HomeMy WebLinkAbout20210920PAC to Bayer 117-1 Q0542 Bowler Flats LGI SIS Final to Cust.pdf
Large Generator Interconnection
System Impact Study Report
Completed for
Bowler Flats Energy Hub, LLC
Bowler Flats Energy Hub
LGIQ# Q0542
Proposed Interconnection
To the Existing
230 kV Frannie - Yellowtail
Transmission Line
August 19, 2014
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TABLE OF CONTENTS
1.0 DESCRIPTION OF THE GENERATING FACILITY .................................................................... 1
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 (NERC Requirement) ...................................................................... 2
5.0 STUDY ASSUMPTIONS ................................................................................................................. 2
5.1 Energy Resource (ER) Interconnection Service ......................................................................... 5
5.1.1 Study Results 5
5.1.2 Requirements 10
5.1.1 Cost Estimate 18
5.1.2 Schedule 19
5.1.3 Maximum Amount of Power that can be delivered into Network Load, with No Transmission
Modifications (for informational purposes only). 19
5.1.4 Additional Transmission Modifications Required to Deliver 100% of the Power into Network
Load (for informational purposes only) 20
5.2 Network Resource (NR) Interconnection Service .................................................................... 21
5.2.1 Study Results 21
5.2.2 Network Resource Requirements 23
5.2.3 Network Resource Cost Estimate 27
5.2.4 Schedule 28
6.0 PARTICIPATION BY AFFECTED SYSTEMS ............................................................................ 28
7.0 APPENDIX 1: PROPERTY REQUIREMENTS ............................................................................ 29
8.0 APPENDIX 2: COMBINED QUEUE ............................................................................................ 31
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1.0 DESCRIPTION OF THE GENERATING FACILITY
Bowler Flats Energy Hub, LLC (“Interconnection Customer”) proposed interconnecting 240
MWs of new generation to PacifiCorp’s (“Transmission Provider”) Frannie – Yellowtail 230 kV
transmission line approximately 2.75 miles north of the Frannie substation located in Park
County, Montana. The Bowler Flats Energy Hub project (“Project”) will consist of 120 Gamesa
2.0 G114 wind turbine generators for a total output of 240 MWs. The requested commercial
operation date is approximately December 1, 2015.
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 “Q0542.”
2.0 SCOPE OF THE STUDY
The interconnection system impact study 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,
an identified network upgrades associated with such higher queued interconnection) that, on the
date the interconnection system impact study is commenced:
(i) are directly interconnected 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.
The interconnection system impact study will consist of a short circuit analysis, a stability
analysis, and a power flow analysis. The interconnection system impact 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,
including preliminary indication of the cost and length of time that would be necessary to correct
any problems identified in those analyses and implement the interconnection. The
interconnection system impact study will 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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3.0 TYPE OF INTERCONNECTION SERVICE
The Interconnection Customer has selected Network Resource (NR) interconnection service, but
has also elected to have the interconnection studied as an Energy Resource (ER). The
Interconnection Customer will select NR or ER prior to the facilities study.
4.0 DESCRIPTION OF PROPOSED INTERCONNECTION
To interconnect the Q0542 Project to the 230 kV Frannie – Yellowtail transmission line will
require the construction of a new 230 kV three breaker ring bus switching substation including
control house and the installation of metering, protection and control and communications
equipment. Transmission system upgrades will also be required at Frannie substation, Yellowtail
substation, Cedar Mountain substation, Oregon Basin substation, McCullough Peak microwave
station, Cody Service Center, Casper Service Center, Portland Control Center and Salt Lake
Control Center.
4.1 Other Options Considered (NERC Requirement)
The Interconnection Customer could have chosen to interconnect directly to the Frannie
substation but, chose to have the Q0542 Project tap the existing 230 kV Frannie – Yellowtail
transmission line approximately 2.75 miles North of the Frannie substation.
5.0 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, the Transmission Provider reserves the right to re-evaluate this request, and
the results and conclusions could significantly change.
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 and are expected to
be in-service on or after the Interconnection Customer’s requested in-service date
for the Project will be modeled in this study.
o Generation Interconnection Queue: when relevant, interconnection facilities
associated with higher queue interconnection requests will be modeled in this
study. However, no generation will be simulated from any higher queued project
unless a commitment has been made to obtain transmission service.
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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
can make a request to designate a generating resource as a network resource. Since the
queue of higher priority transmission services requests may be different when and if a
Network Customer’s requests network resource designation for this generation 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). However, a network customer can
elect to designate more generating resources in an area than can be accommodated by
existing or planned transmission capacity. The network customer would then be required
to dispatch the resources so as to limit total generation so as not to exceed the network
customer’s transmission rights.
This study assumes the project will be integrated into the Transmission Provider’s system
to the existing Frannie – Yellowtail 230kV line at or near a point approximately 2.75
miles north of Frannie substation located in Park County, Wyoming.
This study assumes that the Railroad – Silver Creek 138kV line planned for December
2015 is in-service.
This study assumes that Q0542 is in-service in summer 2016. The 2016 heavy and light
load conditions are applied to this study.
PacifiCorp standards require post contingency voltage limits of 0.9 per unit and 1.1 per
unit.
The Interconnection Customer will construct and own any facilities required between
the Point of Change of Ownership and the project.
Generator tripping may be required for certain outages.
All facilities will meet or exceed the minimum WECC, NERC, and the Transmission
Provider’s performance and design standards.
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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
If wind turbines are connected electrically near series capacitors, then specialized studies
to consider SSR (Sub-Synchronous Resonance) and Sub-Synchronous Control
Interactions (SSCI) may be required. If N-1 or N-2 contingencies result in a radial path
of the turbines into the series capacitors, then studies are essential – for other non-radial
configurations, the studies are necessary at the discretion of the Transmission
Provider. Such studies must demonstrate that the wind turbine controls do not contribute
negative damping to the system, and that the mechanical modes of resonance in the
turbine do not interact with system series capacitors. If such interactions occur, it is the
responsibility of the wind developer to provide remedies, and to provide adequate
protection to ensure the sub-synchronous interactions are detected and the wind turbines
tripped.
The Latham/Platte 230kV line upgrades from a DUTT relaying scheme to a POTT
relaying scheme using mirrored bits, associated with the TOT4 project, have been
completed.
The 230kV bus configuration modifications at Latham substation associated with the
TOT4A project have been completed.
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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 available basis.
Consistent with the Transmission Provider’s Open Access Transmission Tariff, the facility will
be studied such that deliverability will be determined to the Transmission Provider’s aggregate
network loads assuming some portion of existing network resources are displaced by the output
of the Interconnection Customer’s large generating facility. Energy resource interconnection
service in and of itself does not convey transmission service.
5.1.1 Study Results
The PSS/E version 33.5 program was used to evaluate the steady state performance of the system
for contingencies described in Table 1. The 2014 Heavy Summer WECC case was modified for
the study. The study area was limited to the Big Horn area in Wyoming since the Point of
Interconnection (POI) is located on the Frannie – Yellowtail 230 kV line.
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The case was tuned to meet the maximum path flow on the Yellowtail South path. The
Yellowtail South path is jointly owned between PacifiCorp (PAC) and Western Area Power
Administration (WAPA). The path limit is 625 MW, with ownership split 400 MW for
PacifiCorp (230 kV lines) and 225 MW for WAPA (115 kV lines). The Yellowtail South path
consists of the following lines:
Yellowtail (PAC) – Frannie 230 kV (owned by PAC) *
Yellowtail (PAC) – Sheridan 230 kV (owned by PAC)
Yellowtail (WAPA) – Lovell 115 kV #1 line (owned by WAPA)
Yellowtail (WAPA) – Lovell 115 kV #2 line (owned by WAPA)
*Post Q0542, the metering point for the Yellowtail – Frannie 230 kV line would move from
Yellowtail to the new Q0542 Point of Interconnection so that the power flow from this Project is
captured in the path flow.
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Table 1
N-1 Outages
PAC owned facilities
# Contingency
1 Yellowtail (PAC) - Point of Interconnection 230kV line
2 Point of Interconnection - Frannie - Garland - Oregon Basin 230kV line
3 Oregon Basin - Grass Creek - Thermopolis (PAC) 230kV line
4 Thermopolis (PAC) - Riverton 230kV line
5 Riverton - Casper 230kV line
6 Yellowtail (PAC) - Sheridan 230kV line
7 Sheridan - Buffalo 230kV line
8 Buffalo - Kaycee - Midwest - Claim Jumper 230kV line
9 Buffalo - Carr Draw 230kV line
10 Carr Draw - Casper 230kV line
11 Yellowtail (PAC) – Rim Rock 161kV line
12 Thermopolis (PAC) - Kirby Creek - Hilltop 115kV line
13 Thermopolis (PAC) - Thermopolis (WAPA) 115kV #1 line
14 Thermopolis (PAC) - Thermopolis (WAPA) 115kV #2 line
15 Riverton 230/115kV transformer
16 Thermopolis 230/161kV transformer
17 Thermopolis 230/115kV #2 transformer
WAPA owned facilities
# Contingency
1 Yellowtail (PAC) - Yellowtail (WAPA) 230kV line
2 Yellowtail (WAPA) - Crossover 230kV line
2 Thermopolis (PAC) - Bad Water 230kV line
3 Bad Water - Buffalo Head - Spence 230kV line
4 Spence - Casper 230kV line
5 Lovell - Nahne Jensen - Basin - Worland - Hilltop & Thermopolis (WAPA) 115kV line
6 Lovell - Big George -Meeteesee - Carter Mountain - Thermopolis (WAPA) 115kV line
7 Yellowtail 60MW hydro generator #1
8 Yellowtail 60MW hydro generator #2
9 Yellowtail 60MW hydro generator #3
10 Yellowtail 60MW hydro generator #4
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NorthWestern Energy owned facilities
# Contingency
1 Yellowtail (PAC) - Billings 230kV line
Tri-State owned facilities
# Contingency
1 Thermopolis 230/115kV #1 transformer
Customer owned facilities
# Contingency
1 Point of Interconnection - Collection Site 230kV line
2 New 240MW wind generator
Table 1: List of Contingencies
Prior to adding Q0542, no thermal overload and voltage issues are observed under N-0
conditions. After adding Q0542, no thermal overload and voltage issues are observed under N-0
conditions.
There are known system conditions following contingencies that exist prior to the addition of the
Q0542 project which are provided here for documentation purposes. The following
contingencies cause the overload on Worland Tap – Basin – Nahne Jensen 115kV WAPA line:
N-1 outage of the Yellowtail (PAC) – Yellowtail (WAPA) 230kV line, or
N-1 outage of Yellowtail – Frannie – Garland – Oregon Basin 230kV line.
To mitigate this issue, tripping the section of Worland Tap – Basin 115kV line or Basin – Nahne
Jensen 115kV line is required. WAPA indicates that within five years there are plans to
reconductor the Worland Tap – Basin – Nahne Jensen 115kV line with 477ACSS (Aluminum
Conductor Steel Supported) which has a limit of 800 amps (159 MVA). The tripping scheme will
no longer be required if this new reconductor project is completed.
The following contingency causes low voltage issues in WAPA 115kV system:
N-1 outage of the Yellowtail (PAC) – Yellowtail (WAPA) 230kV line
Tripping the Meeteesee Tap – Big George 115kV WAPA line alleviates this low voltage issue.
No new voltage violations or thermal overloads are identified in the study for N-1 contingencies
with Q0542 in-service other than the existing issues identified. However, coordination with
WAPA is still required to operate the new generation facility properly under certain N-1
conditions described above or for other outage conditions that may occur from time to time.
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5.1.2 Requirements
5.1.2.1 Generating Facility Modifications
The Generation and Interconnection facilities owned by the Interconnection Customer are
required to operate under automatic voltage control with the voltage sensed electrically at the
Point of Interconnection. The generating and interconnecting facility should have sufficient
reactive capacity to enable the delivery of 100 percent of the plant output to the Point of
Interconnection at unity power factor measured at 1.0 per unit voltage under steady state
conditions.
Generators capable of operating under voltage control with a voltage droop are required to do so.
Studies will be required to coordinate the voltage droop setting with other facilities in the area.
As required by NERC standard VAR-001-1a, the Transmission Provider will provide a voltage
schedule for the Point of Interconnection. When voltage droop controls are not available, the
generation and interconnection facilities should be operated so as to maintain the voltage at the
Point of Interconnection between 1.01 pu to 1.04 pu. At the Transmission Provider’s discretion,
these values might be adjusted depending on the operating conditions. Within this voltage range,
the generating and interconnecting facilities should operate so as to minimize the reactive
interchange between the generation/interconnection facilities and the Transmission Provider’s
system (operation fixed at unity power factor at the Point of Interconnection). If the voltage is
outside the upper or lower range, the voltage control scheme should operate so as to utilize the
reactive capabilities of the generating and interconnecting facilities to maintain the voltage to a
value within the control band. The voltage control settings of the generation and interconnection
facilities must be coordinated with the Transmission Provider prior to energization (or
interconnection). The reactive compensation must be designed such that the reactive switching
(if required by the Interconnection Customer) does not cause step voltage changes greater than
+/-3% on the Transmission Provider’s system.
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 prior to
interconnection. The list of approved generator models is continually updated and is available
on the http://www.WECC.biz website.
The Transmission Provider was unable to obtain a working generator model from the
Interconnection Customer.
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5.1.2.2 Transmission Modifications
The Point of Interconnection substation is to be looped in to the Frannie – Yellowtail 230kV
Transmission line approximately 2.75 miles north of the Frannie substation located in Park
County, Wyoming. This new switching substation will split the line into two new sections:
Q0542-Yellowtail on the northern end and Frannie - Q0542 on the southern end.
The Q0542 Point of Interconnection substation will be located one span away from the existing
transmission line between structures 8/123 and 1/124. A loop in of the Point of Interconnection
substation off the transmission line toward Frannie will require removing H-frame structures
8/123 and 1/124 and replacing them with two new 3-pole TI451 structures and 2 new 3-pole
TI452 structures. All structures will be guyed wood poles.
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Figure 1: System One Line Diagram
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5.1.2.3 Existing Circuit Breaker Upgrades – Short Circuit
The increase in the fault duty on the system as a result of the addition of the generation facility
with the 120 – 2.35 MVA generators fed through 1 – 156/208/260 MVA step up transformer
with 8% impedance will not push the fault duty above the interrupting rate of any of the existing
fault interrupting equipment.
5.1.2.4 Protection Requirements
As indicated in the one line diagram shown in Figure 1, the proposed Point of Interconnection
2.75 miles north of Frannie substation in the Yellowtail – Oregon Basin 230 kV line will require
the construction of a new Point of Interconnection substation with three 230 kV breakers. There
will be a 9.51 mile line from the Point of Interconnection substation to the Generation
Interconnection Customer’s collector substation. The line between Yellowtail and Oregon Basin
substations is protection with line relays using power line carrier for communication. Since in
this part of the Transmission Provider’s service territory the communication options are limited
we will plan to continue to use the power line carrier for the line relay communication media
between the Point of Interconnection substation and Yellowtail substation, and between the Point
of Interconnection substation and Oregon Basin substation. In each case we will continue to use
one set of frequency shift transmitters and receivers using direct underreaching transfer trip line
logic schemes. The line relays at Yellowtail and Oregon Basin have been replaced in recent
years and with the development of new settings these relays will function with the relays that are
planned for the Point of Interconnection substation. For the line between the Point of
Interconnection substation and the collector substation a line current differential system will be
used. The Transmission Provider will design and built a panel containing the line relays that will
be compatible with the units being installed at the Point of Interconnection substation. The two
line relay set will communication over an optical fiber cable that will need to be installed in
conjunction with the 9.51 mile 230 kV tie line.
At the Point of Interconnection substation a relay will be installed that will monitor the voltage
magnitude and frequency. If the voltage, magnitude or frequency, is outside of the normal
operation range this relay will send a trip signal to cause the Interconnection Customer’s 34.5 kV
line breakers at the collector substation to open.
5.1.2.5 Data (RTU) Requirements
The installation of a RTU is required at the Transmission Provider’s Point of Interconnection
substation. Additional data for the operation of the power system will be needed from
Interconnection Customer’s collector substation. RTU units will be installed at both locations to
acquire the operational data and send the data back to the Transmission Provider’s operational
center. In addition to the control and indication of the 230 kV breakers in the Point of
Interconnection substation the following data from the Point of Interconnection substation and
the Interconnection Customer’s collector substation will be monitored:
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From the Point of Interconnection substation:
Analogs:
Net generation MW
Net generation MVAr
Energy register values
230 kV A phase voltage
230 kV B phase voltage
230 kV C phase voltage
From the Interconnection Customer’s collector substation:
Analogs:
Real power flow 34.5 kV line #1
Reactive power flow 34.5 kV line #1
Real power flow 34.5 kV line #2
Reactive power flow 34.5 kV line #2
Real power flow 34.5 kV line #3
Reactive power flow 34.5 kV line #3
Real power flow 34.5 kV line #4
Reactive power flow 34.5 kV line #4
Real power flow 34.5 kV line #5
Reactive power flow 34.5 kV line #5
Real power flow 34.5 kV line #6
Reactive power flow 34.5 kV line #6
Real power flow 34.5 kV line #7
Reactive power flow 34.5 kV line #7
Real power flow 34.5 kV line #8
Reactive power flow 34.5 kV line #8
Real power flow 34.5 kV line #9
Reactive power flow 34.5 kV line #9
Real power flow 34.5 kV line #10
Reactive power flow 34.5 kV line #10
Real power flow 34.5 kV line #11
Reactive power flow 34.5 kV line #11
Real power flow 34.5 kV line #12
Reactive power flow 34.5 kV line #12
Reactive power flow 34.5 kV from reactive device
Total Wind Farm Generation (MW)
Average Wind Farm Wind Speed (m/s)
Average Wind Farm Atmospheric Pressure (Bar)
Average Wind Farm Temperature (Celsius)
Wind Direction
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Status:
230 kV transformer breaker
34.5 kV transformer breaker
34.5 kV Line #1 breaker
34.5 kV Line #2 breaker
34.5 kV Line #3 breaker
34.5 kV Line #4 breaker
34.5 kV Line #5 breaker
34.5 kV Line #6 breaker
34.5 kV Line #7 breaker
34.5 kV Line #8 breaker
34.5 kV Line #9 breaker
34.5 kV Line #10 breaker
34.5 kV Line #11 breaker
34.5 kV Line #12 breaker
34.5 kV Reactive Device breaker
5.1.2.6 Substation Requirements
Oregon Basin substation
No major substation modifications are required at Oregon Basin substation.
Yellowtail substation
No major substation modifications are required at Yellowtail substation.
Q0542 Point of Interconnection substation
The Point of Interconnection substation will be built as a three breaker ring bus with all
necessary equipment such as: circuit breakers, CCVT’s, lightning arresters, an SSVT, and group
operated switches. Bus, bus support structures, and dead end towers will be installed as well as
conduit, cable trench, and yard lights. The substation will be fenced and a ground grid installed.
A control house will be installed to enclose all of the relay and communication equipment.
Q0542 Customer substation
Relay panels and a separate battery system will need to be installed in the Customer substation.
This equipment will need to be installed in a separate lockable room within the Customer’s
control house, or a separate control building will need to be installed. With either option, only
Transmission Provider personnel will have access to that area. Since PacifiCorp personnel will
require access into the Customer substation, a Current Distribution, Electromagnetic Fields,
Grounding and Soil Structure Analysis CDEGS analysis will be required to verify the grounding
design safe step and touch potentials.
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5.1.2.7 Communication Requirements
Communication requirements to physically connect the Q0542 project will consist of:
Install fiber on the existing 2.75 miles line between Frannie substation and Point of
Interconnection substation.
The Interconnection Customer will be required to install fiber on the new 9.51 mile line
between the Point of Interconnection substation and the Q0542 collector substation.
Upgrade the MAS radio between Frannie substation and McCullough Peak microwave
station.
Install a new microwave tower at Frannie substation.
Upgrade the Fractional T1 radios from McCullough Peak to Cedar Mountain microwave
stations and Cody Service Center with larger Microwave.
Install leased T1 line at Cody Service Center and interface with the microwave.
Install multiplex, communication batteries and chargers at all the locations requiring
upgrades.
Install Fiber DMX nodes at Frannie, the Q0542 Point of Interconnection substation and
the Q0542 collector substations.
Install new RTUs at Point of Interconnection substation and the Q0542 collector
substation.
Install substation network at all sites.
Power line carrier will be required on the 230 kV transmission line from Point of
Interconnection substation to the Yellowtail substation and on the 230 kV transmission
line from the Point of Interconnection substation to the Oregon Basin substation.
Mirrored bit relaying will be used on the Q0542 Point of Interconnection to Q0542
collector substation line.
Communications work will also be required at other locations to include Casper Service
Center, Portland Control Center (PCC), and the Salt Lake Control Center (SCC).
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5.1.2.8 Metering Requirements
Interchange Metering
At the Transmission Provider’s Q0542 Point of Interconnection substation the interchange
metering will be designed bidirectional and rated for the total net generation of the project
including metering the retail load (per tariff) delivered to the 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 CT/VT extended range for high accuracy metering with ratio’s
to be determined during the design phase of the project The metering instrument transformers
are long lead items and should be given appropriate time to meet in-service expectations.
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 including per phase
voltage and amps data.
An Ethernet connection is required for retail sales and generation accounting via the MV-90
translation system.
The Transmission Provider recommends the Interconnection Customer install meter by-pass
switches to reduce operational disruption. If the Interconnection Customer elects not to install
metering bypass switches, the Interconnection Customer’s generator will need to be taken off
line for metering testing, repair and service.
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5.1.1 Cost Estimate
Q0542 Collector substation – Engineering, procurement and installation
of protection and control and communications equipment.
$300,000
Q0542 Point of Interconnection substation - Engineering, procurement
and construction of a substation take-off structure and associated
installation of the Interconnection Customer’s last span of conductor.
$425,000
Q0542 Point of Interconnection substation - Engineering, procurement
and installation of metering and communications equipment.
$250,000
Q0542 Point of Interconnection substation to Frannie substation –
Engineering, procurement and installation of approximately 2.75 miles of
fiber optic cable.
$390,000
Sub-total Direct Assignment Costs $1,365,000
Interconnection – Network Upgrade Costs
Q0542 Point of Interconnection substation – Engineering, procurement
and construction of the 230 kV three breaker ring bus point of
interconnection switching substation.
$9,000,000
230 kV Frannie – Yellowtail transmission line – Engineering,
procurement and construction to loop in/out the 230 kV Frannie –
Yellowtail transmission line.
$330,000
Frannie substation - Engineering, procurement and installation of
communication upgrades including MAS radio and microwave upgrades.
$305,000
McCullough Peak microwave station - Engineering, procurement and
installation of communication and protection and control upgrades
including upgrading the MAS and Fractional T1 radio equipment.
$365,000
Cedar Mountain substation - Engineering, procurement and installation
of communication upgrades including upgrading the Fractional T1 radio
equipment.
$305,000
Cody Service Center - Engineering, procurement and installation of
communication upgrades including upgrading the Fractional T1 radio
equipment, installing a T1 line and updating the microwave interface.
$320,000
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Yellowtail substation - Engineering, procurement and installation of
protection and control upgrades.
$90,000
Oregon Basin substation - Engineering, procurement and installation of
protection and control upgrades.
$95,000
Casper Service Center, Portland Control Center and Salt Lake Control
Center - Engineering, procurement and installation of communication
upgrades.
$45,000
Sub-total Network Upgrade Costs $10,855,000
Total Cost – ER Interconnection Service – Interconnection Only $12,220,000
5.1.2 Schedule
At this time, it is estimated that the upgrades required to place this project in service could be
completed within 24 months of a signed interconnection agreement. Further details regarding
the schedule will be available through the Facilities Study when a more detailed estimate has
been prepared. The two items will be necessary before any construction starts:
1. Obtain the necessary permits and rights of way to construct the facilities necessary to
interconnect the Q0542 project (Interconnection Customer’s responsibility)
2. Execute a Large Generation Interconnection Agreement.
Please note the time required to execute the scope of work coupled with the anticipated date the
Interconnection Agreement will be signed, results in a timeframe that does not support the
Interconnection Customer’s requested in-service date of December 1, 2015.
5.1.3 Maximum Amount of Power that can be delivered into Network Load, with No
Transmission Modifications (for informational purposes only).
Zero megawatts can be delivered to network load with no transmission modifications.
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Bowler Flats Energy Hub, Q0542
5.1.4 Additional Transmission Modifications Required to Deliver 100% of the Power into
Network Load (for informational purposes only)
In order to deliver 100% of the Project output to network load, all of the improvements identified
in the Energy Resource Section of this report would be required, as well as the following
improvements (see Figures 2 and 3):
A new 150-mile 230 kV line from Shirley Basin substation to the Bitter Creek substation
with connections to the Standpipe and Latham substations. The line termination at Point
of Rocks to Bridger will be removed as the line will be extended and terminate at the
Bitter Creek substation, creating the Bridger – Bitter Creek line which is part of the 150
mile line mentioned above.
The line from Bridger to Point of Rocks will be removed and extended to terminate at
Bitter Creek
Addition of a new bay at Shirley Basin substation with one 230kV circuit breaker to add
the new line termination. The substation will still operate as a ring bus.
A new cross bay at Standpipe substation with three new 230 kV circuit breakers and two
new line terminations
Expansion of the Latham substation with new cross bays, two new 230 kV circuit
breakers and two new line terminations
A new four-breaker ring bus substation, adjacent to the existing Bitter Creek substation
and construction of four line terminations.
Accelerate the reconfiguration of the Bridger substation (see Figure 3)
A new 50-mile 230 kV line from White Horse to Jonah Gas new substations
A new 230 kV three-breaker substation at White Horse
A new 230 kV three-breaker substation at Jonah Gas
Two (2) new 230 kV phase shifting transformers at Craven Creek substation
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5.2 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 under a variety of severely stressed
conditions in order to determine the transmission modifications. If any, which are necessary in
order to deliver the aggregate generation in the area of the Point of Interconnection to the
Transmission Provider’s aggregate load, and assumes that some portion of existing network
resources are displaced by the output of the Interconnection Customer’s large generating facility.
Network resource interconnection service in and of itself does not convey transmission service.
5.2.1 Study Results
Wyoming has more generation than load, and as such, surplus energy must be exported to
network loads in other states. Projects are planned to construct additional transmission lines (the
Energy Gateway projects) from Wyoming to points in Idaho, Oregon, Utah, and the Desert
Southwest to accommodate additional exports from Wyoming; however these projects will not
be in-service in time for the proposed interconnection. An overview of these plans can be found
at the Northern Tier Transmission Group website (http://www.nttg.biz/site/) or at the Informal
Message section of Transmission Provider’s OASIS website
(http://www.oasis.pacificorp.com/OASIS/PPW/).
In order to deliver 100 percent of the Project output to network loads prior to the completion of
the Aeolus to Populus segment of Energy Gateway, additional system improvements are required
for the Q0542 project. There are several transmission constraints in Wyoming that need to be
alleviated in order to accommodate the 240 MW Q0542 output (see Figure 2):
(1) TOT 4A. TOT 4A is defined as the sum of the flows on the following 230kV lines:
Riverton – Wyopo, Spence – Mustang and Miners – Platte. This path is fully committed
at this time.
(2) Rock Springs / Firehole West. This path is defined as the sum of the flows on the Rock
Springs – Raven 230 kV and the Firehole - Mansface 230 kV lines. This path is fully
committed at this time.
To accommodate the Project output, a new approximately 150-mile long 230 kV line from
Shirley Basin to Bitter Creek substation, will be necessary in order to increase the constrained
TOT 4A transmission path. Additional studies will be required to determine the new TOT 4A
path rating after the addition of the new line and it will have to go through the WECC Three
Phase Facility Rating process.
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Additionally, a new approximately 50-mile long 230 kV line from a new substation (White
Horse) on the Atlantic City – Rock Springs 230 kV line, to a new substation near Jonah Gas is
required. A 230 kV phase shifting transformer at Craven Creek is required for flowability as the
Monument West path is also phase shifted.
A portion (128 MW) of the 240 MW project output could be scheduled on the Bridger West
system. The Bridger West (three 345 kV lines) path capacity is 2400 MW and current obligations
total 2208 MW. The remaining 192 MW of capacity is shared between Idaho Power, 64 MW
(one-third) and PacifiCorp, 128 MW (two-thirds). The remainder will be scheduled on the
improved Rock Springs/Firehole West path (White Horse – Jonah).
The new proposed projects are in Figures 2 and 3.
Pinedale
Jonah
FieldChappel
Creek
Chimney Butte
Labarge
Kemmerer
Monument
Exxon
Blacks Fork
South
Trona
Palisades
Blue
Rim
Mansface Firehole
Little Mtn
Rock
Springs
Jim Bridger
Point of RocksBitter
Creek
Bar X
Atlantic City
Mustang Great
Divide
Bairoil
115 kV
Spence
Riverton
Echo
Springs
Latham
Wyopo
TOT4A
850MW
Lima
Columbia Geneva Steel
Platte
Flaming Gorge
Naughton Craven Creek
Railroad
Paradise
Raven
Idaho
Wyoming
Utah Colorado
Treasureton
Ben
Lomond
To Populus
To Three Mile Knoll
Birch
Creek
230 kV345 kV
<230 kV
Foreign owned
Miners
White
Horse
Standpipe Shirley Basin
Proposed
230kV
Evanston West
1280 MW
Monument West
475 MW
Bridger West
2400 MW
Rock Springs –
Firehole 640 MW
Figure 2: Central & Southwest Wyoming Transmission System
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5.2.2 Network Resource Requirements
5.2.2.1 Generating Facility Modifications
See Section 5.1.2.1.
5.2.2.2 Network Resource Transmission Modifications
Transmission modifications required include the following (refer to Figures 2 and 3):
Construct a new 150-mile 230 kV transmission line from Shirley Basin to the Bitter
Creek substation.
Construct a new 50-mile 230 kV transmission line from White Horse to the Jonah Gas
substation.
Figure 3 – New 230 kV Line from Shirley Basin to Bitter Creek substation and Other
Improvements
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5.2.2.3 Network Resource Protection and Control Requirements
To support the Transmission line upgrades required for the NR part of the project the following
protective relaying will be required along with communication links to support the line relaying:
Shirley Basin – Standpipe
Standpipe – Latham
Latham – Platte
Latham #1 Bitter Creek
Latham #2 Basin –Bitter Creek
Bitter Creek – Point of Rocks
Bitter Creek– Jim Bridger
White Horse – Jonah Gas
Rock Springs – White Horse
White Horse – Atlantic City
All of the transmission lines will be built with optical fiber cable in the shield wire position.
This communication media will be used by the line relay in most locations. For each of the
transmission lines, permissive overreaching transfer trip scheme will be used except for the short
line between the Bitter Creek and the Bridger substations which will use line current differential
and the White Horse to Atlantic City transmission line which will continue to use power line
carrier.
Relaying will be needed for the new phase shifting transformers in the Craven Creek substation.
5.2.2.4 Network Resource Substation Requirements
Shirley Basin substation
At Shirley Basin substation a new bay will be added with one 230 kV circuit breaker to add the
new line termination. The substation will still operate as a ring bus. Other major equipment
installed include: CCVT’s, group operated switches, and lightning arresters.
Standpipe substation
Standpipe substation will need to be expanded to the south/west which includes additional fence,
ground grid, and grading. A new bay will be installed with three 230 kV circuit breakers to
terminate the two new line positions in the breaker and a half configuration. Other major
equipment include: CCVT’s group operated switches, and lightning arresters.
Latham substation
At Latham substation two new 230 kV circuit breakers will be installed to terminate the two new
line positions. Other major equipment include: CCVT’s, group operated switches, and lightning
arresters.
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Echo Springs substation
Relaying on the existing 230kV line from Latham to Point of Rocks will be mirrored bits. Two
wave traps will be removed.
Bitter Creek substation
Bitter Creek substation will be completely expanded. A new substation will be constructed
directly adjacent to the existing substation. The new substation will be a four breaker ring bus
with four 230kV, 3000A breakers and four line terminations. Other major equipment include:
CCVT’s, group operated switches, lightning arresters, and a new control building. It is assumed
a distribution line can be built to provide station service. The fence will enclose both old and
new yards and the new ground grid will be tied with the existing ground grid. The 230kV
Monell line will remain in its existing position.
Point of Rocks substation
The existing 230kV position to Jim Bridger substation will be removed. Two 230 kV switches
will be removed.
Jim Bridger substation
As part of the Jim Bridger reconfiguration, two 230kV bays will be installed with five 230kV,
3000A circuit breakers. Other major equipment required include: group operated switches,
CCVT’s, and lightning arresters. Additional AC and DC load centers will be required. One
230kV breaker and one 230kV switch will be removed. The 230kV line terminations will be
moved within the substation.
Jonah Field substation
A new substation will be constructed near the Jonah Gas facility. This substation will be a three
breaker ring bus with three 230kV circuit breakers. Other major equipment required include:
CCVT’s, group operated switches, a control building, and lightning arresters. It is assumed a
distribution line is in close proximity and can be expanded to serve the station service of the
substation. Fencing, grading, ground grid, conduit, cable trench, and yard lighting will be
required.
White Horse substation
A new substation will be constructed in between Atlantic City substation and Rock Springs
substation. This substation will be a three breaker ring bus with three 230kV circuit breakers.
Other major equipment required include: CCVT’s (one with a line tuner and carrier accessories),
a wavetrap, an SSVT, group operated switches, a control building, and lightning arresters.
Fencing, grading, ground grid, conduit, cable trench, and yard lighting will be required.
Atlantic City substation
No major substation modifications are required at Atlantic City substation.
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Rock Springs substation
One 230kV wavetrap will be removed (old Atlantic City line).
Craven Creek substation
Two 230kV phase shifting transformers will be installed (one for redundancy). Three 230kV
circuit breakers will be installed. Other major equipment include: lightning arresters and group
operated switches; three CCVT’s will be relocated within the substation. The installation of the
transformers will require expanding the substation which includes fencing, grading, and new
ground grid.
5.2.2.5 Network Resource Communication Requirements
Communication Requirements to deliver the Q0542 Projects generation to the Transmission
Provider’s Network Load include:
Install OPGW fiber optic cable on the new 150 mile line from Shirley Basin to Bitter
Creek and on to Jim Bridger substation.
Fiber nodes and multiplex will need to be installed at Platte, Latham, Echo, Bar X, Bitter
Creek and Point of Rocks.
Mirrored bits line protection will be over the OPGW fiber installed on the new lines.
Install a new RTU at Bitter Creek substation
Install 48 volt battery and chargers at Echo, BarX, and Bitter Creek substations.
Install OPGW fiber optic cable on the new line from Jonah Field to the new White Horse
substation.
Install a new RTU at the White Horse substation
Install fiber node and multiplex at the White Horse substation.
Communications work will also be required at other locations to include Casper Service
Center, Portland Control Center (PCC), and the Salt Lake Control Center (SCC).
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5.2.3 Network Resource Cost Estimate
Interconnection – ER Only $12,220,000
NR Interconnection
Shirley Basin substation – Bitter Creek substation - Engineering,
procurement and construction of a new 150 mile 230 kV transmission
line.
$88,500,000
White Horse substation – Jonah Gas substation - Engineering,
procurement and construction of a new 150 mile 230 kV transmission
line.
$26,500,000
Shirley Basin substation - Engineering, procurement and construction of
a new bay and 230 kV circuit breaker including CCVT’s, group operated
switches, and lightning arresters.
$3,300,000
Standpipe substation - Engineering, procurement and construction to
expand substation, add a bay and three 230 kV circuit breakers including
CCVT’s group operated switches, and lightning arresters.
$6,700,000
Latham substation - Engineering, procurement and construction to add
two new 230 kV circuit breakers including CCVT’s, group operated
switches, and lightning arresters.
$2,750,000
Echo Springs substation - Engineering, procurement and installation of
mirrored bits relaying and removal of two wave traps.
$2,650,000
Bitter Creek substation - Engineering, procurement and construction of a
new four breaker ring bus substation including CCVT’s, group operated
switches, lightning arresters, and a new control building.
$17,700,000
Point of Rocks substation – Engineering and removal of the 230 kV line
position to the Jim Bridger substation and the removal of two switches.
$285,000
Jim Bridger substation - Engineering, procurement and construction of
two new bays and five new 230 kV circuit breakers, new AC and DC
load centers and the installation of group operated switches, CCVT’s,
and lightning arresters.
$8,850,000
Jonah Field substation - Engineering, procurement and construction of a
230 kV three breaker ring bus including CCVT’s, group operated
switches, a control building, and lightning arresters.
15,500,000
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Bowler Flats Energy Hub, Q0542
White Horse substation - Engineering, procurement and construction of a
new 230 kV three breaker ring bus substation including CCVT’s (one
with a line tuner and carrier accessories), a wavetrap, an SSVT, group
operated switches, a control building, and lightning arresters.
12,600,000
Atlantic City substation – Engineering and labor to upgrade the
protection and control equipment at the Atlantic City substation.
$80,000
Rock Springs substation - Engineering and labor to remove one 230 kV
wavetrap.
$43,000
Craven Creek substation - Engineering, procurement and construction to
expand the substation and install two 230 kV phase shifting transformers
and three 230 kV circuit breakers including group operated switches, a
control building, lightning arresters and relocation of three CCVT’s.
$44,400,000
Total Cost – NR Interconnection Service – Interconnection Only $242,078,000
5.2.4 Schedule
The Transmission Provider estimates it will require approximately 7 to 10 years to design and
build both the Energy Resource and Network Resource facilities described in this report after the
completion of both items below.
1. Obtain the necessary permits and rights of way to construct the facilities necessary to
interconnect the Q0542 project (Interconnection Customer’s responsibility)
2. Execute a Large Generation Interconnection Agreement.
Please note the time required to execute the scope of work coupled with the anticipated date the
Interconnection Agreement will be signed, results in a timeframe that does not support the
Interconnection Customer’s requested in-service date of December 1, 2015.
6.0 PARTICIPATION BY AFFECTED SYSTEMS
Transmission Provider has identified the following affected systems: Western Area Power
Administration. A copy of all reports will be shared the each affected system.
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Bowler Flats Energy Hub, Q0542
7.0 APPENDIX 1: PROPERTY REQUIREMENTS
Property Requirements for Point of Interconnection Substation
The following applies to property acquired by an Interconnection Customer on which a Point of
Interconnection substation will be built to accommodate the Interconnection Customer’s project.
The property will ultimately be assigned to PacifiCorp, the Transmission Provider.
Property must be environmentally, physically and operationally acceptable to the
Transmission Provider without any material defects of title (or as deemed acceptable to
the Transmission Provider) and without unacceptable encumbrances. The property shall
be a permitted or permittable use in all zoning districts. Property lines shall be surveyed
and show all encumbrances, roads (private or public); easements (prescriptive or express)
etc.
Examples of potentially unacceptable environmental, physical, or operational conditions:
Environmentally unacceptable conditions could include but are not limited to
known contamination of site; evidence of environmental contamination by any
dangerous, hazardous or toxic materials as defined by any governmental agency;
property is in violation of building, health, safety, environmental, fire, land use,
zoning or other such regulation, ordinances, or statues of any governmental
entities having jurisdiction over the property; underground or above ground
storage tanks; known remediation sites on property; ongoing mitigation activities
or monitoring activities; asbestos; lead-based paint, etc. At a minimum, a phase I
environmental study is required for company land being acquired in fee.
Evidence will be required 60 days prior to the start of construction.
Physically unacceptable conditions could include but are not limited to inadequate
drainage; in flood zone; erosion issues; wetland overlays; threatened and
endangered species; archeological or culturally sensitive areas; inadequate sub-
surface elements, etc. Geotechnical studies are required by the Transmission
Provider.
Operationally unacceptable conditions could include but are not limited to
inadequate access for company equipment; existing structures on land that require
removal prior to building of substation; ongoing maintenance for landscaping or
extensive landscape requirements; ongoing homeowner's or CC&R's that are not
acceptable to the Transmission Provider.
Property should be acquired by fee ownership. If fee acquisition is not possible, then the
term shall be perpetual and the use exclusive and provide the Transmission Provider with
all property rights it deems necessary (perpetual easement). All contracts are subject to
the Transmission Provider’s approval prior to execution.
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The Interconnection Customer is required to identify any and all land rights to the subject
property, which are to be retained by the Interconnection Customer prior to conveying
property. All retained land rights are subject to the Transmission Provider’s approval.
If the Interconnection Customer is building facilities to be owned by the Transmission
Provider, then the Interconnection Customer must obtain all permits required by all
relevant jurisdictions for the use including but not limited to conditional use permits,
Certificates of Public Convenience and Necessity, California Environmental Quality Act,
etc., as well as all construction permits for the project
Interconnection Customer will not reimburse through network upgrades for more than the
market value of the property.
Property must be assignable to company and without litigation, suit, liens, condemnation
actions, foreclosures actions, etc.
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Bowler Flats Energy Hub, Q0542
8.0 APPENDIX 2: COMBINED QUEUE
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
2 01/19/01 East N/A
SF Phosphates
Substation, 230
kV
02/01/02 11
3 01/23/01 East N/A
West Valley
Substation, 138
kV
09/01/01 200
7 03/07/01 East N/A
Foote Creek
Substation,
34.5 kV
08/01/01 50
8 03/08/01 East N/A
Monument
Switching
Station, 230 kV
10/01/04 110
9 04/01/01 East N/A
Rowley
Substation, 138
kV
06/15/01 80
11 07/20/01 East N/A
Gatsby
Substation, 138
kV
09/01/02 120
12 08/27/01 East N/A
Longhollow
Switching
Station, 138 kV
12/26/03 146
18 10/21/02 East N/A
Northwest
Substation, 46
kV
10/06/04 25
20 04/30/03 East GEN Mona 345kV 03/22/06 280
21 04/30/03 East GEN Mona 345kV 03/22/06 245
29a 09/18/03 East GEN Goshen 161kV 02/12/06 64.5
29b 09/18/03 East GEN Goshen 161kV 10/20/10 129
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QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
44 06/03/04 East ER Timp - Tri-City
Line, 138kV 07/29/07 535-S
567-W
52 03/28/05 East GEN
Terminal Sub
Distribution
Circuit, 12.47kV
07/20/06 3.2
59 08/24/05 East NR
North of
Antelope Mine
Sub, 230kV
06/01/11 250-S
285-W
66 12/05/05 East NR
Blundell
Geothermal
Sub
10/19/07 11-S
15-W
73 03/27/06 East GEN
Spanish Fork -
Santaquin,
46Kv
07/31/08 18.9
310 339268 04/12/06 East NT PACE
(Resource) PACE 04/15/06 141
78 04/25/06 East NR
Mona
Substation,
345Kv
04/25/06 59
90 06/22/06 East ER Uinta Long
Hollow, 138kV 05/15/08 60
93 09/19/06 East GEN
Tooele
Substation, 47-
kV
03/01/08 1
96 10/09/06 East NR
w/ER
Uinta Long
Hollow, 138kV 07/02/08 79.5
107 11/14/06 East NR Timp-Tri-City
line, 138kV 08/18/08 79-S
49-W
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Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
111 12/08/06 East NA
2700 East
11600 South,
Sandy, UT
08/09/07 0.511
117 01/18/07 East NR
w/ER
Miners-
Difficulty Line,
230kV
12/09/08 99
118 01/18/07 East NR
w/ER
Miners-
Difficulty Line,
230kV
12/09/08 19.5
119a 01/29/07 East NR
w/ER
Foote Creek
Sub. 230kV 09/30/09 127.5
120 02/08/07 East NA
Existing point of
service in
Laramie, WY
10/04/07 0.65
126 03/05/07 East NR Near Glenrock
Mine 230kV 01/02/09 237
129 03/30/07 East N/A Oquirrh-Lark,
46-kV 04/01/09 4.8
138 05/22/07 East N/A Green River 12
circuit, 12.5kV 05/22/09 0.575
139 05/25/07 East N/A
University
Substation,
46kV
10/09/09 7.6
150 07/13/07 East N/A
PacifiCorp's
24.9-kV Circuit,
QRY15, out of
Quarry
Substation
6/18/2009 1
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Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
153 08/08/07 East NR
w/ER
Dave Johnston-
Yellowcake
Line, 230-kV
10/28/10 200.5
154 08/10/07 East N/A Goshen-Ucon
Line, 69-kV 04/30/12 19.8
161 09/04/07 East N/A
14.4-kV Circuit
out of Pinedale
Substation
1/22/2009 0.05
165 10/12/07 East N/A 3474 N. 3rd
Street 3/11/2008 0.03
171 11/08/07 East N/A
PacifiCorp's 69-
kV, Sand Hills
Line between
Casper & Platte
Junction
12/25/2009 19.5
175 12/07/07 East NE
w/ER
Craven Creek
to Chappel
Creek 230 kV
11/30/12 150
191 01/25/08 East NR
w/ER
PAC's 230 kV
Jim Bridger -
Aeolus
08/01/14 500
199 02/20/08 East NR
PacifiCorp's
proposed 230-
kV Aeolus
Substation
12/01/14 200
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Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
200 02/20/08 East NR
PacifiCorp's
proposed 230-
kV Aeolus
Substation
12/01/14 100
201 02/20/08 East NR
PacifiCorp's
proposed 230-
kV Aeolus
Substation
12/31/15 100
203 02/26/08 East NR
w/ER
Shirley-Basin
Substation on
the PacifiCorp's
230-kV Miners-
Difficulty Line
09/30/10 111
213 04/22/08 West N/A
Bernice #22
circuit out of
Bernice
Substation
8/4/2009 0.3
214 04/24/08 East N/A Pinedale Circuit
#23 02/18/09 1.96
220 05/12/08 East NR
w/ER
Latigo
Substation
between
Casper and
Windstar 230-
kV line
11/20/09 100.5
947 493092 05/23/08 East NT PACE
(Resource) PACE 6/1/2012
316 -
S
562-W
224a 05/27/08 East NR
w/ER
PacifiCorp's
345 kV Mona
substation
05/15/15 320
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Bowler Flats Energy Hub, LLC Page 36 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
224b 05/27/08 East NR
w/ER
PacifiCorp's
345 kV Mona
substation
05/15/15 230
252 11/25/08 East N/A
Customer's
existing 46-kV
system
3/1/2009 0.23
253 11/26/08 East N/A
1600 West B
Avenue, Utah
Industrial
Depot, Tooele,
Utah
2/20/2009 0.05
255 12/23/08 West NR
w/ER
3.2 miles NE of
PacifiCorp's
Goshen
Substation
05/20/12 151.8
256 01/14/09 West NA HPS 12 Circuit 04/15/09 1.696
267-A 04/13/09 East NR
w/ER
PacifiCorp's
345-kV Jim
Bridger Power
Plant, Point of
Rocks, WY
6/12/10
18.3-
S
22-W
267-B 04/13/09 East NR
w/ER
PacifiCorp's
345-kV Jim
Bridger Power
Plant, Point of
Rocks, WY
5/5/13
18.3-
S
22-W
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 37 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
267-C 04/13/09 East NR
w/ER
PacifiCorp's
345-kV Jim
Bridger Power
Plant, Point of
Rocks, WY
5/22/11
18.3-
S
22-W
267-D 04/13/09 East NR
w/ER
PacifiCorp's
345-kV Jim
Bridger Power
Plant, Point of
Rocks, WY
5/27/12
18.3-
S
22-W
270-A 04/30/09 East ER
PacifiCorp's
Huntington
Power Plant,
Huntington, UT
11/21/10 16.2
270-B 04/30/09 East ER
PacifiCorp's
Huntington
Power Plant,
Huntington, UT
4/30/15 16.2
271-A 04/30/09 East ER
PacifiCorp's
Hunter Power
Plant,
Castledale, UT
4/13/10 17.0
271-B 04/30/09 East ER
PacifiCorp's
Hunter Power
Plant,
Castledale, UT
4/30/15 17.0
271-C 04/30/09 East ER
PacifiCorp's
Hunter Power
Plant,
Castledale, UT
4/30/16 8.7
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 38 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
272 05/14/09 East NR
w/ER
PacifCorp's
proposed new
substation on
the 230-kV
Miners-
Difficulty Line
9/30/10 12.0
1145 563529 06/26/09 East NT PACEW PACEW 4/1/10 25.0
282 08/07/09 East N/A
PacifiCorp's
138/46-kV
Lampo
Substation
9/25/09 0.0360
290-A 09/22/09 East NR/ER
17 miles south
SE of Rock
Springs, WY
6/30/12 100.8
290-B 09/22/09 East NR/ER
17 miles south
SE of Rock
Springs, WY
12/31/12 100.8
290-C 09/22/09 East NR/ER
17 miles south
SE of Rock
Springs, WY
6/30/13 50.4
291 09/25/09 East NR/ER
PacifiCorp's
Emery to
Spanish Fork
345 kV line
12/31/11 100.0
1167 581025 10/05/09 East NT PACE PACE (Load) 3/1/11 53-S
94-W
1169 583608 10/14/09 East NT GSHN GSHN (Load) 1/1/13 32-S
64-W
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 39 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
1170 583614 10/14/09 East NT PACE PACE (Load) 9/1/10 21
301 10/27/09 East NR/ER
PacifiCorp's
proposed new
substation
adjacent to the
Lake Side
Power Gen
Facility
6/1/14 707-S
670-W
306-A 11/13/09 East NR/ER
PacifiCorp's
Amassa
Substation,
(DJ-Difficulty
230-kV)
1/31/11 48.3
310 12/21/09 East N/A
PacifiCorp's
34.5-kV
Parowan
Substation
10/31/10 20.0
311 12/22/09 East N/A
Three Peaks
Substation
Substation
10/31/10 20.0
313 12/22/09 East NR
PacifiCorp's
138 kV switch
132 located 3/4
mile N of the
generation
facility site
12/31/12 25-S
65-W
314 12/31/09 East NR
PacifiCorp's
34.5-kV West
Cedar
Substation
12/31/10 20.0
1190 603498 02/15/10 East NT PACE PACE (Load) 7/1/10 12.0
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 40 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
323-A 03/03/10 East NR/ER
PacifiCorp's
230-kV
Sunbeam
Substation
5/31/11 21.6
323-B 03/03/10 East NR/ER
PacifiCorp's
230-kV
Sunbeam
Substation
11/30/11 21.6
324 03/08/10 East N/A
Parowan -
Rocky
Mountain
Power
Substation
8/10/12 40.0
1202 614127 04/09/10 East NT WYOEAST WYODAK (Load) 11/17/10 35.0
332 04/29/10 East N/A
PacifiCorp's
24.9-kV circuit,
SML21, out of
South Milford
Substation
6/1/11 2.8
1209 617716 05/03/10 East NT GSHN GSHN (Load) 1/1/13 39.0
1210 618363 05/03/10 East PTP PACE MDWP 6/1/11 3.0
1214 618940 05/14/10 East NT WYOCENTRAL WYOCENTRAL
(Load) 10/1/10 10.0
333 05/17/10 East N/A
PacifiCorp's
24.9 kV circuit,
SML21, out of
South Milford
Substation
10/1/11 2.8
1215 620282 05/19/10 East NT PACE PACE (Load) 6/30/11 17.0
1216 621679 05/27/10 East NT PACE PACE (Load) 7/1/10 15.0
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 41 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
335 06/01/10 East NR/ER
PacifiCorp's
Amassa
Substation,
(DJ-Difficulty
230-kV)
3/1/12 49.5
341 06/10/10 East NR/ER
PacifiCorp's
Goshen
Substation at
161 kV
11/1/12 120.0
1223 625986 06/17/10 East NT WYOEAST WYOEAST (Load) 1/1/11 2.0
1224 626003 06/17/10 East NT PACE PACE (Load) 10/1/10 2.0
1225 626275 06/17/10 East NT WYOEAST WYOEAST (Load) 12/10/10 9
1229 626453 06/23/10 East NT PACE PACE (Load) 7/1/11 150.0
1230 626791 06/23/10 East NT PACE PACE (Load) 2/24/11 30.0
1231 626864 06/23/10 East NT PACE PACE (Load) 11/1/10 6.0
1236 630525 07/15/10 East NT WYOEAST WYOEAST (Load) 6/1/11 15.0
1237 634125 08/03/10 East NT PACE PACE (Load) 10/1/10 8.0
348 08/09/10 East N/A
PacifiCorp's
24.9-kV Circuit,
QRY15, out of
Quarry
Substation
4/30/11 0.22
1238 635532 08/09/10 East NT WYOEAST WYOEAST (Load) 7/31/13 67.0
1241 637972 08/20/10 East NT PACE PACE (Load) 7/1/13 21.0
1248 645170 09/22/10 East PTP PACE MDWP 1/1/12 3.0
1251 645781 09/29/10 East NT PACE PACE (Load) 10/1/11 4.0
1252 645790 09/29/10 East NT PACE PACE (Load) 12/1/10 8.0
1256 648008 10/08/10 East NT PACE
(Resource) PACE 5/1/14 660.0
1258 648377 10/12/10 East NT PACE PACE (Load) 5/1/13 13.0
1263 656398 11/09/10 East NT DJ WYOEAST (Load) 12/1/10 1.0
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 42 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
363 12/13/10 East N/A
PacifiCorp's
24.9‐kV
Southfork
Circuit, 4H27,
out of South
Cody
Substation
TBD 0.1
365 12/20/10 East N/A
PacifiCorp's
34.5‐kV N
Rawlins
Curcuit, 9H440,
out of Platte
Substation
5/1/2011 0.11
367 12/27/10 East N/A
PacifiCorp's
proposed
Sigurd‐Red
Butte 345‐kV
transmission
line
1/1/2014 169-S
172-W
375 03/04/11 East NR/ER Difficulty
Substation 10/1/2014 351
1305 686836 03/18/11 East NT PACE PACE (Load) 4/1/2011 6.00
384 03/30/11 East NR/ER Pinto
Substation 12/31/2012 60
1312 692513 04/04/11 East NT PACE PACE (Load) 7.00
1317 702580 05/11/11 East NT PACE PACE (Load) 04/01/12 70
1326 709355 06/07/11 East PTP PACE PACE 1/1/2015 20
396 08/04/11 East N/A
Circuit OQU18,
Oquirrh #18
feeder, out of
Oquirrh
substation
12/1/2011 0.585
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 43 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
1361 741886 10/12/11 East NT WYOCENTRAL
WYOCENTRAL
(Load) 1/1/2012 37
403 10/25/11 East NR/ER Sigurd
Substation 7/1/2014 525
1376 752491 11/29/11 East NT PACE PACE (Load) 1/1/2013 5
407 01/17/12 East NR/ER
Rock Springs-
Naughton Line,
230kV
12/31/2012 79.8
409 01/26/12 East NR/ER
Windstar-
Aeolus line,
230kV
9/30/2014 320
1405 769663 02/27/12 East NT PACE PACE (Load) 5/1/2012 89
1407 770827 03/07/12 East NT WYON WYON (Load) 5/1/2012 4
415 03/12/12 East N/A
24.9-kV circuit,
SML21, out of
South Milford
12/1/2012 10
420 03/26/12 East NR/ER
Carbide
substation,
69kV
10/1/2014 200
1412 775561 03/28/12 East NT GSHN GSHN (Load) 10/1/2013 3
1497 785040 05/23/12 East NT WYOEAST PACE 11/01/13 25
425 06/01/12 East N/A Chappel Creek
substation 7/30/2016 156.2
426 06/26/12 East NR/ER Moab-Pinto
Line, Pole #365 8/31/2014 80
1520 804038 08/15/12 East NT PACE PACE 8/15/2012 2
1521 804043 08/15/12 East NT WYOCENTRAL WYOCENTRAL 10/15/2012 1
1523 805002 08/23/12 East NT PACE PACE 12/1/2012 46
1524 805181 08/23/12 East NT WYOCENTRAL WYOCENTRAL 11/1/2012 5
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 44 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
432 08/27/12 East N/A
Customer's
existing 138kV
substation
5/1/2013 6.3
1530 806472 08/30/12 East NT TRONA TRONA 11/1/2012 8
1531 806486 08/30/12 East NT TRONA TRONA 1/1/2015 29
1532 806494 08/30/12 East NT PACE PACE 1/1/2012 2
1533 806544 08/30/12 East NT PACE PACE 1/1/2012 4
1534 806561 08/30/12 East NT PACE PACE 1/1/2013 6
1535 806585 08/30/12 East NT PACE PACE 12/1/2012 8
1536 807115 08/31/12 East NT PACE PACE (Load) 9/1/2013 5
1540
809252;
809367 09/14/12 East NT BOZ ANDK (Load) 8/1/2016 50
1541
809254;
809362 09/14/12 East NT BOZ ANDK (Load) 8/1/2016 100
1542
809337;
809374 09/14/12 East NT BOZ ANDK (Load) 1/1/2013 20
1543
809340;
809375 09/14/12 East NT BOZ ANDK (Load) 1/1/2015 24
1544
809347;
809376 09/14/12 East NT BOZ ANDK (Load) 2/1/2015 3
1545
809353;
809378 09/14/12 East NT BOZ ANDK (Load) 1/1/2016 3
1546
809355;
809380 09/14/12 East NT BOZ ANDK (Load) 9/1/2016 3
1547
809357;
809382 09/14/12 East NT BOZ ANDK (Load) 1/1/2017 11
1548
809397 ;
809398 09/14/12 East NT BOZ ANDK (Load) 1/1/2013 30
437 09/17/12 East N/A
Circuit PRS13,
Preston #13,
out of Preston
substation
4/17/2014 0.5
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 45 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
438 09/18/12 East N/A
Customer's
electric system
from Tooele
Depot
substation
4/1/2013 1.75
439 09/18/12 East N/A
Customer's
electric system
from Tooele
Depot
substation
4/1/2013 1.56
442 10/11/12 East N/A
RIGBY-
REXBURG
TAP TO
WEBSTER
9/30/2014 5.6
1578 77610461 12/06/12 East NT Sunbeam BRDY 3/1/2013 45
450 12/21/12 East N/A Pavant
substation 3/15/2014 50
451 01/02/13 East N/A
Circuit CLM11,
Coleman #11,
out of Coleman
substation
12/13/2013 3
1591 77717778 01/02/13 East PTP PACE 4C 1/1/2014 66
1592 77717792 01/02/13 East PTP PACE 4C 1/1/2014 100
453 01/07/13 East N/A
Circuit CLF11,
CLIFTON #11
DAYTON &
BANIDA, out of
Clifton
substation
12/31/2013 1.6
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 46 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
454 01/10/13 East N/A
Circuit WCD28,
West Cedar
#28, out of
West Cedar
substation
6/30/2014 3
455 01/10/13 East N/A
Circuit WCD28,
West Cedar
#28, out of
West Cedar
substation
6/30/2014 3
456 01/10/13 East N/A
Circuit BKl12,
Brooklawn #12,
out of
Brooklawn
substation
6/30/2014 2.1
457 01/10/13 East N/A
Circuit BKl11,
Brooklawn #11,
out of
Brooklawn
substation
6/30/2014 2.1
1599 77699698 01/16/13 East NT GSHN GSHN 11/1/2013 1
459 01/18/13 East N/A
Circuit SML12,
South Milford
#12, out of
South Milford
substation
6/30/2014 3
460 01/18/13 East NR/ER
Pavant-Gonder
Transmission
Line
12/31/2014 160
1603 77786388 01/23/13 East NT PACE MDGT 01/01/15 24
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 47 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
1605 77762035 01/25/13 East NT NEWPOINT NEWPOINT 01/01/16 84
1607 77762000 01/30/13 East NT NEWPOINT NEWPOINT 01/01/16 164
463 02/11/13 East N/A
Circuit ENO12,
Enoch#12, out
of Enoch
substation
6/30/2014 3
464 02/11/13 East N/A
Circuit WCD28,
West Cedar#
28, out of West
Cedar
substation
6/30/2014 3
465 02/11/13 East NR/ER Abajo
substation 12/31/2015 50.4
471 02/28/13 East N/A
Circuit WCD28,
West Cedar
#28, out of
West Cedar
substation
6/30/2014 3
472 02/28/13 East N/A
Circuit WCD28,
West Cedar
#28, out of
West Cedar
substation
6/30/2014 3
473 02/28/13 East N/A
Circuit WCD28,
West Cedar
#28, out of
West Cedar
substation
6/30/2014 3
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 48 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
475 03/08/13 East N/A
Circuit ENV12,
Enterprise #12,
out of
Enterprise
Valley
substation
12/31/2013 3
488 03/19/13 East N/A
Circuit PRV25,
Parowan
Valley#25, out
of Parowan
Valley
substation
12/31/2013 3
489 03/19/13 East N/A
Circuit ENO12,
Enoch#12, out
of Enoch
substation
12/31/2013 3
491 03/19/13 East N/A
Circuit BKl12,
Brooklawn #12,
out of
Brooklawn
substation
12/31/2013 3
492 03/19/13 East N/A
Circuit SML12,
South Milford
#12, out of
South Milford
substation
12/31/2013 3
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 49 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
493 03/19/13 East N/A
Circuit SML11,
South Milford
#11, out of
South Milford
substation
12/31/2013 3
1722 78169628 04/30/13 East PTP TRONA REDB 5/1/2014 30
1723 78170277 04/30/13 East PTP TRONA MPAC 5/1/2014 30
500 06/12/13 East N/A
Circuit RKW11,
Porter Rockwell
#11, out of
Porter Rockwell
substation
9/1/2013 2.589
1747 78351080 06/18/13 East NT PINTO PACE 11/30/2015 80
502 06/27/13 East N/A
Circuit MLF12,
Milford#12, out
of Milford
substation
10/15/2015 2.97
503 06/27/13 East N/A
Circuit SML21,
South Milford
#21, out of
South Milford
substation
10/15/2015 2.97
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 50 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
504 06/27/13 East N/A
Circuit SML12,
South Milford
#12, out of
South Milford
substation
10/15/2015 2.97
512 08/22/13 East N/A
Milford
substation 72-
47kv
distribution
circuit, pole
number I73-28-
10#, 059303
3/1/2015 3
513 09/10/13 East NR/ER
138kV bus at
West Cedar
substation (or)
138kV bus at
Three Peaks
substation
12/31/2015 80
514 09/13/13 East NR/ER
Tap to the 138
kV Enterprise
Valley – West
Cedar
transmission
line
12/1/2015 80
515 09/13/13 East NR/ER
Sigurd to Red
Butte No. 2
345kV
transmission
line
12/1/2015 80
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 51 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
516 09/13/13 East NR/ER
Sigurd to Red
Butte No. 2
345kV
transmission
line
6/30/2015 3
1766 78752066 09/26/13 East NT DJ WYOE 10/1/2014 50
1767 78752068 09/26/13 East NT DJ WYOE 10/1/2014 50
1768 78752070 09/26/13 East NT DJ WYOE 10/1/2014 50
1769 78752071 09/26/13 East NT DJ WYOE 10/1/2014 109
1770 78752072 09/26/13 East NT DJ WYOE 10/1/2014 109
1771 78752081 09/26/13 East NT Fourcorners DJ 10/1/2014 85
518 10/01/13 East N/A
Tap to 34.5 kV
MDD24
(Middleton 24)
circuit feeding
Dixie Deer
substation
6/30/2015 2.97
519 10/01/13 East N/A
Tap to 34.5 kV
MDD24
(Middleton 24)
circuit feeding
Dixie Deer
substation
6/30/2015 3
520 10/01/13 East N/A
Tap to 34.5 kV
MDD24
(Middleton 24)
circuit feeding
Dixie Deer
substation
6/30/2015 2.97
521 10/01/13 East N/A
Tap to 12.5 kV
DXD12 (Dixie
Deer 12) circuit
11/1/2015 3
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 52 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
523 10/08/13 East N/A
Santaquin-
Nebo #2, tap to
Burgin (one of
two 46kV lines
in the area)
11/1/2015 6
524 10/08/13 East N/A Terminal –
Tooele 46kV 11/1/2015 6
525 10/09/13 East NR/ER Parowan
substation 11/30/2016 40
526 10/16/13 East N/A
TAR11,
Tamarisk 11 (to
the immediate
north of
substation)
12/31/2014 3
527 10/16/13 East N/A
HUC13,
Huntington 13
(South of town,
on Route10)
12/31/2014 3
528 10/16/13 East N/A HUC12,
Huntington 12 12/31/2014 3
1778 78834184 10/18/13 East NT PACE PACE 12/1/2013 10
529 10/22/13 East N/A WCD 28 6/30/2015 3
530 10/22/13 East N/A WCD 28 6/30/2015 3
531 10/22/13 East N/A WCD 28 6/30/2015 3
1780 78849614 10/22/13 East NT WYOC WYOC 1/1/2014 21
1781 78865513 10/25/13 East NT WYOE WYOE 1/1/2014 20
532 11/07/13 East NR/ER Pavant
substation 7/1/2016 50
1787 78984295 11/26/13 East NT WYOE WYOE 7/30/2014 7.5
System Impact Study Report
Bowler Flats Energy Hub, LLC Page 53 August 19, 2014
Bowler Flats Energy Hub, Q0542
QUEUE OASIS
AREF
Completed
Request
Received
Control
Area
Type of
Request
POR (TSR) /
Location of
Interconnection
(GI)
POD (TSR)
Start Date
(TSR) /
Cust.
Requested
Commercial
Operation
(GI)
MW
539 12/13/13 East NR/ER
138k/ linetap
on PacifiCorp's
Wecco Radial
line
3/31/2016 130.4
541 12/23/13 East NR/ER
Pinto
substation at
138 kV through
facilities
constructed for
Q0384
12/31/2015 138
1794 79099043 12/23/13 East NT PACE PACE 3/31/2014 1
1796 79132251 01/03/14 East NT PACE PACE 1/1/2014 25
1797 79164408 01/09/14 East NT PACE PACE 2/1/2014 200
542 01/23/14 East NR/ER
230 kV Frannie
– Yellowtail line
approximately 3
miles North of
the Frannie
substation
12/1/2015 240