20191025Supplement toApplication.pdf

ROCKY MOUNTAIN
POVT'ER
A orvrsroN oF PAcrFrcof,P
October 25,2019
REC EIVED
'!r; CCT 25 Pll 2' 03
- 1."'rl;,',tr,oN
RE,
VIA OVERNIGHT DELIVERY
Diane Hanian
Commission Secretary
Idaho Public Utilities Commission
11331WChindenBlvd
Building I Suite 201A
Boise, Idaho 83714
CASE NO. PAC-8.19-16 - PACIFICORP'S APPLICATION FOR
ACKNOWLEDGEMENT OF THE 2OI9 INTEGRATED RESOURCE PLAN
Dear Ms. Hanian:
The Company also identified additional information and clariSing changes in the 2019 IRP,
Volume II - Appendices A-L, and clarifring changes and a value correction in 2019 IRP Volume
II - Appendices M-R. The changes are summarized in the table below. Enclosed as a supplement
to the 2019 IRP is a replacement page for each change. The identified changes do not affect the
prefened portfolio, inputs or outcomes of the 2019 IRP, and do not affect any other materials
provided.
I This change is incoryorated in the publicly posted version:
httos:/www.oacificom.com/content/dam/Dcom/documents/en/pacificorp/energyl'integrated-resource-
PaciliCorp 2019 IRP Volume II Appendices A-Lr
Reference Update Page
Appendix D Replacement ofblank page with additional DSM tables and
discussion.72
Appendix E,Replaced Appendix E in its entirety with updated discussion T-7 6b2
1407 North Temple, Suite 310
Salt Lake City, Utah 84116
Please find enclosed the data disc and data drive containing non-confidential and confidential work
papers for the 2019 Integrated Resource Plan ("lRP"). PacifiCorp supplements its 2019IRP filing
with the discs to support and provide additional details for the analysis described within the 2019
IRP. Confidential information in the 2019 IRP will be provided to any party that has signed a non-
disclosure agreement in this Docket. PacifiCorp requests that interested parties contact the state
manager at the number listed below for a copy of the non-disclosure agreement that must be
executed and submitted prior to obtaining a copy ofthe confidential information.
olanr20l9 IRP_Volume Il Aopendices A-L.odf
2 Two additional pages in Volume II appendices A-L, Appendix E (Sman Grid) are numbered 76a and 76b.
Page 2
3 This change is incorporated in the publicly posted version
https://wr,r.w.oacifi corD.corn/content/dam/DcorD/ents/en/Daci fi com,/enersvlintesrated-resource-
olar/2019-lRP Volume-ll-Apoendices-M-R.pdf
All formal corespondence and data requests regarding this filing should be addressed as follows:
By e-mail (preferred):datarequest@pacifi com.com
[e-mail]
ted.weston@pacifi com.com
yvonne.hoqle@Dacifi com.com
By regular mail:Data Request Response Center
PacifiCorp
825 NE Multnomah Street, Suite 2000
Portland, Oregon, 97 232
Ted Weston
Idaho Regulatory Affairs Manager
i407 West North Temple, Suite 330
Salt Lake Ciry, utah 841l6
PaciliCorp 20l9IRP Votume II Appendices M-R3
Update Page
Appendix M
Replacement page to align the Gateway quick reference table
(bottom ofpage) with the changes below:276
Replacement page ofcase P-22 fact sheet clarifying description and
correcting the transmission path map.378
Replacement page of case P-22 f^cl sheet correcting the Bridger
WY to Populus path rating from 1.621 MW to 1,700 MW.379
Replacement page of case P-23 fact sheet clarifying description,
correcting description and transmission path map.380
Replacement page of case P-23 fact sheet correcting the Bridger
WY to Populus path rating from 1,621 MW to 1,700 MW.
Replacement page ofcase P-25 fact sheet clarifuing description and
correcting the transmission path map.382
Replacement page of case P-25 fact sheet correcting the Bridger
WY to Populus path rating from 1,621 MW to 1,700 MW.383
Replacement page ofcase P-26 fact sheet clarifuing description and
correcting the transmission path map.384
With copies to:
Yvonne Hogle
Assistant General Counsel
Rocky Mountain Power
1407 W. North Temple, Suite 320
Salt Lake City, Utah 84116
Reference
381
Page 3
Informal inquiries may be directed to Ted Weston, Idaho Regulatory Affairs Manager, at
[phone].
Sincerely,
eS
Vice Presi
Enclosures
Jim Yost, Idaho Govemor's Office (without enclosures)
Benjamin Otto, Idaho Conservation League (without enclosures)
Mark Stokes, Idaho Power Company (without enclosures)
Teri Carlocl Idaho Public Utilities Commission stalf (without enclosures)
Randall Budge, (Monsanto) (without enclosures)
Nancy Kelly, Westem Resource Advocates (without enclosures)
"^-Dn
cc
PACIFICORP - 20 I9 IRP APPENDIX D - DEMAND-SIDE MANAGEMENT RESoTJRCES
II
The following tables show the economic DSM resource selections by state and year in the 2019
IRP preferred portfolio, P45CNW.
Table D.4 - Incremental Enerry Efficiency Resource Selections (2019 IRP Preferred
Portfolio)
For the 2O-year assumed nameplate capacity contributions (MW impacts) by state and year
associated with the Energy Efficiency resource selections above, see Table 8.18 - PacifiColp's
20l9IRP Preferred Portfolio, in Volume I of the 2019IRP.
l1 tlc!libmi.-3r{l Party ContBcts
l5 1.5Crlfomir{.oYwH
Cllrfomra-hriqatc 48 4E
58 58&lifomia-Thenms ta(
109 109Oreron-3d Prrw Contmct!
15Ocron-Ancilkv S.rYic.3 '15
133 133Or.co!-Idrate
Washinrtoo-3rd Putv CotrllcE 10.9 109
t9 l9washinfi on-Anciu.rv S.ryiccs
Waihin*ton-CooYwH 1_1 71
8l 8l
t66 166w hitrctor-Th..mDsrat
U!h-3id P[ty ColEacts 767 167
Utai-ADcillffv ScNi..s 83 5.3 32 167
99 72 6.8 7_0 12r-\an{oo[T H ,tl 70 559
ULi'lrrir!t.I9 l9
lt6?82 83 5t 1383Utah-Thcnms tal
ldaho-lrriest.52 37 I8 t06
373 373Wyomilr-3rd Puty Cotrlrcts
wvomnr-Ancil'Iv Scrvic.s 30 l0
52 52
1.8 ]E
t2 6.1
ltlr:i|i?!--l''tl-Ililt!-r,tnflfilItfilfiitfiflit!!lljlnfiiEllEiltlflirhflr',fiEnnr,lrl/T lllllllfillilIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIIII
IIIIIIIIIIIIIIIIIIIII
IIIIIIIIIIIIIIIITIIIIIIIIIIIIII
IIIIIIIIIII
EIE!}EIEIiI'-IIIIIII IIIEcEEi-IEEnrf,Ilrlr-,IrI' xrtrfl rrrrlErrE!?7ti't-Frr
II
II
II
II IIIIII
IIIIII
IIIII IIIIII
IIIIIII I IIITIII
I
IIIIIIIIIIIIII
6.7405.130 5,710 5.210 6.180 6.7@ 6.710 6.900
I65.580 171.U0 170.8t0 175.ffiIt2,370 168,410 163.960 158.100 152,370 t44.500
40.550 44.450 46.4X 46.420 453ma,M)39,900 43.710 4\tm 41,510
x4270 254.120 2y.5 260.1$256.810 x2.620 244.500 244.Tt|216.870255,470
18.100 17.190 17.590 lE.4l0 20.90 20.580 20.450 m.7q 20.400 20.020
593m 50.960 54.960 '7t250 T2$83290 u 9l 700 91270 88.540
Ene.gy Effl.iency Enerty (MWh) Selected by State and Yearn @@-t't-@,I.ifiJ-tilrrIEil-fitI,-litf-nr:r
-?-
IirrEilrIli-IfrI
EFlr.|'lri'r E@ @@EE@@@Effi @@
I 5.8q)5.3806,690 6,400 6,220 4,1l0 4.M0 3.660 1tun 2.640
r18.120 113.420 98.860 99240130,550 122,100 96.100 95.190 84,090
37.9'70 36.610 14.190 32.040 10r30 D,'ICo 22.74t r 8.r90 15.620 1s.330
213.380 200.900 198.E80 184.760 t35.510 122.2X 93.920 80230 81110
19.410 18210 r7.480 I7.400 15.760 12.850 I 1.930 9.810 8.370 8.640
81230 75.380 66.490 6t,490 56.140 41.140 4{.520 35,1m 25,6m 25.880
Eneryy Efficiency ErerEy (MWhlSeleded by State and Yea,
-tt-fitlrfEirriErrllltrrnillti!
rrtirtrftiErrtiErrtilr,r
-irilI'JI-rrTiI
I
Ei?!fls .n@I@BE@EEmEm@@@@
72
Preferred Portfolio DSM Resource Selections
Table D.3 - Incremental Demand Response Resource Selections (2019 IRP Preferred
Portfolio)
PAC'rFrCoRP-20l9IRP APPENDTXE-SMARTCBTD
AppsxorxE-StrranrGruo
Smart grid is the application of advanced communications and controls to the electric power
system. As such, a wide array of applications can be defined under the smart grid umbrella.
PacifiCorp has identified specific areas for research that include technologies such as dynamic line
rating, phasor measurement units, distribution automation, advanced metering infrastructure
(AMI), automated demand response and other advanced technologies. PacifiCorp has reviewed
relevant smart grid technologies for transmission and distribution systems that provide local and
system benefits. When considering these technologies, the communications network is often the
most critical infrastructure decision. This network must have relevant speed, reliability, and
security and be scalable to support the entire service territory and interoperable for many device
types, manufacturers, and generations of technology.
PacifiCorp has focused on those technologies that present a positive benefit for customers and has
implemented fimctions such as advanced metering, dynamic line rating, and distribution
automation. This will optimize the electrical grid when and where it is economically feasible,
operationally beneficial and in the best interest of customers. PacifiCorp is committed to
consistently evaluating the value of emerging technologies for integration when they are found to
be appropriate investnents. The company is working with state commissions to improve
reliability, energy efficiency, customer service, and integration of renewable resources by
analyzing the total cost ofownership, performing thorough cost-benefit analyses, and reaching out
to customers concerning smart grid applications and technologies. As technology advances and
development continues, PacifiCorp is able to improve cost estimates and benefits of smart grid
technologies that will assist in identiffing the best suited technologies for implementation.
Transmission Network and Operation Enhancements
Dynamic Line Reting
Dynamic line rating is the application of sensors to transmission lines to indicate the real-time
current-carrying capacity of the lines in relation to themral restrictions. Transmission line ratings
are typically based on line loading calculations given a set of worst-case weather assumptions,
such as high ambient temperatures and very low wind speeds. Dynamic line rating allows an
increase in current-carrying capacity when mote favorable weather conditions are present and the
transmission path is not constrained by other operating elements. The Standpipe-Platte (formally
Miners-Platte) project was implemented in 2014 and has moved from pilot stage into firll
deployment. Standpipe-Platte is currently the only dynamic line rating application in PacifiCorp.
The Standpipe-Platte project has delivered positive results as windy days are directly linked to
increased wind power generation and increased tansmission ratings. A dynamic line rating system
is used to determine the resulting cooling effect of the wind on the line. The curent carrying
capacity is then updated to a new weather dependent line rating. The Standpipe-Platte 230 kilovolt
ftV) transmission line is one of three lines in the TOT4A tansmission corridor, and had been one
of the limits of the corridor power transfer. As a result of this project, the TOT4A Westem
Electricity Coordinating Council (WECC) non-simultaneous path rating was increased.
Dynamic line rating will be considered for all future transmission needs as a means for increasing
capacity in relation to faditional construction methods. Dynamic line rating is only applicable for
71
Introduction
PACITICORP _ 20I9 IRP APPFNDIX E_ SMART GRID
Digital Fault Recorders / Phasor Measurement Unit Deployment
To meet compliance with the North American Electric Reliability Corporation (NERC) MOD-
033-1 and PRC-002-2 standards, PacifiCorp has installed over 100 multifrrnctional digital fault
recorders (DFR) which include phasor measurement unit (PMU) firnctionality. The installations
are at key transmission and generation facilities throughout the six-state service territory, generally
placed on WECC identified critical paths. PMUs provide sub-second data for voltage and current
phasors, which can be used for MOD-033-1 event analysis and model verification. DFRs have a
shorter recording time with higher sampling rate to validate dynamic disturbance modelling per
PRC-002-2. The DFR/PMUs will deliver dynamic PMU data to a centralized phasor data
concentrator (PDC) storage server where offline analysis can be performed by hansmission
operators, planners, and protection engineers. Installation of the communications and data fiansfer
systems between the individual PMUs and the PDC is underway and planned for completion by
the end of2019. Additionally, transient DFR data will be downloaded manually at substations.
Transmission planners will use the phasor data quantities from actual system events to benchmark
performance of steady-state and transient stability models of the interconnected aansmission
system and generating facilities. Using a combination of phasor data from the PMUs and analog
quantities currently available tlrough Supervisory Control and Data Acquisition System
(SCADA), transmission planners can set up the system models to accurately depict the
transmission system prior to, during, and following an event. Differences in simulated versus
actual system performance will then be evaluated to allow for enhancements and corrections to
the system model.
Model validation procedures are being evaluated, in conjunction with data and equipment
avaiiability to fulfill MOD-033-1. Creation of a documented process to validate data that includes
the comparison ofa planning power flow model to actual system behavior and the comparison of
the planning dynamic model to actual system response is ongoing. PacifiCorp will continually
evaluate potential benefits of PMU installation and intelligent monitoring as the industry considers
PMU in special protection, remedial action scheme and other roles that support transmission grid
operators. With the hansitions at Peak Reliability, PacifiCorp will continue to work with the
Califomia Independent System Operator (CAISO)'s Reliability Coordinator West to share data as
appropriate.
Distribution Automation and Reliability
Distribution Automation
Distribution automation encompasses a wide field of smart grid technology and applications that
focus on ushg sensors and data collection on the distribution system, as well as automatically
adjusting the system to optimize performance. Distribution automation can also provide improved
outage management with decreased restoration times after failure, operational efficiency, and peak
load management using distributed resources and predictive equipment failure analysis using
complex data algorithms. PacifiCorp is working on distribution automation initiatives focused on
improved system reliability through improved outage management and response.
74
tJrermal constraints and only provides additional site-dependent capacity during finite time
periods, and it may or may not align with expected transmission needs of future projects.
PacifiCorp will continue to look for opportunities to cost-effectively employ dynamic line rating
systems, and the Standpipe-Platte dynamic line rating system will be redeployed with newer
equipment in 2020.
PACIFICORP _ 20I9 IRP APPENDIXE_SMARTGRID
In Oregon, PacifiCorp identifred 40 circuits on which cost benefit analyses were performed. From
this analysis two circuits in Lincoln City, Oregon were selected to have a fault location, isolation
and service restoration (FLISR) system installed. The project is on track to be installed by the end
of 2019. This pilot is intended to provide field validation of lab tested solutions for outage
management and automated restoration, and will identifr improvements to the operating systems
and drive implementation of FLISR throughout the service territory.
Wildlire Mitigation
In response to concerns of wildfue danger to customers, PacifiCorp began developing
communication systems and practices to improve system reliability in at risk areas. Selected
substations in Siskiyou County, Califomia and Wasatch County, Utah are preliminary sites that
will have rernote communication installed to allow dispatch operators to modiry re-closer settings.
Development of standards for re-closers to enable the remote communication have been completed
and the pilot implementation will be provided to at risk substations by the conclusion of20l9. The
ability to inte$ate legacy systems to various communication networks will allow PacifiCorp to
improve its response to failures in remote locations.
Distribution Substation Metering
Substation monitoring and measurement of various electrical attributes were identified as a
necessity due to the increasing complexity of distribution planning driven by growing levels of
primarily solar generation as distributed energy resources. Enhanced measurements improve
visibility into loading levels and generation hosting capacity as well as load shapes, customer usage
pattems, and infomntion about reliability and power quality events.
ln20l7, an advanced substation metering project was initiated to provide an affordable option for
gathering required substation and circuit data at locations where SCADA is unavailable and/or
uneconomical. SCADA has been the preferred form ofgathering load prolile data from distribution
circuits, however SCADA systems can be expensive to install and additional equipment is required
to provide the data needed to perform distribution system and power quality analysis. When system
data rather than data and control is important, SCADA is no longer the best option.
A preliminary wave of approximately 20 meter replacements with cellular communications were
deployed in 2018, with 30 additional meters to be firlly deployed by the end of2019 at identified
substations to firlly investigate their capabilities. Specialized software will provide users a refined
view the reliability and power quality information in addition to the standard substation and circuit
data. The project will also evaluate if the metering solutions provide cost effective situational
awareness and control.
Distributed Energy Resources
Enerry Storage Systems
ln 2017, PacifiCorp filed the Energy Storage Potential Evaluation and Energy Storage Project
proposal with the Public Utilities Commission or Oregon. This filing was in alignment with
PacifiCorp's sftategy and vision regarding the expansion and integration of renewable
technologies. The company proposed a utility-owned targeted energy storage system @SS) pilot
project. In 2019 PacifiCorp began project development and is progressing to build an ESS on a
Hillview substation distribution circuit in Corvallis, Oregon. This is a 20.8 kV radial distribution
cfucuit with a peak load of 20 megawatts (MW). The intent of this project is to integate the ESS
75
PACIFICORP _ 2OI9 IT{P APPENDIXE_SMARTGRID
into the existing distribution system with the capability and flexibility to potentially advance to a
future micro grid system.
PacifiCorp is installing a stationary battery system and photovoltaic (PV) solar array to test the
effectiveness of using non-traditional methods to correct the voltage issues during peak loading
conditions. The project location is on a disftibution circuit out of the Panguitch substation located
in Garfield County, Utah with an anticipated in-service date of November 2019. This project is
intended to reduce the loading on the power transformer, improve voltqgs conditions, and mitigate
costs associated with upgrading the upstream 69 kV transmission system under a traditional poles
and wires build-out. The battery system is rated at one MW capacity and five megawatt-hours
(MWh) of energy delivery, and the solar PV array is rated at 650 kilowatts (kW) of capacity.
PacifiCorp is partnering with Utah State University to demonstrate the ability to integrate solar
PV, natural gas generation, energy storage, and electronic confiols to create a customer managed
microgrid. This microgrid is designed to operate autonomously and seamlessly connect and
disconnect from the company's electric grid based on demand and supply. The microgrid system
will be located at Utah State University's Electric Vehicle Roadway facility in Logan, Utatr and is
expected to be firlly operational by the end of 201 9.
Demand Response
In 2018, PacifiCorp transitioned to tle automatic dispatch ofthe residential air conditioner (A"/C)
program in Utah, utilizing two-way communication devices to respond to frequency dispatch
signals. Known as Cool Keeper this ftequency dispatch innovation is a grid-scale solution using
fast-acting residential demand response resources to support the bulk power system. Some utilities
use generating resowces to perform this function, but as higher levels of wind and solar resources
are added, additional balancing resources are required. The Cool Keeper system provides over 200
MWs of operating reserves to the system through the conhol of more than 108,000 A/C units.
Dispatchable Customer Resources
PacifiCorp partnered with a developer in 2018 to make an innovative solar and battery solution
possible at a 600 unit multi-family community in Utah. Known as Soleil Lofts, this project
provides a unique oppornrnity for the company to implement an hnovative solution using solar
and battery storage integration along witl demand response and advanced management ofthe grid
tlrough daily energy load shaping. The project will include the development ofa company-owned
utility data and dispatch portal with direct access to 621 Sonnen batteries, each rated at 8kW, for
a total of 4.8 MWs of capacity and 12 MWh of energy within the project area. In addition to the
cost savings with leveraging the Soleil community partnership, ttre project creates opportunity to
develop and test new programs related demand response, load shaping and rate design.
Advanced Metering fnfrastructure
Advanced metering infrastructure (AMI) is an integrated system of smart meters, communications
networks, and data management systems that provide interval data available on a daily basis. This
infrastructure can also provide advanced functionalities including remote connecVdisconnect,
outage detection and restoration signals, and support distribution automation schemes. In 2016,
PacifiCorp identified economical AMI solutions for Califomia and Oregon that delivered tangible
benefits to customers while minimizing the impact on consumer rates. The Califomia AMI project
was completed in 2018 and the Oregon project is on schedule for completion before the end of
2019. The Califomia project installed approximately 45,000 smart meters and constructed a field
area network covering the 11,000 square mile Califomia service area. The Oregon project will
76
PACIFICOR-P-2OI9IRP APPENDIXE_SMARTGRID
install approximately 608,000 smart meters and construct a field area network covering the 21,000
square mile Oregon service area.
A new information technology (IT) infrastructure for the AMI project was put in place prior to the
start of field network and meter deployments. This IT solution inciuded all required data
acquisition, corurecVdisconnect, outage detectior/restoration and related functions as well as an
enhanced customer website that allows customers to view their hourly, daily, weekly, and monthly
usage. The information provided through the enhanced website provides customers with more
tools to better monitor and manage their energy usage.
In 2018, AMI projects were approved for Utah and Idaho, and work on these projects is underway
and scheduled for completion by the end of 2021. The projects will be executed under one
management structure with two strategies, and involves replacing nearly all Idaho meters with
Itron Riva smart meters and constructing a field area network that will allow two-way meter
communication. AMI firnctionality consistent with Califomia and Oregon will be delivered in
Idaho including capturing interval read data, remote connect and disconnect capability, outage
management functionality and analytic data.
In Utatr, a hybrid AMR/AM system will be put in place, and approximately 172,000 Iton Riva
smart meters will be installed in snategic locations. These meters will deliver full AMI
functionality, consistent with ldaho. The field area network will be able to communicate with the
new Riva meters and the approximately 790,000 remaining AMR meters that were installed
beginning with the initial AMR deployment started in 2006. This hybrid solution will enable
interval data and outage management capability for the AMR meters while allowing the
investrnent to be better utilized. Over time, the AMR meters will be replaced with AMI meters as
they fail, or new meters are connected, or in areas where customer or business benefits are
identified.
Outage Management Improvements
PacifiCorp is in the process of upgrading its outage management software to incorporate smart
meters outage notifications. These notifications, in concert with customer reported outages, will
provide higher visibility into distribution systems to identifr the most likely point of failure. With
this information field operations will be able to locate and isolate the damaged sections and restore
custome$ sooner, while providing better clarity to customers through the existing web-based
outage map. The software upgrade will be completed in mid-2020.
In Utah, PacifiCorp has initiated a project to enhance the ability to receive outage notifications
from intelligent line sensors, smart meters and existing AMR meters. The intelligent line sensors
will be installed on distribution circuits that will provide service to critical facilities. For the
purpose of this project, critical facilities have been defined as major emergency facility centers
such as hospitals, hauma centers, police and fire dispatch centers, etc. The information provided
by the line sensors will allow control center operators to target restoration at critical facilities
during major outages sooner than is ctrnently possible. Full implementation of the project is
expected to be completed by December 2021, concurrent witl the completion of the AMI project.
76a
PACIFICORP _ 2OI9 IRP APPENDIXE-SMARTGRID
PacifiCorp is continuing to evaluate smart grid technologies and pilot projects that can benefit
customers. The company regularly develops smart grid reports to examine the quantifiable costs
and benefits of individual components of the smart grid. While the net present value of
implementing a comprehensive smart grid system throughout PacifiCorp is negative at this time,
the company has implemented specific projects and programs that have positive benefits for
customers and continue to explore pilot projects in other areas of interest. In order to reduce risks
to the company, the grid, our customers and supporting systems, it is essential to identifr affordable
advanced technologies and implement industry best practices.
76b
Future Smart Grid
Case Fact Sheets - Overview
CP-Cases Portfolio-Develoomcnl Facl Shee8
The following CP-Cases Portfolio-Development Fact Sheets strmmarize key assumptions and portlolio results
for each CP-Case developed for the 2019 IRP.
Ouick Reference Guide
No Gas & Enerw Galewav Fact Sheets
The following Fact Sheets summarize key assumptions and portfolio results for each No Gas and Energy
Gateway Case developed for the 2019 IRP.
Ouick Reference Guide
P-l6CP 2t,553 Base Med Gas,
Mcd COr Base
Jim Brid8cr l-2 and
Nsughton I -2
Rctiremcnt 2025
P46 Base Sctmcnt F 2026
P4sCP 2l,480
Jim Bridgcr t-2
Rrtircmcrr 2023 and
2038
P-31 Bale Base Med Gas,
Mcd COr Base Segment F 2026
P46CP JimBridger3&4
Rctircmcnt 2025 P-31 2t,460 Base Base Mcd Gas,
Mcd CO,B&9c Sctmcnt F 2026
P46CP
t23C 21,402 Base Med Gas,
Med CO,Basc Segnent FJimBridgcr3&4
Rctircmcnt 2023 P46 Bas€2026
P47CP JiInBridger3&4
Rctbcment 2035 P45 2t,469 Base Base Mcd Ga!,
Mcd CO,Brse Segm€nt F 2026
P-48CP JimBridgcr3&4
Retircment 2033 P-45 21,451 Base Base Mcd GA3.
Mcd CO,Basc Segmcnt F 2026
P-53CP
JimBridgcrl&2
R€tirement 2025, Jim
BridScr 3 Rctir€meDt
2028, ind Jim Bridger 4
R.tircmcm 2032
P.3l 2t,479 Base Base Mcd Gas,
Med COr Base Segmeit F 2026
P-29 P-45CNW, No New Gas
Option P45CN}Y 2t,798 Base Base Med Gas,
M.d CO,Base Segmcnt F
P-29
PS 2t,970 Base Base Mcd Gas,
Mcd CO Basc Scgment F
P-45CNW, No Nel 6as
Option \f,ith pump€d
hydro storagc
P-45CNW
P-22 21,8t6Encr$r Gatcway Segment
D.3 P.45CNW Basc Base Mcd Gas,
Med CO,Base Add Segmeat
D.3 2030
P-23 En rgy Ga&way Scgment
D,3,E&H P.36CP'22,151 Base Base Med Gas,
Mcd COr Basc
Add Segrcnrs
D.3, Segmeit
E, ard H
2026
P-25 Encrgy Cdlwcy Scgment
D,3,E&H P.45CNW 22.213 Bas€Bas€Med Gas,
Med COr Basc
Add Segments
D.3, Segment
E, and H
2030
P-26 EncrS/ Gateuay Segmcnt
H P-45CNW 21,519 Base Base Med Gas,
Mcd CO!Base Add Segment
H 2028
I P-36 retirements with no DJ win4 no send-alone solar and expanded r€liability studies.
276
Cr'c Il.rcripdoD Prrart
Crta
so
PVRR
($D)
Lo.d PriYata
Gell cor Pollcy FCITs Grt wry
l'Yer of
Nfir
Ttcntr.l
Cllc Darcrlpfior Prrcnt
Crrt
so
PVNR
($D)
Lord PriYrta Gctr Col Policy FOTi Grt.wrv
1' Ycrr of
Th.rEd
Crlc Da.tarlpdotr ParaDt
C$a
so
PVRR
(sD)
Lord PrivrtG
Geu COr Policy FOTr GrtctrY
It Y.rr of
Nav
ThcrE.l
Portfolio: Enerry Gateway Segment D3 @-22)
Transmission
Incremental tansmission path D3 is shown in the map below.
C.LsB Assuurrroxs
Desciotion
Gateway Study P-22 includes Segment D3 -Bridger/Anticline
to Populus, which also increases Path C capacity from Borah
to Utah North. Path C capacity expands by 1,000 MW
nonhbound, and by 650 Mw southbound. This $ensitivity is a
variant ofthe preferred portfolio, P-45CNW.
PoRTFoLIo Suwu,ny
Svstem Ootimizer PVRR ($ 521,886
Resource Portfolio
Cumulative changes to the resource porfolio (new resource
additions to address load service and reliability requirements
and resource retirements), represented as cumulative nameplate
capacity, arc zummarized in the figure below.
Cumul.tive Namaplata Capacity
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Descriplion Year Cuoacin'
2026 I,700+ I,000( D 3 ) B ridger/Ant ic I i ne- P o pulus
2024 I,700Aeolus Wyoming - to - Utah S
Goshen - to - Utah N 2030 800
Yakima- to S. Aeron/California 2037 150
3'18
Energy Gateway Portfolio-Development
Fact Sheets
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Portfolio: Energi Gateway Segmentr D3, E and H (P-23)
Transmission
Incremental transmission paths are shown in the map below
C.Lsr Assulrrroxs
Descriolion
Gateway Study P-23 includes Segment D3 - Populus to
Bridger/Anticline, along with Segment E, Populus-
Hemingway and Segrn€nt H, Boardman - Hemingway. This
sensitivity is a variant ofthe case P-36CP.
Ponrror,ro Suutu,q,ny
Svstem Oprtmizer PYRR 6ml $22,151
Resource Portfolio
Cumulative changes to the resowce portfolio (new resource
additions to address load service and reliability requirements
and resource retirements), represented as cumulative nameplate
capacity, are summarized in the figure below.
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2026 1,260E - Populus-Heminway
H - Boardman-Heminswov 2027 600
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2037 150Yakima- to - S. Oregon/California
Energy Gateway Portfolio-Development
Fact Sheets
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Portfolio: Energr Gateway Segments D3, E and H (P-2O
Transmission
Incremental tsansmission paths are shown in the map below
Clsn Assulryrroxs
Descinlion
Gateway Study P-25 includes Segrrent D3 - Populus to
Bridger/Articline, along with Segment E, Populus-
Hemingway and Segpent H, Boardman - Hemingway. This
sensitivity is a variant ofthe preferred portfolio, P45CNW.
PoRTFoLIo Suu*mnv
Ststem Optimizer PVRR (Sm)$22,273
Resource Portfolio
Cumulative changes to the resource porfolio (new resource
additions to address load service and reliability requir€ments
and resource retirements), represented as cumulative nameplate
capacity, are sumnarized in the figure below.
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D 3 - Bridser/A fi icl ine- P opul us 2026 1,700+ 1,000
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2027 600H - B oardrnan-Heminpt ay
Aeolus lvyominp - to - Utah S 2024 1700
Goshen - to - Utah N 2030 800
Yakima- to - S. Orezon/Colifornia 2038 150
382
Energy Gateway Portfolio-Development
X'act Sheets
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Portfolio: Enerry Gateway Segment H (P-26)
Trusmission
Transmission path is shown in the map below
C.r,sr Assurwrroxs
Descriotion
Gateway Study P-26 includes Sepent H, Boardman -
Hemingway. This sensitivity is a variant ofthe prefened
porfolio, P-45CNW.
Ponrror,to Sutuumy
System Ootimizer PVRR ($d $21.579
Resource Porlfolio
Cumulative changes to the resource portfolio (new resource
additions to address load service and reliability requirements
and resourc€ retirements), represented as cumulativ€ nameplate
capacity, are summarized in the figure below.
Cumul.tive N.ft aplata Cap.clty
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Year Cspscitt,Descriotion
H - Boardma*Heminsww 2027 600
Aeolus W'yominq - to - Utah S 2021 1,700
2030 800Goshen - to - Utah N
Energy Gateway Portfolio-Development
Fact Sheets
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