20180329PAC to Staff UT Q713SIS.pdf

PAciFICORP
System Impact Study Report
Large Generator Interconnection
System Impact Restudy Report
Completed for
("Interconnection Customer")
Q0713
Proposed Point of Interconnection
Yellowcake -Antelope Mine 230 kV transmission line
(POI at approx.43.113 N,105.425 W)
January 29,2018
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TABLE OF CONTENTS
1.0 DESCRIPTION OF THE GENERATING FACILITY ..............................................l
2.0 SCOPE OF THE STUDY.....................................................l
3.0 TYPE OF INTERCONNECTION SERVICE ...............................................2
4.0 DESCRIPTION OF PROPOSED INTERCONNECTION...............................................2
5.0 OTHER OPTIONS CONSIDERED ..............................................4
6.0 STUDY ASSUMPTIONS...................................................................................4
7.0 ENERGY RESOURCE (ER)INTERCONNECTION SERVICE...............................................5
7.1 Requirements .......................................................5
7.1.2 Generating Facility Modifications 5
7.1.3 Transmission System Modifications 7
7.1.4 Transmission Requirements 8
7.1.5 Existing Circuit Breaker Upgrades -Short Circuit 8
7.1.6 Protection Requirements 8
7.1.7 Data (RTU)Requirements 9
7.1.8 Substation Requirements 11
7.1.9 Communication Requirements 12
7.1.10 Metering Requirements 13
7.2 Cost Estimate (ER).............................................15
7.3 Schedule.................................................................................................................................16
7.3.1 Maximum Amount of Power that can be deliveredinto NetworkLoad,with No Transmission
Modifications(for informationalpurposes only)16
7.3.2 Additional Transmission ModificationsRequired to Deliver 100%of the Power into Network
Load (for informationalpurposes only)16
8.0 PARTICIPATION BY AFFECTED SYSTEMS..............................................16
9.0 APPENDICES .........................................................16
9.1.1 Appendix 1:HigherPriority Requests 17
9.1.2 Appendix 2:Property Requirements 18
9.1.3 Appendix 3:Study Results 20
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1.0 DESCRIPTION OF THE GENERATING FACILITY
("Interconnection Customer")proposed interconnecting 350 MW of new generation to
PacifiCorp's ("Transmission Provider")Yellowcake -Antelope Mine 230 kV transmission line
(Point of Interconnection at approx.43.113 N,-105.425 W)located in Converse County,
Wyoming.The project ("Project")will consist of one hundred forty (140)GE 127 2.5 MW wind
turbines for a total output of 350 MW.The requested commercial operation date is December 31,
2020.
The restudy of this Project is performed due to the staging of the Energy Gateway West project.
Specifically,while the entire Gateway West project has a longer developmenttimeline,the Aeolus-
Bridger/AnticlineD.2 segment of the project (500 kV segment from the planned Aeolus substation
to the planned Anticline substation)now has an expected 2020 in-service date.The earlier
availability of the D.2 segment materiallychanges certain modeling assumptions that could impact
the cost or timing of the interconnection of certain projects whose previous studies depended on
Gateway West in its entirety.
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 "Q0713."
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.
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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.
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 Point of Interconnection ("POI")substation between Yellowcake and Antelope Mine 230 kV
substations.Figure 1 below,is a one-line diagram that illustrates the interconnection of the
proposed Generating Facility to the Transmission Provider's system.
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0713 POI Substation
Yellowcake 230 kV
-I Antelope Mine
Point ofChangeofInterconnectionOwnership
Tie Line Substation
7 3 Miles
Q0713 Substation
34.5kV
colrcecor
colriector
Figure l Simpli ied System One Line Diagram
,Q0713
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5.0 OTHER OPTIONS CONSIDERED
The followingalternative options were considered as potential points of interconnection for this
Project:None
6.0 STUDYASSUMPTIONS
All active higher priority transmission service and/or generator interconnection requests with
an in-service date of December 2020 or earlier will be considered in this study and are listed
in Appendix 1.If any of these requests are materiallymodified 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
queued 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.2 500 kV line from the proposed
Aeolus substation to the proposed Anticline substation and ancillary projects are assumed in
service in 2020.
All system improvements associated with the prior queued projects are in service before
Q0713.This includes a new Aeolus -Shirley Basin #2 230 kV line with 2xl557 ACSR
(Q0707),rebuild of the Standpipe-Freezeout-Aeolus 230 kV line to 2x1272 (Q0712),and
rebuild of the Aeolus -Shirley Basin #1 230 kV line with 2xl557 ACSR (Q0712).
All existing and proposed Remedial Action Schemes ("RAS")associated with prior queue
generation facilities are assumed to be in service for this study.
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A RAS that will arm approximately 640 MW of generation for the Energy Gateway D.2
outages was 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.
7.1 Requirements
7.1.2 GENERATINGFACILITY MODIFICATIONS
All interconnecting synchronous and non-synchronous generators are required to
design their Generating Facilities with reactive power capabilities necessary to
operate within the full power factor range of 0.95 leading to 0.95 lagging.This
power factor range shall be dynamic and can be met using a combination of the
inherent dynamic reactive power capability of the generator or inverter,dynamic
reactive power devices and static reactive power devices to make up for losses.
For synchronous generators,the power factor requirement is to be measured at the
Point of Interconnection.For asynchronous generators,the power factor
requirement is to be measured at the high-side of the generator substation.The
Generating Facility must provide dynamic reactive power to the system in support
of both voltage scheduling and contingency events that require transient voltage
support,and must be able to provide reactive capability over the full range of real
power output.
If the Generating Facility is not capable of providing positive reactive support (i.e.,
supplying reactive power to the system)immediately followingthe removal of a
fault or other transient low voltage perturbations,the Generating Facility must be
required to add dynamic voltage support equipment.These additional dynamic
reactive devices shall have correct protection settings such that the devices will
remain on line and active during and immediately followinga fault event.
Generators shall be equipped with automatic voltage-control equipment and
normallyoperated with the voltage regulation control mode enabled unless written
authorization from the Grid Operator is given to operate in other control mode (e.g.
constant power factor control).The control mode of the generating units shall be
accurately represented in operating studies.The generators shall be capable of
operating continuouslyat their maximum power output at its rated field current
within +/-5%of its rated terminal voltage.
As required by NERC standard VAR-001-la,the Transmission Provider will
provide a voltage schedule for the Point of Interconnection.In general,Generating
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Facilities should be operated so as to maintain the voltage at the Point of
Interconnection,or other designated point as deemed appropriated by Transmission
Provider,between 1.00 per unit to 1.04 per unit.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.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 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.If the need for a master
controller is identified,the cost and all related installation requirements will be the
responsibility of the Interconnection Customer.Participation by the Generating
Facility in subsequent interaction/coordination studies will be required pre-and
post-commercial operation in order ensure system reliability.
To facilitate collection and validation of accurate modeling data to meet NERC
modeling standards,PacifiCorp,as the Planning Coordinator,requires Phasor
MeasurementUnits (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 Generator
Facility'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 generators must meet the Federal Energy Regulatory Committee ("FERC")and
WECC low voltage ride-through requirements as specified in the interconnection
agreement.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 continually updated and is available on the
http://www.WECC.bizwebsite.
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Based on the turbine specification data provided by the Interconnection Customer,
the wind turbines do not have the capability to deliver 100%of the power to the
Point of Interconnection within the range of +/-0.95 power factor.The data
provided indicates that the wind turbines have a power factor capability of 0.98
capacitive and 0.96 inductive at rated power.
The study showed that the collector system injects approximately 17.2 MVAr (see
Figure 3 in Appendix 3)when it is connected to the transmission system without
the wind turbines being online.The Interconnection Customer will be required to
ensure that there is minimum reactive interchange under these conditions and that
the collector system of the Project is not contributing excessive reactive power into
the system increasing voltage under lightload conditions.Failure of the Project to
minimize the reactive interchangeunder these conditions may result in the opening
of the POI breakers for the Project by the grid operator.
At low output level,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.PacifiCorp has experienced high
voltages in the Wyomingarea when the transmission system is lightly loaded with
low wind conditions.With low wind conditions the wind farms tend to supply
reactive power into the transmission system increasing the voltage.
The Interconnection Customer is responsible for the protection of the transmission
line between the GeneratingFacility 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
7.1.3 TRANSMISSIONSYSTEM MODIFICATIONS
Construct a new POI substation with 3-breakerring bus configuration between
Yellowcake and Antelope Mine substations (refer to Figure 1).
Expansion of the Windstar 230 kV substation with a new 230 kV bus.
Addition of two new 230 kV breakers at Windstar substation.
A new line termination at Windstar substation.
A new line termination at Shirley Basin substation and one 230 kV circuit
breaker.
Construction of a new,60-mile Windstar -Shirley Basin 230 kV line with 2-
1272 ACSR (AluminumConductor Steel Reinforced).
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Additionally,the Q0713 project triggers the need for the Transmission Provider's
planned Energy Gateway South project.This project consists of a new 400 mile
500 kV transmission line from the planned Aeolus substation in Wyoming to the
Transmission Provider's existing Clover substation in central Utah,with ancillary
improvements.
7.l .4 TRANSMISSIONREQUIREMENTS
Construct approximately 1,200 feet of 230 kV transmission line to loop-in the
existing Antelope-Yellowcake 230 kV line to the Q0713 POI substation.This will
require two guyed wood pole main line structures near structure 1/33 and a new
guyed wood pole structure at each end of the POI sub.
Construct approximately 60 miles of 230 kV transmission line from Windstar
substation to Shirley Basin substation.Conductor shall be double bundle 1272
ACSR "Bittern"Conductor.
The Interconnection Customer shall construct the tie line from the collector
substation to the tie-line substation.
The Interconnection Customer is required to build tie-line substation adjacent to the
new POI substation which will house the tie-line circuit breaker.The Transmission
Provider shall review the design of the tie-line span between the tie-line substation
deadend tower and the new 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 new 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.
7.1.5 EXISTING CIRCUITBREAKER UPGRADES -SHORT CIRCUIT
The increase in the fault duty on the system as a result of the addition of the
Generating Facility with 140 GE 127 2.5 MW wind turbine generators fed through
140 -2600 kVA 34.5 kV -690 V transformers with 9.0%impedance then fed
through two 230 -34.5kV 120/115/200 MVA step up transformers with 8.0%
impedance will not push the fault duty above the interrupting rating of any of the
existing fault interruptingequipment.
7.l.6 PROTECTIONREQUIREMENTS
The installation of protective relays for line fault detection will be required at the
Transmission Provider's new 230 kV POI substation for the protection of the line
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to the Interconnection Customer's collector substation and the lines to Windstar
and Teckla substations.
The ground mats of the tie-line substation and the Q0713 POI substation must be
tied together so that metallic control cables can be used between the two facilities.
Bus differential relays will be applied to detect faults on this connection.With this
arrangement the Interconnection Customer must install line relays systems that will
detect and clear all faults on the tie lines in 5 cycles or less.A set of non-pilotstep
distance line relays that will detect faults on the tie-line will also be applied at the
Q0713 POI substation.Should the Interconnection Customer desire a potential
alternative to the tie line substation in order to provide adequate protection to its
tie-line,the Interconnection Customer may petition the Transmission Provider for
an exemption to this arrangement.The Transmission Provider must review and
approve the Interconnection Customer's proposed alternative.Without approval of
the proposed alternative the tie-line substation configuration will be required.The
Interconnection Customer will need to supply and maintain sets of line relays to be
installed at Q0713 collector substation that will detect faults on the 230 kV line
back to the Q0713 POI substation.These line relays can be time coordinated with
the relays detecting faults on the transmission network and will not communicate
with the line relays to be installed at the Q0713 POI substation for the tie-line.
Protective relay elements in the line relays at the Q0713 POI substation will monitor
voltage and frequency.If the voltage,magnitude or frequency is outside of the
normal operation range,this relay will trip the 230 kV breaker at the tie line
substation.
The lines to Windstar and Teckla substations will continue to use permission over
reaching logic line distance relays so the existing relays at Windstar and Teckla
substations will require setting adjustments to accommodate addition of the POI
substation.
The new 230 kV line between Windstar and Shirley Basin substations will be
protected with a line current differential relay system.
7.1.7 DATA (RTU)REQUIREMENTS
Data for the operation of the power system will be needed from the Generating
Facility and the new POI substation.The Interconnection Customer will install a
Transmission Provider approved data concentrator at the collector substation and
will install OPGW between the collector substation and tie line substation.The
data will then be tied into a Transmission Provider owned RTU at the new POI
substation.
In addition to the control and indication of the new 230 kV breakers at the POI
substation,the followingdata will be acquired through the POI substation RTU.
Also listed is the data that will be acquired from the collector substation.
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From POI substation:
Analogs:
Net GenerationMW
Net GeneratorMVAr
Energy Register
From the Q0713 collector substation:
Analogs:
Transformer l Real power
Transformer l Reactive power
Transformer 2 Real power
Transformer 2 Reactive power
34.5 kV Real power 52 Al &N
34.5 kV Reactive power 52 Al &N
34.5 kV Real power 52 A2 &C
34.5 kV Reactive power 52 A2 &C
34.5 kV Real power 52 D
34.5 kV Reactive power 52 D
34.5 kV Real power 52 E
34.5 kV Reactive power 52 E
34.5 kV Real power 52 F
34.5 kV Reactive power 52 F
34.5 kV Real power 52 G
34.5 kV Reactive power 52 G
34.5 kV Real power 52 H
34.5 kV Reactive power 52 H
34.5 kV Real power 52 I
34.5 kV Reactive power 52 I
34.5 kV Real power 52 J
34.5 kV Reactive power 52 J
34.5 kV Real power 52 K
34.5 kV Reactive power 52 K
34.5 kV Real power 52 L &Bl
34.5 kV Reactive power 52 L &Bl
34.5 kV Real power 52 M &B2
34.5 kV Reactive power 52 M &B2
34.5 kV Reactive power 52 CAP l
34.5 kV Reactive power 52 CAP 2
A phase 230 kV transmission voltage
B phase 230 kV transmission voltage
C phase 230 kV transmission voltage
Average Wind speed
Average Plant Atmospheric Pressure (Bar)
Average Plant Temperature (Celsius)
Status:
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230 kV Transformer Breaker 1
230 kV Transformer Breaker 2
34.5 kV breaker 52 Al &N
34.5 kV breaker 52 A2 &C
34.5 kV breaker 52 D
34.5 kV breaker 52 E
34.5 kV breaker 52 F
34.5 kV breaker 52 G
34.5 kV breaker 52 H
34.5 kV breaker 52 I
34.5 kV breaker 52 J
34.5 kV breaker 52 K
34.5 kV breaker 52 L &Bl
34.5 kV breaker 52 M &B2
34.5 kV breaker 52 CAP 1
34.5 kV breaker 52 CAP 2
34.5 kV breakerBus Tie
Line Relay Alarm
From the Tie Line Substation
Status:
230 kV Breaker
7.1.8 SUBSTATIONREQUIREMENTS
90713 POI Substation:
To support the requested interconnection,the Project will require a new 230kV,
three breakerring bus POI substation.The substation will be approximately 270'x
470'(fence dimensions)based on the Interconnection Customer provided facility
requirements.The followingis a list of the major equipment required for this
Project:
3 -230kV Power Circuit Breakers
6 -230kV CCVTs
3 -230kV CT/VT Metering units
13 -230kV Switches
9 -230kV Lightning Arresters
l -230kV SSVT
l -Microwave Communication System
90713 Collector Station:
The Interconnection Customer will provide a separate graded,groundedand fenced
area along the perimeter of the Interconnection Customer's Generating Facility for
the Transmission Provider to install metering equipment.This area will share a
fence and ground grid with the Generating Facility and have separate,
unencumbered access for the Transmission Provider.AC station service for the
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control house will be supplied by the Interconnection Customer.DC power for the
control house will be supplied by the Transmission Provider.
Windstar Substation:
Install a new 230kV bay and line position to support a new 230kV line to Shirley
Basin substation.The followingmajor material will be required for this Project:
2 -230kV Power Circuit Breakers
3 -230kV CCVTs
5 -230kV Switches
3 -230kV Lightning Arresters
Shirlev Basin Substation:
Install a new 230kV bay and line position to support a new 230kV line to Windstar
substation.The followingmajor material will be required for this Project:
l -230kV Power Circuit Breaker
3 -230kV CCVTs
5 -230kV Breaker Disconnect Switches
l -Motor Operated Line Disconnect Switch
3 -230kV Lightning Arresters
l -Line Relay Panel
l -Breaker Control Panel
7.1.9 COMMUNICATIONREQUIREMENTS
The Interconnection Customer is required to install OPGW between the POI
substation and the collector substation.ADSS fiber is required between the tie-line
substation and the POI substation.The Interconnection Customer is to supply 2 -
DNP3 circuits from the collector substation to the tie line substation and into the
POI substation building with the SCADA points required.
Communications to the Transmission Provider's existing communications will be
achieved through microwave.A new microwave communication system will be
installed at the POI substation.The POI microwave will connect to the
Transmission Provider's Flat Top communications site.The microwave tower at
Flat Top will need to be replaced.The path will then connect to the Transmission
Provider's Glenrock communications site and on through the existing system.The
existing microwave between Glenrock and Flat Top will be upgraded to a 6 Ghz
space diversity path.
Communication circuits are required between the POI,Windstar and Teckla
substations over the new microwave.Multiplexes,routers and channel banks will
be required at the POI,Teckla,and collector substations.At the POI substation a
48volt battery and charger is required for communication.At the collector
substation the Interconnection Customer will supply AC voltage for the
commumcation equipment.
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7.1.10 METERINGREQUIREMENTS
InterchangeMetering
Point of Interconnection will be at the Transmission Provider Q0713 substation.
Metering will be designed bidirectional and rated for the total net generationof the
Project.The bidirectional metering will also include the retail load (per tariff)
delivered to the Interconnection Customer.The Transmission Provider will specify
and order all interconnection revenue metering,including the instrument
transformers,metering panels,junction box and secondary metering wire.The
primary metering transformers shall be combination 1000:5 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 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,MVA,includingper phase
voltage and amps data.
An Ethernet connection is required for retail sales and generation accounting via
the MV-90 translation system.
Q0713 Transformer A metering:
Revenue metering is required on the high side of the step-up transformers.The
primary metering transformers shall be combination 230kV,500:5 CT/VT
extended range for high accuracy metering.
The Transmission Provider will design and procure the collector revenue metering
panels.The panels shall be located inside the collector control house.The collector
substation metering panel shall include two revenue quality meters,test switches,
and all SCADA metering data terminated at a metering interposition block.An
Ethernet phone line is required for retail sales and generation accounting via the
MV-90 translation system.
Q0713 Transformer B metering:
Revenue metering is required on the high side of the step-up transformer.The
primary metering transformers shall be combination 230kV,500:5 current ratio,
CT/VT extended range for high accuracy metering.
The Transmission Provider will design and procure the collector revenue metering
panels.The panels shall be located inside the collector control house.The collector
substation metering panel shall include two revenue quality meters,test switches,
and all SCADA metering data terminated at a metering interposition block.An
Ethernet phone line is required for retail sales and generation accounting via the
MV-90 translation system.
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Station Service/Construction Power
The Project is within the Transmission Provider service territory.Please note,prior
to back feed Interconnection Customer must arrange transmission retail meter
service for electricityconsumed by the Project and arrange back up 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 1-800-625-6078to arrange this service.Approval for back feed is contingent
upon obtaining station service.
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7.2 CosT ESTIMATE (ER)
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
Q0713 Collector substation $1,218,000
Add metering and control house
Q0713 POI substation $837,000
Add POI terminal and metering
Total Direct Assigned $2,055,000
Network Upgrade
Q0713 POI substation $9,702,000
Add 230kV ring bus substation
Yellowcake -AntelopeMine transmission line $399,000
Loop transmission line in/out ofPOI substation
Windstar to Shirley Basin 230kV line $28,726,000
Build 60 miles ofnew 230 kV line
Windstar substation $4,194,000
Add new line position,update relaysettings
Shirley Basin substation $2,120,000
Add new line position
Flat Top substation $904,000
Upgrade communications equipment
Teckla substation $48,000
Upgrade communications equipment,update relay settings
Glenrock substation $174,000
Upgrade communications equipment
Total Network Upgrade $46,267,000
Grand Total $48,322,000
*Any distribution line modifications identified in this report will require a field visit analysis in
order to obtain a more thorough understanding of 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.
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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 Generating Facility 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.
7.3 SCHEDULE
The Transmission Provider estimates it will require approximately 60-78 months to permit,
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 developed and optimized during the Facilities Study.
Please note,the time required to perform the scope of work identified in this report as well
as the current anticipated in-service date of the Transmission Provider's Gateway South
transmission line (2024)does not support the Interconnection Customer's requested
Commercial Operation date of December 31,2020.
7.3.1 MAXIMUMAMOUNT OF POWER THAT CAN BE DELIVERED INTO NETWORK
LOAD,WITH No TRANSMISSIONMODIFICATIONS(FOR INFORMATIONAL
PURPOSES ONLY)
Zero (0)MW can be delivered on a firm basis to the Transmission Provider's
network loads with additional transmission modifications.
7.3.2 ADDITIONAL TRANSMISSIONMODIFICATIONSREQUIREDTO DELIVER 100%
OF THE POWER INTO NETWORKLOAD (FOR INFORMATIONAL PURPOSES
ONLY)
In order to deliver 100%of the power into Network Load,in addition to the
mitigation identified in section 5.1.1.2,the completion of additional Transmission
Provider Energy Gateway projects and other system improvements would also be
required.
8.0 PARTICIPATION BY AFFECTED SYSTEMS
Transmission Provider has identified the followingaffected systems:WAPA,Black Hills,Tri-
State,and Basin Electric
A copy of this report will be shared with each Affected System.
9.0 APPENDICES
Appendix 1:Higher Priority Requests
Appendix 2:Property Requirements
Appendix 3:Study Results
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9.1.1 APPENDIX 1:HIGHERPRIORITYREQUESTS
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:
Q0542 (240 MW)-QF/NR
Q0706 (250 MW)-ER
Q0707 (250 MW)-ER
Q0708 (250 MW)-ER
Q0712 (520 MW)-ER
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9.1.2 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 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 relevantjurisdictionsfor 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 able to be permitted 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
governmentalagency;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
mitigation activities or monitoring activities;asbestos;lead-based paint,etc.A
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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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9.1.3 APPENDIX3:STUDYRESULTS
Power Flow 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.The 2015 Heavy Summer case
was modified for the study.
Power flow studies were performed on both peak and off-peak load cases.The study was
performed assuming the Energy Gateway D.2 Projects are in-service.The local 500 kV,345 kV,
230 kV and 115 kV transmission system outages were considered during the study.
N-0 Results:
Under N-0 conditions with the Q0713 project in service there is a 101%overload on the Difficulty
-Amasa 230 kV line.A new approximately 60-mile 230 kV line from Windstar to Shirley Basin
constructed with 2-1272 ACSR will mitigate this issue as well as some N-1 issues discussed
below.
The data provided by the Interconnection Customer indicated that the generator does not have
adequate reactive capability to deliver 100%of its power output at +/-0.95 power factor.Hence,
external shunt compensation which is dynamic in nature will be required in order to control the
voltage and provide adequate reactive capability to maintain the voltage at the POI with a +/-0.95
power factor on the high side of the step-up transformer.
Figure 3 below,shows injection of approximately 17.2 MVAr into the transmission system was
observed if the collector system was connected with no generation from the Project.The addition
of 17.2 MVAr on the transmission system under light load conditions could cause high voltages.
The Project must control the voltage at the POI within the required voltage range provided by the
Transmission Operator.
N-1 Results:Assuming Energy Gateway D.2 segment and the system improvements associated
with the prior queued projects are in service,the followingissues were identified.
o Outage of the Amasa -Difficulty-Shirley Basin 230 kV line overloads the Dave Johnston
South Tap -Refinery Tap to 101%.Low voltages in the Spence -Buffalo Head area also
observed.The new Windstar -Shirley Basin 230 kV line identified as mitigation under
the N-0 results will resolve these issues.
Outage of the Aeolus -Anticline 500 kV line,the Aeolus 230/500 kV transformer or the
Anticline 345/500 kV transformer,post generation dropping of 640 MW (Aeolus RAS),
results in multiple230 kV line overloads.Construction of the Transmission Provider's
planned Energy Gateway South 500 kV line from Aeolus to Clover,approximately 400
miles,will mitigate these issues.
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N-2 Results:No N-2 thermal or voltage issues were observed in the studies.
65060 1.010
ANT MINE 232.20
99749
Q0713_P0l
99750 99751 99752 99753
-100.34 Q0713 COL Q0713 COL Q0713 GEN Q0713 GEN
30.11 0.01 -0.00 0.00 e e -0.00 0.00 -0.00 -0.00 e «0.00
-17.17 15.69 -15.69 a e 15.77 -15.77 -0.00 0.00 -0.00
100.33
-12.94 1.021 1.026 1.026 1.026
234.75 35.39 35.40 0.71
1.019
234.37
66745 o 1.019
YELLOWCK '"234.40
Figure 3:Chargingfrom Q713 collector systems
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