderville Tap -Cottonwood 138 kV line.The outage of the 230 kV line
causes additional flow on the local 138 kV system which overloads the Silver Creek -
Snyderville Tap -Cottonwood 138 kV line.The line rating is limited by 2.5 miles of
transmission line build with 500 AAC conductor which needs to be rebuild.Also,jumper
limitingthe line rating also needs to be replaced.Figure 2 below shows the changes in the
power flow due to the outage.
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67153GLENCO>D7 7 937-5
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Figure 2:Ben Lomond -Birch Creek 230 kV line outage
Depending on the operating condition,the outage of the Long Hollow -Painter Tap -Painter 138 kV line overloads the Q0715
POI -Railroad 138 kV line above its four-hour emergency rating but does not overload above its 30 minute emergency rating.
The outage of the 138 kV line causes all of the generation from Hinshaw and Mountain Wind Generating Facilities to flow
toward the Canyon Compression Tap,overloading the Q0715 -Railroad 138 kV line above its 4-hour emergency rating.
Figure 3 demonstrates the overload seen on the 138 kV line.Under this operating condition,the Project will be required to
curtail,in order to bring the Q0715 POI -Railroad 138 kV line below its continuous rating.
Page 17 April 18,2016
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6753GLENCOE7-7 9"7'S
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Figure 3:Long Hollow -Painter 138 kV line outage.
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Depending on the real time outages and operating conditions,certain N-1-1 outage may
require curtailment of Q0715.
N-2 Results:Assuming Energy Gateway and the system improvements associated with the prior
queued projects are in service,the followingN-2 thermal issues were observed in the studies.
For the N-2 outage of the Ben Lomond -Birch Creek 230 kV line and Ben Lomond -
Naughton 230 kV line,there is an existing Naughton West RAS that drops the following
generators:
o Part of Naughton generation
o Mountain Wind generation
o Hinshaw generation
In order to interconnect the Project and alleviate the thermal overload due to the outage
mentioned above,the Naughton West RAS must be modified to include the Q0715
Project.
The credible N-2 outage of Ben Lomond -Syracuse 345 kV line +Populus -Terminal
345 kV line causes overload on the Ben Lomond -Warren 138 kV line.This is an
existing issue and the addition of the Q0715 exacerbates the thermal overload observed
on the line by 3%of its emergency rating.Mitigationof this issue must be in service prior
to mterconnection.
The credible N-2 outage of the Ben Lomond -Terminal #2 345 kV line +Ben Lomond -
Syracuse 345 kV line causes overload on the following138 kV line segments:
o Ben Lomond -Warren 138 kV line
o Warren -West Ogden 138 kV line
o West Ogden -Midline 138 kV line
o Midline -Clinton East Tap 138 kV line
o Clinton East Tap -Syracuse 138 kV line
This is an existing issue and the addition of the Q0715 exacerbates the thermal overload
observed on these segments by 3%of its emergency rating.Mitigationof this issue must
be in service prior to interconnection.
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