20180411Dauphinais Supplemental Direct - Redacted.pdf

RECElVED
20\3 APR 11 PM 4:27
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
IN THE MATTER OF THE APPLICATION )
OF ROCKY MOUNTAIN POWER FOR A )CERTIFICATE OF PUBLIC )CASE NO.PAC-E-17-07
CONVENIENCE AND NECESSITY AND )BINDING RATEMAKING TREATMENT )
FOR NEW WIND AND TRANSMISSION )
FACILITIES )
REDACTED Supplemental Direct Testimony and Exhibits Of
James R.Dauphinais
On Behalf of
Monsanto Company
April l l,2018
Project 10465
CONFIDENTIAL
SUBJECT TO PROTECTIVE ORDER IN CASE NO.PAC-E-17-07
ROCKY MOUNTAIN POWER
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
CASE NO.PAC-E-17-07
Table of Contents to the
Supplemental Direct Testimony of James R.Dauphinais
I.INTRODUCTION AND SUMMARY..................................................l
II.PACIFICORP'S UPDATES TO THE TRANSMISSION PROJECTS ...............................3
III.ADDITIONAL EXPECTED TRANSFER CAPABILITY CONCERNS...........................8
IV.NEED FOR TRANSMISSION PROJECTS..................................................10
Exhibits:
Monsanto Exhibit 211:Response to WIEC Data Request 22.2
Monsanto Exhibit 212:Response to WIEC Data Request 22.4
Monsanto Exhibit 213:March 30,2018 Study Report -Aeolus West
Transmission Path Transfer Capability Assessment
Confidential Monsanto Exhibit 214:March 22,2018 Updated Study Summary
Monsanto Exhibit 215:Final Facilities Study for Boswell Wind Projects
Monsanto Exhibit 216:Response to WIEC Data Request 17.7
REDACTED Dauphinais,Di-Supp -i
Monsanto Company
ROCKY MOUNTAIN POWER
BEFORE THE IDAHO PUBLIC UTILITIES COMMISSION
CASE NO.PAC-E-17-07
Supplemental Direct Testimony of James R.Dauphinais
l I.INTRODUCTION AND SUMMARY
2 Q.PLEASE STATE YOUR NAME AND BUSINESS ADDRESS.
3 A.James R.Dauphinais.My business address is 16690 Swingley Ridge Road,Suite 140,
4 Chesterfield,Missouri 63017.
5 Q.WHAT IS YOUR OCCUPATION?
6 A.I am a consultant in the field of public utility regulation and a managing principal with
7 the firm of Brubaker &Associates,Inc.,which specializes in energy,economic,and
8 regulatory consulting.
9 Q.ARE YOU THE SAME JAMES R.DAUPHINAIS WHO PRE-FILED DIRECT
10 TESTIMONY IN THIS DOCKET ON BEHALF OF MONSANTO COMPANY
ll ("MONSANTO")?
12 A.Yes,I am.
13 Q.WHAT IS THE PURPOSE OF YOUR SUPPLEMENTAL DIRECT TESTIMONY?
14 A.I respond to the Supplemental and Second Supplemental Direct Testimony of Rocky
15 Mountain Power's ("RMP,""PacifiCorp"or the "Company")witness Mr.Rick A.Vail.
REDACTED Dauphinais,Di-Supp -1
Monsanto Company
l My silence with respect to any position taken by RMP in its supplemental and
2 second supplemental direct testimony in this proceeding should not be interpreted as an
3 endorsement of that position.
4 Q.PLEASE SUMMARIZE YOUR CONCLUSIONS.
5 A.Nothing in Mr.Vail's supplemental and second supplemental direct testimony on behalf
6 of RMP would lead me to change my conclusions regarding the specific risks associated
7 with RMP's proposed Transmission Projects in this proceeding:
8 1.Risks to Transmission Project construction costs or the receipt of Production Tax
9 Credits ("PTCs")for the Wind Projects due to the incomplete nature of RMP's power
10 system analysis studies for the Transmission Projects;'
ll 2.Risks to Transmission Project construction costs or the receipt of PTCs due to
12 incomplete permitting of the Transmission Projects;
13 3.Risks to Transmission Project construction costs or the receipt of PTCs due to
14 construction risks;and
15 4.Risks related to actually recovering a portion of the revenue requirement associated
16 with the Transmission Projects from PacifiCorp's third-party transmission customers.
17 Further,Mr.Vail's eleventh hour assertion in his supplemental direct testimony
18 that the Aeolus-to-Bridger/Anticline line portion of the proposed Transmission Projects
19 will need to be constructed in the near future even if the new Wind Projects are not
20 constructed is unsupported and contrary to RMP's direct testimony in this proceeding.
21 As a result,the assertion should be given no weight by the Idaho Public Utilities
22 Commission("Commission").
23 Because the Transmission Projects are not needed to provide reliable electric
24 service at lowest reasonable cost,and because the Transmission Projects can only be
'The Wind Projects are TB Flats I &H,Cedar Springs,Ekola Flats,and Uinta,totaling 1,311
MW of new capacity.The TransmissionProjects are the Aeolus-to-Bridger/Anticline line and network
upgrades required to interconnect the Wind Projects.
REDACTED Dauphinais,Di-Supp -2
Monsanto Company
l justified if the forecasted net benefits and risks associated with the Combined Projects are
2 such that pursuit of the Combined Projects is in the public interest for RMP's retail
3 customers in Idaho,I continue to recommend that if the Commission approves a CPCN
4 for the Combined Projects,that approval should include protections to increase the
5 likelihood that customers will benefit from the Company's proposal.
6 II.PACIFICORP'S UPDATES TO THE TRANSMISSION PROJECTS
7 Q.PLEASE BRIEFLY SUMMARIZE THE UPDATES MR.VAIL PROVIDES IN
8 HIS SUPPLEMENTAL DIRECT TESTIMONY WITH RESPECT TO THE
9 TRANSMISSION PROJECTS.
10 A.Mr.Vail provides updates on the status of:
11 Expected design and cost for the Transmission Projects based on the outcome of the
12 2017R RFP;
13 Engineering,Procurement and Construction ("EPC")contracts;and
14 Required easements.
15 Based on the outcome of the 2017R RFP,the estimated cost of the 230 kV and
16 138 kV Network Upgrades portion of the Transmission Projects has increased over 150
17 percent,from approximately million to million due to the selection of the
18 Cedar Springs and Uinta Wind Projects.2 Mr.Vail indicates these increased estimated
19 transmission costs have been incorporated into RMP witness Link's updated economic
20 analysis.3 Mr.Vail also indicates the additional Network Upgrades will not delay the
21 completion of the Transmission Projects as a whole and have not materially changed
22 RMP's timeline or process for finalizing EPC contracts.4
2 Supplemental Direct Testimonyof Rick A.Vail at pp.3-5.
3 Id.at pp.4-5.
4 Id.at pp.5-6.
REDACTED Dauphinais,Di-Supp -3
Monsanto Company
l Q.PLEASE BRIEFLY SUMMARIZE THE ADDITIONAL UPDATE MR.VAIL
2 PROVIDES IN HIS SECOND SUPPLEMENTAL DIRECT TESTIMONY WITH
3 RESPECT TO THE TRANSMISSION PROJECTS.
4 A.Mr.Vail provides an additional update with respect to the makeup and estimated cost of
5 the 230 kV and 138 kV Network Upgrades portion of the Transmission Projects as a
6 result of RMP's restudy of the System Impact Studies ("SIS")for several of the Wind
7 Projects.This restudy was triggered by RMP's plan to complete the Energy Gateway
8 Aeolus-to-Bridger/Anticline D.2 transmission segment in 2020.6 The additional update
9 of the Network Upgrades also reflects RMP's decision to replace the McFadden Ridge II
10 Wind Project with the Ekola Flats Wind Project.Mr.Vail identifies that the estimated
11 cost of the 230 kV and 138 kV Network Upgrades portion of the Transmission Projects
12 has increased yet again by another 11%-this time from million to
13 million.
14 Mr.Vail also reports that RMP has confirmed there is sufficient transfer
15 capability to interconnect the 1,150 MW of the proposed Wind Projects that would be
16 interconnected behind the TOT4A/TOT4B constraint along with a 240 MW Qualifying
i
17 Facility that already has an executed interconnection agreement.Specifically,Mr.Vail
18 indicates RMP's updated studies indicate it can interconnect 1,510 MW of incremental
19 wind generation behind the TOT4A/TOT4B constraint.6
6 Second Supplemental Direct Testimonyof Rick Vail at pp.1-4.
6 Id.at 7.
REDACTED Dauphinais,Di-Supp -4
Monsanto Company
l Q.DO MR.VAIL'S UPDATES ALLEVIATE OR REDUCE THE RISKS TO
2 TRANSMISSION PROJECT CONSTRUCTION COSTS OR THE RECEIPT OF
3 PTCs DUE TO CONSTRUCTION RISK THAT YOU DISCUSSED IN YOUR
4 DIRECT TESTIMONY?
5 A.No.At best,they remain the same as they were.For example,while Mr.Vail reported
6 on transmission right-of-way acquisition in his supplemental direct testimony,'in
7 response to Data Request WIEC 22.2,8 RMP admitted that as of March 22,2018,it has
8 only acquired 2.8819 miles (or 2.8%)of the total right-of-way necessary for the
9 Transmission Projects."In addition,based on RMP's response to Data Request WIEC
10 22.4,it is clear RMP has a large list of regulatory approvals and permits ahead of it for
11 the Transmission Projects.'°
12 Finally,quite possibly,the risks associated with the Transmission Projects may be
13 greater due to the additional Network Upgrades that have now been added to the
14 Transmission Projects.As a general principle,the more expensive and complex a project
15 is,the greater the risks involved.
7 Supplemental Direct Testimonyof Rick A.Vail at p.6.
*Wyoming Public Service Commission,Docket No.20000-520-EA-17("Wyoming New
Wind/TransmissionDocket"),Data Request WIEC 19.2.WIEC stands for "Wyoming Industrial Energy
Consumers."In Monsanto Data Request No.2 to RMP,Monsanto requested a copy of all data requests
and responses from the Wyoming New Wind/TransmissionDocket in discoveryin this proceeding.
MonsantoExhibit No.211
io MonsantoExhibit No.212.
REDACTED Dauphinais,Di-Supp -5
Monsanto Company
l Q.DOES MR.VAIL'S UPDATE WITH RESPECT TO RMP'S TECHNICAL
2 STUDIES FOR THE TRANSMISSION PROJECTS ALLEVIATE YOUR DIRECT
3 TESTIMONY CONCERNS WITH RESPECT TO THE INCOMPLETE NATURE
4 OF THOSE STUDIES AND THE RISKS THEY POSE TO CONSTRUCTION
5 COSTS AND THE RECEIPT OF PTCs?
6 A.No.In its 16'Supplemental Response to Data Request WPSC 3.4,"RMP provided a
7 copy of its updated study report of March 30,2018 regarding its Aeolus West
8 Transmission Path Transfer Capability Assessment.I have included a copy of this
9 updated study report as Monsanto Exhibit No.213.The updated study report indicates
10 that RMP's updated power flow analyses could support 1,510 MW of incremental wind
11 generation behind the TOT4A/TOT4B constraint and an incremental east to west transfer
12 capability across Wyoming of 951 MW.12 However,the updated study report also
13 indicates that RMP currently has unresolved issues with the modeling of some of the
14 wind turbine models in its dynamic stability studies."While the Company believes it
15 can resolve the issue with the wind turbine manufacturer,the issue is nevertheless still
16 outstanding.
17 In addition,in Response to Data Request WIEC 22.3,RMP provided a March 22,
18 2018 update to its Response to WIEC Informal Data Request 1.1,14 which summarized
19 the additional technical studies that will need to be completed for the Transmission
20 Projects.I have provided a copy of this updated summary as Confidential Monsanto
"Wyoming Wind/TransmissionDocket 1"Supplemental Response to Data Request WPSC 3.4.
WPSC stands for Wyoming Public Service Commission.
12 MonsantoExhibit No.213 at pp.12-14 and 17.
"MonsantoExhibit No.213 at 17.
14 RMP's Response to WIEC Informal Data Request 1.1 was provided in Monsanto Exhibit No.
206.
REDACTED Dauphinais,Di-Supp -6
Monsanto Company
1 Exhibit No.214.The updated summary shows the initial transfer capability assessment
2 studies will and joint transfer capability assessment
3 studies are .The updated summary also
4 shows that RMP's Remedial Action Scheme ("RAS")studies will
5 .Moreover,it does not appear RMP has completed its study for the Latham
6 Dynamic Device.
7 The incomplete nature of all of the foregoingstudies exposes RMP to the risk that
8 something in the results of the studies when they are completed could lead to:(i)the
9 needed transfer capability and incremental wind interconnection capability either not
10 being realized or delayed;or (ii)the Transmission Projects having greater costs than
11 forecasted by RMP.Failure or delay in the full realization of the necessary incremental
12 transfer capability and wind interconnection capability could lead to the Wind Projects
13 not receiving their full PTCs.This would significantly reduce the forecasted gross
14 economic value of the Combined Projects.Additional costs for the Transmission
15 Projects would increase the total costs for the Combined Projects.In either case,the
16 forecasted net benefits of the Combined Projects would be reduced -potentially down to
17 a net cost for RMP's retail customers.
REDACTED Dauphinais,Di-Supp -7
Monsanto Company
l III.ADDITIONAL EXPECTED TRANSFER CAPABILITY CONCERNS
2 Q.DO YOU HAVE ANY OTHER CONCERNS WITH RESPECT TO THE
3 EXPECTED TRANSFER CAPABILITY OF THE PROPOSED TRANSMISSION
4 PROJECTS BASED ON YOUR REVIEW OF MR.VAIL'S SECOND
5 SUPPLEMENTAL TESTIMONY?
6 A.Yes.According to Mr.Vail,RMP is targeting 1,510 MW of incremental wind
7 interconnection capability behind the TOT3B/TOT4B constraint."Mr.Vail notes this is
8 sufficient to cover the 1,150 MW of the Wind Projects that would be behind the
9 TOT3B/TOT4B constraint plus a 240 MW Qualifying Facility that already has a
10 generation interconnection agreement.However,this fails to consider another 320 MW
11 QualifyingFacility that executed an interconnection agreement with RMP on June 22,
12 2016,which would be interconnected behind the TOT3A/TOT4A constraint near Aeolus.
13 Specifically,the Boswell Wind Projects have a higher priority queue number (Q409-A
14 through Q409-D)and,according to their Final Facilities Study,would require use of
15 capacity on the Energy Gateway Transmission Projects including the Aeolus-to-
16 Bridger/Anticline D.2 segment.I have provided a copy of the Final Facilities Study for
17 this Qualifying Facility as Monsanto Exhibit No.215.The queue status of this
18 QualifyingProject may mean that RMP needs 1,710 of incremental wind interconnection
19 capability behind the TOT4A/TOT4B constraint rather than 1,510 MW.
20 Q.HAS ANY INQUIRYBEEN MADE TO RMP WITH RESPECT TO THIS ISSUE?
21 A.Yes.In its Response to Data Request WIEC 17.7 (Monsanto Exhibit No.216),RMP
22 claims that because other elements of the Energy Gateway Projects would be needed for
23 the Boswell Wind Projects beside the Aeolus-to-Bridger/Anticline line,RMP does not
"Second Supplemental Direct Testimony of Rick A.Vail at p.7.
REDACTED Dauphinais,Di-Supp -8
Monsanto Company
l need to reserve interconnection capability for the Boswell Wind Projects on the
2 Aeolus-to-Bridger/Anticlineline.
3 Q.HOW DO YOU RESPOND TO THIS CLAIM?
4 A.My review of the Revised System Impact Study and Final Facilities Study for the
5 Boswell Wind Projects shows that RMP never really examined whether they could be
6 interconnected with elements of the Gateway West alone without Gateway South.As a
7 result,in my opinion,a restudy would be in order to examine whether their
8 interconnection would be feasible with only the Aeolus-to-Bridger/Anticline Segment
9 D.2 of the Gateway West Projects added,despite the statement in the Final Facilities
10 Study that both Gateway West and Gateway South are required for the Boswell Wind
11 Projects.It makes little sense that other wind interconnections near Aeolus do not require
12 Gateway South,but the Boswell Wind Projects do.
13 If the Transmission Projects are constructed as proposed,there is no assurance
14 that RMP will have sufficient capacity for the Wind Projects in light of QFs such as the
15 Boswell Wind Projects with potentially superior queue positions.That could result in
16 either:(i)a need to potentially increase transfer and interconnection capability beyond
17 that provided by the Transmission Projects -presumably at ratepayer expense;or (ii)a
18 higher risk that the Wind Projects would need to be curtailed,which in turn would result
19 in lower PTCs.This would further increase the risks associated with construction costs
20 of the Combined Projects and the receipt of PTCs from the Wind Projects.
REDACTED Dauphinais,Di-Supp -9
Monsanto Company
1 IV.NEED FOR TRANSMISSION PROJECTS
2 Q.PLEASE SUMMARIZE MR.VAIL'S SUPPLEMENTAL DIRECT TESTIMONY
3 CLAIM WITH RESPECT TO THE NEED FOR THE AEOLUS-TO-
4 BRIDGER/ANTICLINE LINE PORTION OF THE PROPOSED TRANSMISSION
5 PROJECTS.
6 A.Mr.Vail claims,for thefirst time,that there is a need for the Aeolus-to-Bridger/Anticline
7 line,even if the new Wind Projects are not constructed,because it will improve system
8 performance and reliability and directly service customers.l6 To support this claim,he
9 notes long-term transmission plans still call for construction of the line by 2024.2
10 Q.HOW DO YOU RESPOND?
11 A.This "eleventh hour"claim of Mr.Vail should be given no weight.First,as I discussed
12 in my direct testimony,"RMP admitted in its direct testimony that the Transmission
13 Projects and Wind Projects are mutuallydependent on each other.19 RMP also admitted
14 in direct testimony that the Transmission Projects are not necessary for RMP to meet
15 NERC Standards for the Bulk Electric System and WECC Regional Standards and
16 Criteria.20 Furthermore,RMP admitted in direct testimony that the Transmission Projects
17 are not economic without the Wind Projects.2l With respect to long-term transmission
18 plans,at best they identify the line may be necessary at some point in the future.
19 However,long-term transmission plans are not evidence that the line in fact will
20 ultimatelybe needed.
16 Supplemental Direct Testimonyof Rick A.Vail at pp.6-7.
17 Id
"Direct Testimonyof James R.Dauphinaisat pp.4-6.
*Direct Testimony of Cindy A.Crane at p.3.
20 Direct Testimony of Rick A.Vail at pp.19,22-23.
21 ÜÏTOCtTOStimony of Cindy A.Crane at p.10.
REDACTED Dauphinais,Di-Supp -10
Monsanto Company
l Q.CAN YOU PROVIDE AN EXAMPLE TO ILLUSTRATE HOW LONG-TERM
2 TRANSMISSION PLANS ARE NOT EVIDENCE OF NEED?
3 A.Yes,the Commission only needs to look at the history of PacifiCorp's Energy Gateway
4 project to find that long-term transmission plans are not evidence of need.In
5 PacifiCorp's 2011 Integrated Resource Plan ("IRP"),the Company identified planned
6 in-service dates between 2015-2017 for Segment D of Energy Gateway.22 That did not
7 happen.Then,in the Company's 2013 IRP,the "scheduled"in-service dates for Segment
8 D were moved to 2019-2021.23 But,two years later,the window of "scheduled"
9 in-service dates for Segment D was expanded in the 2015 IRP to 2019-2024.24 Although
10 these "scheduled"in-service dates for the sub-segments of Segment D did not change in
11 the 2017 IRP,25 that does not mean they will not change in the future (particularly if they
12 are not necessary for RMP to meet NERC Standards for the Bulk Electric System and
13 WECC Regional Standards and Criteria).
14 Q.DOES THIS CONCLUDE YOUR SUPPLEMENTAL DIRECT TESTIMONY?
15 A.Yes,it does.
\Doc Shares ProlawDocs MED 10465 Testimony-BAT342829.docx
22 PacifiCorp's 2011 IRP at p.291.Segment D includes the Aeolus-to-Bridger/Anticline line.
23 PacifiCorp's 2013 IRP at p.74.
24 ŸRCiÍÏCOrp's 2015 IRP at p.57.
25 PacifiCorp's 2017 IRP at p.71.
REDACTED Dauphinais,Di-Supp -11
Monsanto Company
Monsanto Exhibit No.211
20000-520-EA-17/Rocky Mountain Power Case No.PAC-E-17-07
March 22,2018 Page 1 of 4
WIEC Data Request 22.2
WIEC Data Request 22.2
Please refer to Mr.Vail's March 14,2018 supplemental rebuttal testimony at page 3,
lines 6-10.
(a)Please provide a complete copy of all documents in Mr.Vail's possession (or that he
relied upon for his supplemental rebuttal testimony)that support his statement "the
Company is steadily progressing through the process to acquire necessary easements
and rights-of-way in parallel with the regulatory-approvals process and,based on the
progress to date,remains on track to secure the necessary easements and rights-of-
way to support the construction schedule."
(b)Please identify,as of March 1,2018,the total miles of easements and rights-of-way
of way that gave been acquired for the Transmission Projects and the total remaining
miles of easements and rights-of-ways that remain to be acquired for the
Transmission Projects.
(c)Please provide the Company's latest schedule for completion of the acquisition of the
remaining easements and rights-of-ways that need to be acquired by the Company for
the Transmission Projects.
Response to WIEC Data Request 22.2
(a)Please refer to Attachment WIEC 22.2-1.
(b)Line Mileage Acquisition status (non-public lands)
Total T-Line Mileage:101.1664
Total T-Line Mileage Acquired:2.88 19
Total T-Line Mileage Remaining to be Acquired:98.2845
(c)Please refer to Attachment WIEC 22.2-2.
Respondents:Todd Jensen /Stuart Smith
Witness:Rod Fisher
Monsanto Exhibit No.211
Case No.PAC-E-17-07
Page 2 of 4
Gateway West /EV2020 Transmission Right of Way
OFFER SIGNEDPROPERTYOWNERFACILITY NOTESMAILEDAGREEMENT
ADAMS,STEPHEN F.&CAROLYN L.500kV 11/1/17 Negotiating
230 &ANADARKOLAND CORP.500KV 3/20/18 Negotiating
ANDERSON,VICTOR G.&NANCY F.500kV 11/1/17 Negotiating
AccessBLACKBUTTECOAL 1/24/18 Negotiatingonly
BLAKE SHEEP COMPANY 500kV 11/1/17 Negotiating
AccessBUFFALOWATERCOMPANY,LLC 11/28/17 Negotiatingonly
CITY OF RAWLINS 500kV 11/1/17 Negotiating
AccessCOLORADOINTERSTATEGASCO.11/28/17 Negotiatingonly
ECHO SPRINGS 500kV 11/1/17 Negotiating
ELLIS,WILLIAM R.&MARY LOU 230kV 1/22/18 Negotiating
HANSEN,FREDERICKW.&JANE F.500kV 11/28/17 01/08/18 Signed option
AccessHANSEN,NEILS 11/28/17 Negotiatingonly
HEATH LAND &ENERGY 500kV 11/1/17 Negotiating
HI ALLEN RANCH 230kV 1/22/18 Negotiating
HOOKS RANCH 230kV 1/22/18 Negotiating
AccessHOOVER,MARK D.&ELLA JOY 1/24/18 Negotiatingonly
JAURE,TONYLEO 500kV 11/28/17 01/11/18 Signed option
AccessKORKOWRANCHCORPORATION 1/23/18 Negotiatingonly
i
Monsanto Exhibit No.211
Case No.PAC-E-17-07
Page 3 of 4
LARSEN,DONALDSABIN 500kV 11/1/17 Negotiating
AccessLITTLEAMERICAHOTELS&RESORTS 1/24/18 Negotiatingonly
MIDWEST LAND &LIVESTOCK 230kV 1/22/18 Negotiating
NL LAND &LIVESTOCK,INC 500kV 11/1/17 Negotiating
NORWEST BANK COLORADONA (Echeverria 500kV 11/1/17 NegotiatingTrust)
AccessOLSONLM,INC 11/28/17 01/05/18 signed optiononly
OVERLAND TRAIL LAND AND CATTLE 500kV 1/17/18 NegotiatingCOMPANY
230&PALM BURTON G SUCCESSORTRUSTEE 1/22/18 Negotiating500kV
PETERSON LIVESTOCK,LLC 500kV 11/1/17 Negotiating
SCHROEDER,BILL 500kV 11/6/17 02/07/18 signed easement
PH LIVESTOCKCO.500kV 11/1/17 Negotiating
230 &Q CREEK L&L /DIFFICULTYRANCH 1/22/18 Negotiating500kV
QWEST COMMUNICATIONSCORP.(Century Access 1/24/18 NegotiatingLink)only
RED RIM,INC.500kV 11/1/17 Negotiating
ROCK SPRINGS GRAZINGASSN.500kV 11/1/17 Negotiating
ROCKY MOUNTAINENERGY COMPANY /Access NegotiatingANADARKOonly
ROCKY MOUNTAINSHEEP CO.500kV 11/1/17 Negotiating
RODEWALD,DUANE &DEBORAH C.500kV 11/1/17 12/06/17 signed option
SARATOGA INVESTMENTS,LLC 500kV 11/28/17 Negotiating
SOUTHLANDROYALTYCOMPANY,LLC 500kV 11/1/17 Negotiating
Monsanto Exhibit No.211
Case No.PAC-E-17-07
Page 4 of 4
STATE OF WY GAME &FISH 500kV 1/22/18 Negotiating
230 &STATE OF WYOMING(OSLI)500kV Preparingapplication
UNION PACIFIC RAILROAD 500kV Preparingexhibits to submit
application
Monsanto Exhibit No.212
20000-520-EA-17/Rocky Mountain Power case No.PAC-E-17-07
March 22,2018 Page 1 of 12
WIEC Data Request 22.4
WIEC Data Request 22.4
Please refer to Mr.Vail's March 14,2018 supplemental rebuttal testimony at page 3 line
13,through page 4,line 5.
(a)Please provide the Company's latest schedule for submitting its remaining
submissions to BLM and receiving approvals from BLM.
(b)Please provide the Company's latest schedule for submitting its remaining
submissions to BLM and receiving approvals from the U.S.Army Corps of
Engineers.
(c)Please identify all remaining permitting and regulatory approvals that have not as of
yet been securedby the Company for the Transmission Projects and the latest status
of each of those permitting and regulatoryapproval requests.
(d)Please provide the Company's latest schedule for securing each of its remaining
permits and regulatoryapprovals necessary for the Transmission Projects.
Response to WIEC Data Request 22.4
(a)Please refer to Attachment Attach WIEC 22.4.
(b)The schedule of key activities for securing the Nationwide 12 Permit is outlined
below.
(1)The Company plans to submit the Potential Change Notice to the Agency by
October 1,2018.
(2)Comments to the submittal will be reviewed and incorporated and submitted to
the Agency by December 19,2018 for final acceptance.
(3)A request for Nationwide Permit verification letter will be submitted by January
2,2019.
(4)Issue Nationwide Permit 12 by January 30,2019.
(c)The Company continues to progress the permit and regulatory approvals for:
(1)Section 106 National Historic Properties Act.
(2)Plan of Development Notice to Proceed.
(3)Clean Water Act Section 404 Nationwide Permit 12.
(4)Wyoming Industrial Siting Permit.
(5)Carbon County Conditional Use Permit.
(6)Railroad crossing permits.
(7)Highway Encroachment permits.
Monsanto Exhibit No.212
20000-520-EA-17/Rocky Mountain Power Case No.PAC-E-17-07
Page 2 of 12March22,2018
WIEC Data Request 22.4
(d)The schedule for the above is as follows:
(1)Section 106 National Historic Properties Act:
i.SUBMIT:Draft HPTP to BLM:May 7,2018.
ii.COMPLETE:Final Report Production October 26,2018.
(2)Plan of Development Notice to Proceed:
i.Please refer to Attachment WIEC 22.4 for further details.
(3)Clean Water Act Section 404 Nationwide Permit 12:
i.Please refer to the Company's response to subpart (2)above.
(4)Wyoming Industrial Siting Permit:
i.SUBMIT June 29,2018.
ii.COMPLETE:December 12,2018.
(5)Carbon County Conditional Use Permit:
i.SUBMIT June 7,2018.
ii.COMPLETE December 14,2018.
(6)Railroad crossing permits:
i.Submit Q3 2018.
ii.Complete Ql 2019.
(7)Highway crossing permits
i.To be prepared and submitted by EPC Contractor to support construction
schedule.Anticipate Ql -Q2 2019.
(8)CPCN
i.SUBMIT:June 30,2017.
ii.COMPLETE June 11,2018.
Respondents:Todd Jensen /Stuart Smith /Rod Fisher
Witness:Rod Fisher
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D2
of
Ga
t
e
w
a
y
We
s
t
(S
h
i
r
l
e
y
Ba
s
i
n
to
Ae
o
l
u
s
to
Ji
m
Br
i
d
g
e
r
Se
g
m
e
n
t
s
)
(G
r
e
y
e
d
ro
w
s
we
r
e
ac
c
e
p
t
e
d
in
th
e
GW
W
RO
D
,
No
v
e
m
b
e
r
20
1
3
)
Ma
r
c
h
20
1
8
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
/
N
)
Co
n
s
t
r
u
c
t
i
o
n
Pl
a
n
of
Al
l
PO
D
pla
n
s
ar
e
Gr
o
u
p
1
-
Gr
o
u
p
1
co
m
m
e
n
t
s
re
c
e
i
v
e
d
De
v
e
l
o
p
m
e
n
t
(P
O
D
)
cu
r
r
e
n
t
l
y
be
i
n
g
up
d
a
t
e
d
an
d
in
c
o
r
p
o
r
a
t
e
d
in
t
o
up
d
a
t
e
d
an
d
re
v
i
e
w
e
d
by
BL
M
in
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
ve
r
s
i
o
n
s
3
se
t
s
.
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
fo
r
re
v
i
e
w
,
ex
p
e
c
t
e
d
Gr
o
u
p
2
co
m
m
e
n
t
s
re
c
e
i
v
e
d
RO
W
Gr
a
n
t
-
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
fr
o
m
Ro
c
k
Sp
r
i
n
g
s
,
st
i
l
l
St
i
p
u
l
a
t
i
o
n
la
pe
n
d
i
n
g
fr
o
m
Ra
w
l
i
n
s
du
e
Gr
o
u
p
3
-
to
be
Ma
r
e
l
i
14
,
20
1
8
su
b
m
i
t
t
e
d
Oc
t
o
b
e
r
1,
20
1
8
fo
r
BL
M
re
v
i
e
w
,
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
da
t
e
De
c
e
m
b
e
r
20
1
8
.
En
v
i
r
o
n
m
e
n
t
a
l
BL
M
re
v
i
e
w
co
m
p
l
e
t
e
Ac
c
e
p
t
e
d
in
RO
D
Co
m
p
l
i
a
n
c
e
PO
D
,
Ap
p
e
n
d
i
x
C
Y
(1
1
/
1
2
/
1
3
)
Ma
n
a
g
e
m
e
n
t
Pl
a
n
Re
c
l
a
m
a
t
i
o
n
Pl
a
n
Gr
o
u
p
3
-
to
be
Mo
n
i
t
o
r
i
n
g
lo
c
a
t
i
o
n
s
be
i
n
g
su
b
m
i
t
t
e
d
Oc
t
o
b
e
r
1,
id
e
n
t
i
f
i
e
d
PO
D
,
Ap
p
e
n
d
i
x
D
Y
Fr
a
m
e
w
o
r
k
Pla
n
in
PO
D
20
1
8
fo
r
BL
M
re
v
i
e
w
,
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Si
t
e
-
s
p
e
c
i
f
i
c
re
c
l
a
m
a
t
i
o
n
da
t
e
De
c
e
m
b
e
r
20
1
8
.
tr
e
a
t
m
e
n
t
s
to
be
id
e
n
t
i
f
i
e
d
by
1
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
4
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
/
N
)
Co
n
s
t
r
u
c
t
i
o
n
Co
n
t
r
a
c
t
o
r
an
d
re
v
i
e
w
e
d
by
CI
C
No
x
i
o
u
s
We
e
d
Pl
a
n
RO
W
Gr
a
n
t
-
Gr
o
u
p
3
-
to
be
Ch
a
n
g
e
d
to
Gr
o
u
p
3
fr
o
m
su
b
m
i
t
t
e
d
Oc
t
o
b
e
r
1,
Gr
o
u
p
2
to
in
c
l
u
d
e
20
1
8
St
i
p
u
l
a
t
i
o
n
s
10
&
11
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
20
1
8
fo
r
BL
M
re
v
i
e
w
,
su
r
v
e
y
da
t
a
.
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
p
p
i
n
g
to
be
up
d
a
t
e
d
wi
t
h
PO
D
,
Ap
p
e
n
d
i
x
E
da
t
e
De
c
e
m
b
e
r
20
1
8
.
20
1
9
su
r
v
e
y
da
t
a
St
o
r
m
w
a
t
e
r
Gr
o
u
p
2
-
to
be
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
Po
l
l
u
t
i
o
n
.
su
b
m
i
t
t
e
d
to
BL
M
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
Fr
a
m
e
w
o
r
k
Pla
n
in
PO
D
Pr
e
v
e
n
t
i
o
n
Pla
n
Ja
n
u
a
r
y
18
,
20
1
8
fo
r
-
de
t
a
i
l
e
d
in
f
o
to
be
PO
D
,
Ap
p
e
n
d
i
x
F
Y
.
re
v
i
e
w
,
BL
M
co
m
m
e
n
t
s
Co
n
t
r
a
c
t
o
r
to
fi
l
e
NO
l
s
wi
t
h
su
b
m
i
t
t
e
d
to
WY
D
E
Q
by
du
e
Ma
r
c
h
14
,
20
1
8
;
WY
DE
Q
Co
n
s
t
r
u
c
t
i
o
n
Co
n
t
r
a
c
t
o
r
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Sp
i
l
l
Pr
e
v
e
n
t
i
o
n
,
Gr
o
u
p
2
-
to
be
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
Co
n
t
a
i
n
m
e
n
t
,
an
d
su
b
m
i
t
t
e
d
to
BL
M
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
Co
u
n
t
e
r
m
e
a
s
u
r
e
s
Ja
n
u
a
r
y
18
,
20
1
8
fo
r
Pl
a
n
.
re
v
i
e
w
,
BL
M
co
m
m
e
n
t
s
PO
D
,
Ap
p
e
n
d
i
x
G
Y
Fr
a
m
e
w
o
r
k
Pla
n
in
PO
D
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Pl
a
n
t
an
d
Wi
l
d
l
i
f
e
Gr
o
u
p
3
-
to
be
Ma
p
p
i
n
g
to
be
up
d
a
t
e
d
wi
t
h
Co
n
s
e
r
v
a
t
i
o
n
su
b
m
i
t
t
e
d
Oc
t
o
b
e
r
1,
20
1
9
su
r
v
e
y
da
t
a
Me
a
s
u
r
e
s
Pl
a
n
PO
D
,
Ap
p
e
n
d
i
x
H
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
20
1
8
fo
r
BL
M
re
v
i
e
w
,
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
da
t
e
De
c
e
m
b
e
r
20
1
8
.
St
r
e
a
m
,
We
t
l
a
n
d
,
Gr
o
u
p
3
-
to
be
We
l
l
an
d
Sp
r
i
n
g
su
b
m
i
t
t
e
d
Oc
t
o
b
e
r
1,
Pr
o
t
e
c
t
i
o
n
Pla
n
PO
D
,
Ap
p
e
n
d
i
x
I
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
20
1
8
fo
r
BL
M
re
v
i
e
w
,
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
da
t
e
De
c
e
m
b
e
r
20
1
8
.
2
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
5
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
l
N
)
Pa
l
e
o
n
t
o
l
o
g
i
c
a
l
Gr
o
u
p
3
-
to
be
Me
e
t
i
n
g
wi
t
h
BL
M
on
Re
s
o
u
r
c
e
s
Pl
a
n
su
b
m
i
t
t
e
d
Oc
t
o
b
e
r
1,
Ja
n
u
a
r
y
25
,
20
-
1
8
to
di
s
c
u
s
s
PO
D
,
Ap
p
e
n
d
i
x
J
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
20
1
8
fo
r
BL
M
re
v
i
e
w
,
pl
a
n
pr
e
p
a
r
a
t
i
o
n
an
d
bL
M
EP
M
:
PA
L
E
O
-
5
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
rv
e
i
e
w
da
t
e
De
c
e
m
b
e
r
20
1
8
.
Ag
r
i
c
u
l
t
u
r
e
Ac
c
e
p
t
e
d
in
RO
D
BL
M
re
v
i
e
w
co
m
p
l
e
t
e
PO
D
,
Ap
p
e
n
d
i
x
K
Y
Pr
o
t
e
c
t
i
o
n
Pl
a
n
(1
1
/
1
2
/
1
3
)
Tr
a
f
f
i
c
an
d
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
Tr
a
n
s
p
o
r
t
a
t
i
o
n
Pl
a
n
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
fo
r
re
v
i
e
w
,
BL
M
PO
D
,
Ap
p
e
n
d
i
x
L
Y
Fr
a
m
e
w
o
r
k
Pla
n
in
PO
D
co
m
m
e
n
t
s
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Bl
a
s
t
i
n
g
Pl
a
n
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
fo
r
re
v
i
e
w
,
BL
M
PO
D
,
Ap
p
e
n
d
i
x
M
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
co
m
m
e
n
t
s
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Er
o
s
i
o
n
,
Du
s
t
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
Co
n
t
r
o
l
an
d
Ai
r
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
Qu
a
l
i
t
y
Pl
a
n
fo
r
re
v
i
e
w
,
BL
M
PO
D
,
Ap
p
e
n
d
i
x
N
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
co
m
m
e
n
t
s
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Fi
r
e
Pr
e
v
e
n
t
i
o
n
an
d
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
Su
p
p
r
e
s
s
i
o
n
Pl
a
n
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
fo
r
re
v
i
e
w
,
BL
M
PO
D
,
Ap
p
e
n
d
i
x
O
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
co
m
m
e
n
t
s
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
3
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
6
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
/
N
)
Ha
z
a
r
d
o
u
s
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
Ma
t
e
r
i
a
l
s
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
Ma
n
a
g
e
m
e
n
t
Pla
n
.
fo
r
re
v
i
e
w
,
BL
M
PO
D
,
Ap
p
e
n
d
i
x
P
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
m
PO
D
co
m
m
e
n
t
s
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Co
n
s
t
r
u
c
t
i
o
n
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
Em
e
r
g
e
n
c
y
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
Pr
e
p
a
r
e
d
n
e
s
s
an
d
fo
r
re
v
i
e
w
,
BL
M
PO
D
,
Ap
p
e
n
d
i
x
Q
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
Re
s
p
o
n
s
e
Pl
a
n
co
m
m
e
n
t
s
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Op
e
r
a
t
i
o
n
s
,
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
Ma
i
n
t
e
n
a
n
c
e
an
d
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
Em
e
r
g
e
n
c
y
Co
m
p
l
e
t
e
ex
c
e
p
t
fo
r
fo
r
re
v
i
e
w
,
BL
M
PO
D
,
Ap
p
e
n
d
i
x
R
Y
Re
s
p
o
n
s
e
Pl
a
n
em
e
r
g
e
n
c
y
co
n
t
a
c
t
li
s
t
co
m
m
e
n
t
s
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Cu
l
t
u
r
a
l
Re
s
o
u
r
c
e
s
Ac
c
e
p
t
e
d
in
RO
D
BL
M
re
v
i
e
w
co
m
p
l
e
t
e
PO
D
,
Ap
p
e
n
d
i
x
S
Y
Pr
o
t
e
c
t
i
o
n
Pl
a
n
(1
1
/
1
2
/
1
3
)
Fl
a
g
g
i
n
g
,
Fe
n
c
i
n
g
Gr
o
u
p
2
-s
u
b
m
i
t
t
e
d
to
Su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
an
d
Sig
n
a
g
e
Pl
a
n
BL
M
Ja
n
u
a
r
y
18
,
20
1
8
Ja
n
u
a
r
y
18
as
pa
r
t
of
Gr
o
u
p
2
fo
r
re
v
i
e
w
,
BL
M
PO
D
,
Ap
p
e
n
d
i
x
U
Y
Fr
a
m
e
w
o
r
k
Pl
a
n
in
PO
D
co
m
m
e
n
t
s
du
e
Ma
r
c
h
14
,
20
1
8
;
ex
p
e
c
t
e
d
co
m
p
l
e
t
i
o
n
Ma
y
20
1
8
.
Pa
c
i
f
i
C
o
r
p
'
s
BL
M
re
v
i
e
w
co
m
p
l
e
t
e
Tr
a
n
s
m
i
s
s
i
o
n
Ac
c
e
p
t
e
d
in
RO
D
PO
D
,
Ap
p
e
n
d
i
x
V
Y
Co
n
s
t
r
u
c
t
i
o
n
(1
1
/
1
2
/
1
3
)
St
a
n
d
a
r
d
s
Pa
c
i
f
i
C
o
r
p
'
s
an
d
Ac
c
e
p
t
e
d
in
RO
D
N/
A
PO
D
,
Ap
p
e
n
d
i
x
W
Y
Id
a
h
o
Po
w
e
r
'
s
(1
1
/
1
2
/
1
3
)
4
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
7
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
/
N
)
Ve
g
e
t
a
t
i
o
n
Ma
n
a
g
e
m
e
n
t
Pr
o
g
r
a
m
En
v
i
r
o
n
m
e
n
t
a
l
Ac
c
e
p
t
e
d
in
RO
D
BL
M
re
v
i
e
w
co
m
p
l
e
t
e
PO
D
,
Ap
p
e
n
d
i
x
Z
Y
Pr
o
t
e
c
t
i
o
n
Me
a
s
u
r
e
s
(1
1
/
1
2
/
1
3
)
Pr
e
c
o
n
s
t
r
u
c
t
i
o
n
Su
r
v
e
y
pla
n
s
an
d
NT
P
fo
r
ea
c
h
sp
e
c
i
e
s
,
Sp
e
c
i
a
l
St
a
t
u
s
pr
o
t
o
c
o
l
s
fo
r
ea
c
h
sp
e
c
i
e
s
ap
p
r
o
v
e
d
in
d
i
v
i
d
u
a
l
l
y
or
in
Sp
e
c
i
e
s
Su
r
v
e
y
s
RO
W
Gr
a
n
t
-
-
li
s
t
e
d
be
l
o
w
wi
l
l
be
gr
o
u
p
s
.
(L
i
s
t
e
d
Be
l
o
w
)
St
i
p
u
l
a
t
i
o
n
1c
su
b
m
i
t
t
e
d
to
BL
M
fo
r
re
v
i
e
w
/
a
p
p
r
o
v
a
l
in
Ba
l
d
Ea
g
l
e
Su
m
m
e
r
20
1
8
20
1
8
su
r
v
e
y
pl
a
n
to
be
su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
FE
I
S
3.
1
1
-
1
6
,
3.
1
1
-
4
3
Y
en
d
of
Ja
n
u
a
r
y
30
,
20
1
8
EP
M
:
WI
L
D
-
4
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Bu
r
r
o
w
i
n
g
Ow
l
Su
m
m
e
r
20
1
8
20
1
8
su
r
v
e
y
pl
a
n
to
be
su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
FE
I
S
3.
1
1
-
1
6
,
3.
1
1
-
4
5
Y
en
d
of
Ja
n
u
a
r
y
30
,
20
1
8
EP
M
:
WI
L
D
-
4
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Fe
r
r
u
g
i
n
o
u
s
Ha
w
k
Su
m
m
e
r
20
1
8
20
1
8
su
r
v
e
y
pl
a
n
to
be
su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
FE
I
S
3.
1
1
-
1
6
Y
en
d
of
Ja
n
u
a
r
y
30
,
20
1
8
EP
M
:
WI
L
D
-
4
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Gr
e
a
t
e
r
Sa
g
e
-
g
r
o
u
s
e
Ap
r
i
l
-
Mi
d
-
M
a
y
(l
e
k
20
1
8
su
r
v
e
y
pl
a
n
to
be
FE
I
S
3.
1
1
-
1
6
su
r
v
e
y
s
)
su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
EP
M
:
TE
S
W
L
-
5
Y
en
d
of
Ja
n
u
a
r
y
30
,
20
1
8
Ha
b
i
t
a
t
in
Se
g
m
e
n
t
s
1
-
10
.
5
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
8
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
/
N
)
Ne
w
re
q
u
e
s
t
to
BL
M
re
:
us
i
n
g
re
c
e
n
t
WG
F
D
da
t
a
Mi
d
g
e
t
Fa
d
e
d
Sp
r
i
n
g
20
1
7
No
su
i
t
a
b
l
e
ha
b
i
t
a
t
in
pr
o
j
e
c
t
Ra
t
t
l
e
s
n
a
k
e
ar
e
a
.
Dr
a
f
t
NT
P
le
t
t
e
r
be
i
n
g
pr
e
p
a
r
e
d
fo
r
BL
M
re
v
i
e
w
,
EP
M
:
TE
S
W
L
-
1
3
Y
ex
p
e
c
t
e
d
mi
d
-
M
a
r
c
h
.
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Mi
g
r
a
t
o
r
y
Bi
r
d
s
Su
m
m
e
r
20
1
8
20
1
8
su
r
v
e
y
pl
a
n
to
be
su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
EP
M
:
WI
L
D
-
9
Y
en
d
of
Ja
n
u
a
r
y
30
,
20
1
8
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Mo
u
n
t
a
i
n
Pl
o
v
e
r
Su
m
m
e
r
20
1
8
20
1
8
su
r
v
e
y
pl
a
n
to
be
su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
FE
I
S
3.
1
1
-
1
6
,
3.
1
1
-
4
7
Y
en
d
of
Ja
n
u
a
r
y
30
,
20
1
8
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Py
g
m
y
Ra
b
b
i
t
Wi
n
t
e
r
20
1
7
an
d
BL
M
ap
p
r
o
v
e
d
su
r
v
e
y
Su
m
m
e
r
20
1
8
pl
a
n
.
S
u
r
v
e
y
s
cu
r
r
e
n
t
l
y
be
i
n
g
FE
I
S
3.
1
1
-
1
6
,
3.
1
1
-
4
8
Y
co
n
d
u
c
t
e
d
.
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Ot
h
e
r
Ra
p
t
o
r
Sp
e
c
i
e
s
Su
m
m
e
r
20
1
8
20
1
8
su
r
v
e
y
pl
a
n
to
be
su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
EP
M
:
WI
L
D
-
4
&
8
Y
en
d
of
Ja
n
u
a
r
y
30
,
20
1
8
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
6
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
9
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
/
N
)
Wh
i
t
e
-
t
a
i
l
e
d
Pr
a
i
r
i
e
Su
m
m
e
r
20
1
8
20
1
8
su
r
v
e
y
pl
a
n
to
be
Do
g
su
b
m
i
t
t
e
d
fo
r
BL
M
re
v
i
e
w
FE
I
S
3.
1
1
-
1
7
,
3.
1
1
-
4
9
Y
en
d
of
Ja
n
u
a
r
y
30
,
20
1
8
EP
M
:
TE
S
W
L
-
3
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Wy
o
m
i
n
g
Po
c
k
e
t
Sp
r
i
n
g
20
1
7
Su
r
v
e
y
s
fo
r
su
i
t
a
b
l
e
ha
b
i
t
a
t
in
Go
p
h
e
r
20
1
7
ar
e
co
m
p
l
e
t
e
.
Dr
a
f
t
NT
P
le
t
t
e
r
be
i
n
g
pr
e
p
a
r
e
d
fo
r
BL
M
FE
I
S
3.
1
1
-
1
7
,
3.
1
1
-
5
0
Y
re
v
i
e
w
,
ex
p
e
c
t
e
d
mi
d
-
M
a
r
c
h
.
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Bl
o
w
o
u
t
Pe
n
s
t
e
m
o
n
No
su
i
t
a
b
l
e
ha
b
i
t
a
t
in
Ju
n
e
En
d
a
n
g
e
r
e
d
sp
e
c
i
e
s
in
EP
M
:
TE
S
P
L
-
1
Y
pr
o
j
e
c
t
ar
e
a
pe
r
BA
.
Wy
o
m
i
n
g
on
l
y
.
FW
S
co
n
c
u
r
in
BO
.
No
Su
r
v
e
y
re
q
u
i
r
e
d
NT
P
is
s
u
e
d
8/
2
7
/
1
5
Co
l
o
r
a
d
o
Bu
t
t
e
r
f
l
y
No
su
i
t
a
b
l
e
ha
b
i
t
a
t
in
Ju
l
y
--
Se
p
t
e
m
b
e
r
Th
r
e
a
t
e
n
e
d
sp
e
c
i
e
s
in
Pl
a
n
t
pr
o
j
e
c
t
ar
e
a
pe
r
BA
.
Wy
o
m
i
n
g
on
l
y
.
EP
M
:
TE
S
P
L
-
2
Y
FW
S
co
n
c
u
r
in
BO
.
No
Su
r
v
e
y
re
q
u
i
r
e
d
NT
P
is
s
u
e
d
8/
2
7
/
1
5
Ra
r
e
Pl
a
n
t
Su
r
v
e
y
EP
M
:
TE
S
P
L
-
3
Y
Su
m
m
e
r
20
1
8
Ma
p
p
i
n
g
up
d
a
t
e
d
wi
t
h
an
n
u
a
l
su
r
v
e
y
s
Ut
e
La
d
i
e
s
'
-
t
r
e
s
s
e
s
Su
r
v
e
y
co
m
p
l
e
t
e
d
Au
g
u
s
t
No
ad
d
i
t
i
o
n
a
l
su
r
v
e
y
re
q
u
i
r
e
d
th
r
o
u
g
h
20
1
4
.
No
pl
a
n
t
s
pe
r
em
a
i
l
fr
o
m
FW
S
on
EP
M
:
TE
S
P
L
-
7
Y
fo
u
n
d
.
7/
0
1
/
1
5
.
BL
M
ac
c
e
p
t
e
d
su
r
v
e
y
6/
1
0
/
1
4
an
d
2/
2
3
/
1
5
.
7
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
10
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
l
N
)
Wy
o
m
i
n
g
Sa
g
e
-
HE
A
ba
s
e
l
i
n
e
un
d
e
r
-B
a
s
e
l
i
n
e
mo
d
e
l
gr
o
u
s
e
Mi
t
i
g
a
t
i
o
n
re
v
i
e
w
by
BL
M
ap
p
r
o
v
e
d
by
Ov
e
r
s
i
g
h
t
Pl
a
n
Co
m
m
i
t
t
e
e
(O
C
)
-H
E
A
im
p
a
c
t
s
be
i
n
g
mo
d
e
l
e
d
(c
u
r
r
e
n
t
l
y
)
-F
i
n
a
l
i
z
e
HE
A
en
d
of
Ql
/
b
e
g
i
n
n
i
n
g
Q2
20
1
8
-P
a
c
i
f
i
C
o
r
p
id
e
n
t
i
f
y
po
t
e
n
t
i
a
l
mi
t
i
g
a
t
i
o
n
RO
W
Gr
a
n
t
-
St
i
p
u
l
a
t
i
o
n
1d
Y
pr
o
j
e
c
t
s
/
op
p
o
r
t
u
n
i
t
i
e
s
/
d
e
b
i
t
s
&
cr
e
d
i
t
s
Q2
20
1
8
-D
r
a
f
t
im
p
a
c
t
s
re
s
u
l
t
s
an
d
mi
t
i
g
a
t
i
o
n
pl
a
n
re
v
i
e
w
by
OC
-
mi
d
-
Ma
y
20
1
8
-
Fi
n
a
l
mi
t
i
g
a
t
i
o
n
pl
a
n
ap
p
r
o
v
a
l
Ju
l
y
20
1
8
-
NT
P
Q3
20
1
8
Mi
g
r
a
t
o
r
y
Bi
r
d
NT
P
is
s
u
e
d
wh
e
n
fu
n
d
Ch
r
i
s
Ke
e
f
e
(B
L
M
)
to
RO
W
Gr
a
n
t
-
Ha
b
i
t
a
t
Y
ad
m
i
n
i
s
t
r
a
t
i
o
n
fi
n
a
l
i
z
e
d
co
o
r
d
i
n
a
t
e
wi
t
h
Wy
G
F
re
:
Co
n
s
e
r
v
a
t
i
o
n
Pl
a
n
St
i
p
u
l
a
t
i
o
n
le
an
d
fu
n
d
i
n
g
pr
o
v
i
d
e
d
.
fu
n
d
ad
m
i
n
i
s
t
r
a
t
i
o
n
.
8
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
11
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
/
N
)
Cl
a
s
s
II
I
In
v
e
n
t
o
r
y
2n
d
Am
e
n
d
e
d
PA
Re
p
o
r
t
si
g
n
a
t
u
r
e
pa
g
e
s
in
BL
M
BL
M
re
v
i
e
w
co
m
p
l
e
t
e
,
re
v
i
e
w
co
m
m
e
n
t
s
be
i
n
g
ad
d
r
e
s
s
e
d
,
BL
M
fi
n
a
l
re
v
i
e
w
la
t
e
Fi
n
a
l
Cl
a
s
s
II
I
Re
p
o
r
t
on
Ma
r
c
h
/
e
a
r
l
y
Ap
r
i
l
,
PA
pa
r
t
i
e
s
Na
t
i
o
n
a
l
Hi
s
t
o
r
i
c
N
tr
a
c
k
fo
r
su
b
m
i
t
t
a
l
to
re
v
i
e
w
ea
r
l
y
to
la
t
e
Ap
r
i
l
.
Pr
e
s
e
r
v
a
t
i
o
n
Ac
t
BL
M
on
12
/
1
5
/
2
0
1
7
(s
e
e
be
l
o
w
)
Tr
i
b
a
l
co
n
s
u
l
t
a
t
i
o
n
pe
n
d
i
n
g
Cl
a
s
s
3
su
b
m
i
t
t
a
l
Ra
w
l
i
n
s
FO
-
Cl
a
s
â
N
On
tr
a
c
k
fo
r
de
l
i
v
e
r
y
BL
M
II
I
Re
p
o
r
t
De
c
e
m
b
e
r
20
1
7
co
m
m
e
n
t
s
be
i
n
g
ad
d
r
e
s
s
Ro
c
k
Sp
r
i
n
g
s
FO
¯
N
On
tr
a
c
k
fo
r
de
l
i
v
e
r
y
BL
M
Cl
a
s
s
II
I
Re
p
o
r
t
De
c
e
m
b
e
r
20
1
7
co
m
m
e
n
t
s
be
i
n
g
ad
d
r
e
s
s
Um
b
r
e
l
l
a
Hi
s
t
o
r
i
c
Um
b
r
e
l
l
a
HP
T
P
in
BL
M
co
o
r
d
i
n
a
t
i
n
g
Co
m
p
l
e
t
e
RO
W
Gr
a
n
t
-
Pr
o
p
e
r
t
i
e
s
SH
P
O
Re
v
i
e
w
ha
n
d
l
i
n
g
of
NA
G
P
R
A
,
St
i
p
u
l
a
t
i
o
n
1f
Tr
e
a
t
m
e
n
t
Pl
a
n
Y
et
c
.
wi
t
h
WY
SH
P
O
fo
r
PO
D
Ap
p
e
n
d
i
x
S,
fi
n
a
l
i
z
a
t
i
o
n
At
t
a
c
h
.
S-
2
Se
g
m
e
n
t
HP
T
P
-
Wi
l
l
be
de
v
e
l
o
p
e
d
af
t
e
r
Ma
y
20
1
8
Pe
n
d
i
n
g
Cl
a
s
s
3
re
p
o
r
t
Sh
i
r
l
e
y
Ba
s
i
n
-
RO
W
Gr
a
n
t
¯
Y
ap
p
r
o
v
a
l
of
Cla
s
s
II
I
re
v
i
e
w
/
a
p
p
r
o
v
a
l
Ae
o
l
u
s
-
Ji
m
St
i
p
u
l
a
t
i
o
n
Ig
re
p
o
r
t
fo
r
th
i
s
se
g
m
e
n
t
.
Br
i
d
g
e
r
Pl
a
t
t
e
Ri
v
e
r
Wa
t
e
r
ne
e
d
s
de
t
e
r
m
i
n
e
d
Re
v
i
e
w
of
wa
t
e
r
us
e
Le
t
t
e
r
be
i
n
g
pr
e
p
a
r
e
d
Re
c
o
v
e
r
y
Ag
r
e
e
m
e
n
t
by
co
n
s
t
r
u
c
t
i
o
n
co
n
t
r
a
c
t
o
r
pr
o
p
o
s
e
d
by
th
e
co
n
f
i
r
m
i
n
g
on
l
y
mu
n
i
c
i
p
a
l
co
n
t
r
a
c
t
o
r
(F
a
l
l
20
1
8
so
u
r
c
e
s
wi
l
l
be
us
e
d
RO
W
Gr
a
n
t
-
LN
T
P
)
.
No
t
to
ex
c
e
e
d
Y
St
i
p
u
l
a
t
i
o
n
1h
(9
6
ac
r
e
-
f
e
e
t
/
y
e
a
r
:
3
1
.
3
Pa
y
m
e
n
t
ma
d
e
to
FW
S
on
M
ga
l
l
o
n
s
)
am
o
u
n
t
of
wa
t
e
r
wi
t
h
d
r
a
w
n
fr
o
m
ba
s
i
n
.
NT
P
is
s
u
e
d
wh
e
n
FW
S
co
n
f
i
r
m
s
pa
y
m
e
n
t
9
Mo
n
s
a
n
t
o
Ex
h
i
b
i
t
No
.
21
2
Ca
s
e
No
.
PA
C
-
E
-
1
7
-
0
7
Pa
g
e
12
of
12
No
t
i
c
e
to
IT
E
M
Re
f
e
r
e
n
c
e
Pr
o
c
e
e
d
St
a
t
u
s
Ti
m
i
n
g
Re
m
a
r
k
s
/
C
o
m
m
e
n
t
s
(Y
/
N
)
re
c
e
i
v
e
d
.
No
ne
w
ne
t
de
p
l
e
t
i
o
n
le
t
t
e
r
re
c
e
i
v
e
d
fr
o
m
St
a
t
e
En
g
i
n
e
e
r
4/
1
8
/
2
0
1
3
Up
p
e
r
Co
l
o
r
a
d
o
Wa
t
e
r
ne
e
d
s
de
t
e
r
m
i
n
e
d
De
t
e
r
m
i
n
e
ne
e
d
e
d
Pr
o
p
o
n
e
n
t
s
in
t
e
n
d
to
ob
t
a
i
n
Ri
v
e
r
En
d
a
n
g
e
r
e
d
by
co
n
s
t
r
u
c
t
i
o
n
co
n
t
r
a
c
t
o
r
ac
t
i
o
n
wh
e
n
wa
t
e
r
wa
t
e
r
fr
o
m
so
u
r
c
e
s
wi
t
h
Fi
s
h
Re
c
o
v
e
r
y
.
so
u
r
c
e
an
d
am
o
u
n
t
ex
i
s
t
i
n
g
co
n
s
u
l
t
a
t
i
o
n
.
If
En
d
a
n
g
e
r
e
d
Sp
e
c
i
e
s
.
Pr
o
g
r
a
m
N
kn
o
w
n
.
ob
t
a
i
n
e
d
fr
o
m
no
n
-
Ac
t
Fa
l
l
20
1
8
af
t
e
r
LN
T
P
co
n
s
u
l
t
a
t
i
o
n
so
u
r
c
e
s
,
co
n
s
u
l
t
a
t
i
o
n
an
d
a
pa
y
m
e
n
t
to
FW
S
is
re
q
u
i
r
e
d
Co
n
s
t
r
u
c
t
i
o
n
/
BL
M
re
q
u
e
s
t
s
bo
n
d
Bo
n
d
am
o
u
n
t
de
t
e
r
m
i
n
e
d
Re
c
l
a
m
a
t
i
o
n
Bo
n
d
NL
T
6
mo
n
t
h
s
pr
i
o
r
to
ba
s
e
d
on
th
e
Fi
n
a
l
Pl
a
n
s
of
RO
W
Gr
a
n
t
-
.
co
n
s
t
r
u
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Monsanto Exhibit No.213
Case No.PAC-E-17-07
Page 1 of 20
Aeolus West Transmission Path
Transfer Capability Assessment
Updated Study Report
Revision 2.1
March 30,2018
Prepared by
PacifiCorp -Transmission Planning
Monsanto Exhibit No.213
Case No.PAC-E-17-07
Page 2 of 20
Updated
Aeolus West Transmission Path
Transfer CapabilityAssessment
Table of Contents
Executive Summary..........................................................l
l Introduction ......................................................4
1.1 Purpose...........................................................................4
1.2 Plan of Service .......................................................4
1.3 Planned Operating Date ............................................................5
1.4 Scope ............................................................5
2 Study Criteria..............................................................5
2.1 Thermal Loading ..........................................................5
2.2 Steady State Voltage Range...........................................................6
2.3 Post-Transient Voltage Deviation...........................................................7
2.4 Dynamic StabilityAnalysis Criteria ........................................................7
2.5 Dynamic Voltage Response ...........................................................7
3 Base Case Development ...........-.................................................8
3.1 Base Case Selection .............................................................8
3.2 Generating Facility Additions .......................................................10
3.3 Base Case Modification and Tuning.........................................................11
4 Path Studies ...........................................................12
4.1 Aeolus West vs.TOT 4B ...........................................................12
4.2 Base Case Development.....................................................15
4.3 Dynamic StabilityAnalysis............................................................16
5 Sensitivity Analysis ...................................................................16
6 Study Conclusions......................................................................17
AppendixA -Path Definitions...............................................................18
AppendixB -Power Flow Plots............................................................18
AppendixC -Dynamic Stability Results (Case C7)........................................................18
Monsanto Exhibit No.213
Case No.PAC-E-17-07
Page 3 of 20
Updated
Aeolus West Transmission Path
Transfer Cgpgbility Assessment
Executive Summary
This assessment was conducted to document the Transfer Capability of the Aeolus Westi
transmission path once the Gateway West -Subsegment D.22 (Bridger/Anticline -Aeolus)
transmission facilities (D.2 Project)are added to the Wyoming transmission system and
assumed resources identified in the PacifiCorp 2017R RFP3 Shortlist were added.
The Aeolus West transmission path (see Figure 1)is a new path that will be formed by adding
the D.2 Project in parallel with the TOT 4A4 (Path 37)transmission path facilities.The
anticipated in-service date for the D.2 Project is October 31,2020.The D.2 Project is part of
PacifiCorp's Energy Vision 2020 (EV2020)initiative which includes the following major
transmission facilities and network upgrades
to support new wind generationresources:Figure 1:Aeolus West Transmission Path
Aeolus 500/230 kV substation,
Shirley Basin -Freezeout 230 kV line Aeolus Westloop-in to Aeolus,
Anticline 500/345 kV substation,
Aeolus -Anticline 500 kV new line,
Bridger -Anticline 345 kV new line,
Shirley Basin -Aeolus 230 kV #1 line
rebuild,
Shirley Basin -Aeolus 230 kV #2 new Q -Q
line,
I The Aeolus West transmission path will include the following major transmission elements:Aeolus*-Anticline
500 kV,Platte*-Latham 230 kV,Mustang*-Bridger 230 kV and Riverton*-Wyopo 230 kV transmission
lines.(*meter location)
2 Gateway West -Subsegment D.2 is a key component of the Energy Vision 2020 (EV2020)initiative that was
announced by PacifiCorp on April 4,2017.Other components of the EV2020 initiative include repowering
PacifiCorp's existing wind fleet in southeast Wyoming and adding approximately 1,100 MW of new wind
generation east of the Aeolus West transmission path.[Subsequent to the initial announcement,technical studies
have demonstrated that as high as 1,510 MW can be integrated east ofthe Aeolus West transmission path.]
3 The PacifiCorp 2017R Request for Proposals for renewable resources (2017R RFP)solicited cost-competitive
bids for up to 1,270 MW of new or repowered wind energy interconnecting with or delivering to PacifiCorp's
Wyoming system with the use of third-party firm transmission service and any additional wind energy located
outside of Wyoming capable of delivering energy to PacifiCorp's transmission system that will reduce system
costs and provide net benefits for customers.
4 The existing TOT 4A (Path 37)transmission path is comprised of the Riverton*-Wyopo 230 kV,Platte -
Standpipe*230 kV and Spence*-Mustang 230 kV transmission lines.(*meter location)
1
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Case No.PAC-E-17-07
Page 4 of 20
Updated
Aeolus West Transmission Path
Transfer Capability Assessment
Aeolus -Freezeout230 kV line reconductor,
Freezeout-Standpipe 230 kV line reconductor,
Latham dynamic voltage control device,
Separate the double-circuit portion of the Ben Lomond -Naughton 230 kV #1 and Ben
Lomond -Birch Creek 230 kV #2 lines to create two single-circuit lines,
Railroad -Croydon 138 kV partial line reconductor,
Aeolus 230 kV shunt reactor,
Shirley Basin 230 kV shunt reactor,
The WECC 2021-22 HW power flow base case was utilized for the Aeolus West transfer
capability assessment studies.In support of the EV2020 initiative,which calls for the addition
of new and repowered wind resources in Wyoming,the base case was modified to achievethe
transfer levels evaluated by utilizing PacifiCorp 2017R RFP Shortlist resources as evaluated
in the Large Generation Interconnection (LGI)queue,which added 1510 MW east of the
Aeolus West "cut plane"and 221 MW in southwest Wyoming.For different Aeolus West
transfer levels (heavy and light)and 2400 MW flow across the Jim Bridger West path,resource
levels in eastern Wyoming were varied relative to the Jim Bridger Generation in central
Wyoming and the Emery/Hunter and Huntington generation in central Utah.
Contingencies that were considered in this analysis include:
N-1 of D.2 Project facilities
N-1,N-2 Bridger contingencies
All eastern,central and northern Wyoming transmission system contingencies
performed as part of the TPL-001-4 annual assessment.
For this transfer capability assessment,simultaneousinteraction betweenthe Aeolus West path
and the TOT 4B path was evaluated;however,the interactions with other transmission paths
(Yellowtail South,Jim Bridger West,TOT lA and TOT 3)were monitored throughout the
study.Subsequenttransfer capability assessments will evaluate interaction with TOT 3 (Path
36),Bonanza West (Path 33)and TOT 1A (Path 30)transmission paths.(See AppendixA.)
In this revision of the report,the power flow analysis was re-evaluated to identify maximum
transfer capability by stressing both the Aeolus West and the TOT 4B paths simultaneously.If
required,additional power from Western Area Power Administration (WAPA)was imported
into the PacifiCorp East (PACE)balancing authority area.
2
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Case No.PAC-E-17-07
Page 5 of 20
Updated
Aeolus West Transmission Path
Transfer Capability Assessment
Conclusions
Technical studies have demonstrated that the interconnected Bulk Electric System (BES)in
Wyoming with the D.2 Project added can support the PacifiCorp 2017R RFP Shortlist
resources,and that system performance will meet all North American Electric Reliability
Corporation (NERC)and Western Electricity Coordinating Council (WECC)performance
criteria.
Preliminary power flow studies demonstrate that by utilizing existing and planned southeast
Wyoming resourcess,the Aeolus West transmission path can transfer up to 1829 MW under
simultaneous transfer conditions with the TOT 4B transmission path,effectively6 inCTORSing
the east to west transfer levels across Wyoming by 951 MW.Power flow findings also
indicated:
Dynamic voltage control is necessary at the Latham 230 kV substation to mitigate low
voltage conditions resulting from loss of Bridger/Anticline -Aeolus transmission
facilities.
Under certain operating conditions,one Remedial Action Scheme (RAS)will need to
be implemented to trip generation following outage of specific transmission facilities
in southeast Wyoming.
The location (and output level)of new and repowered wind resources can influence the
transfer capability level across the Aeolus West transmission path and the Aeolus West
vs.TOT 4B nomogram curve.
Dynamic stability studies evaluated a wide range of critical system disturbances in eastern
Wyoming.The analyses identified two outages with poor voltage performance,and another
outage identifieda wind turbine modeling problem.These issues are all attributed to the wind
turbine models at the Q0706,Q0707 and Q0708 projects.PacifiCorp is workingwith the wind
turbine manufacture to resolve these issues.Aside from these issues,the studied outages
evaluated meet the dynamic performance criteria with the system being stable and damped.
Eastern Wyoming Resources:Existing Wind:1124 MW,Dave Johnston (net)717 MW;Wyodak (PacifiCorp -
net)268 MW,New Wind -behind the Aeolus West "cut plane":1510 MW;east Wyoming:1270 MW,north
Wyoming:240 MW.
6 Effective transfers were determined by subtracting the existing TOT 4A path maximum"transfer level (960
MW)from the Aeolus West transfer level (1829 MW)and adding the Platte area loads (82 MW)that are up-
stream of the Aeolus West metering point.
3
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Case No.PAC-E-17-07
Page 6 of 20
Updated
Aeolus West Transmission Path
Transfer Capability Assessment
1 Introduction
1.1 Purpose
The purpose of the study is to demonstratethat the interconnected transmission Bulk Electric
System (BES)in Wyoming with the D.2 Project addedcan support the PacifiCorp 2017R RFP
Shortlist resources and can be operated reliably during normal and contingency operations
throughout the planning horizon.To achieve this purpose,the study will:(1)identify the new
Aeolus West transmission path limitations,(2)evaluate the interactions between the Aeolus
West and the TOT 4B transmission paths and develop a nomogram that depicts system
limitations,and (3)identify any necessary Remedial Action Schemes (RAS).
This report will summarize the results of the power flow and dynamic stability analysis of the
Aeolus West transmission path and will demonstrate that Wyoming transmission system
performance with the D.2 project added meets all NERC and WECC performance criteria.
1.2 Plan of Service
The D.2 Project,and supporting network upgrades consists of the following system
improvements:
1.Add Aeolus 500/230 kV substation
2.Add Aeolus 500/230 kV,1600 MVA transformer
3.Loop the Shirley Basin -Freezeout230 kV line into Aeolus,
4.Add Anticline 500/345 kV substation
5.Add Anticline 500/345 kV,1600 MVA transformer
6.Add the Aeolus -Anticline 500 kV transmission line,137.8-miles,3x1272 ACSR
(Bittern)conductor
7.Add the Anticline -Bridger 345 kV line,5.1-miles,3x1272 ACSR (Bittern)conductor
8.Add the Aeolus 230 kV,60 MVAr shunt reactor
9.Add the Shirley Basin 230 kV,60 MVAr shunt reactor
10.Add Aeolus 500 kV,200 MVAr shunt capacitor
11.Add Anticline 500 kV,200 MVAr shunt capacitor
12.Rebuilding of the Aeolus -Shirley Basin 230 kV #1 line,2xl557 ACSS/TW
(Hudson/TW)conductor
13.Add the Aeolus -Shirley Basin 230 kV #2 line,2xl557 ACSS/TW (Hudson/TW)
conductor
14.Reconductor the Aeolus -Freezeout230 kV line,2xl272 ACSR (Bittern)conductor
4
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Case No.PAC-E-17-07
Page 7 of 20
Updgted
Aeolus West Transmission Path
Transfer Capability Assessment
15.Reconductor the Freezeout-Standpipe230 kV line,2xl272 ACSR (Bittern)conductor
16.Add dynamic reactive device at Latham 230 kV substation.
17.Separate eight miles of the double-circuit Ben Lomond -Naughton 230 kV #1 and Ben
Lomond -Birch Creek 230 kV #2 lines to create two single-circuit lines,and
18.Reconductor 2.35 miles of the Railroad -Croydon 138 kV line,1222 ACCC high
temperature conductor,
1.3 Planned Operating Date
The in-service date for all facilities associated with the D.2 Project is October 31,2020.
1.4 Scope
The Aeolus West transfer capability assessment assumes the addition of new wind generation
facilities as noted in Table 1,which includes the PacifiCorp 2017R RFP Shortlist resources as
evaluated in LGI queue studies.While the new technology and model information of the
repowered units was used in the steady-state and dynamic stability analysis,no incremental
MW output was considered;i.e.,each repowered facility was limited to its current LGI
agreementgenerationcapacity levels.The study was performed using a 2021-22 heavy winter
WECC approved case which was modified to include the D.2 Project facilities.The system
model assumed summer line ratings to assess the thermal limitation of the Wyoming system.
Load served from Platte is normally representedas an open point between Platte -Whiskey
Peak 115 kV.The system configuration with Platte 115 kV normally open is presently the most
limiting scenario for the existing TOT 4A/4B nomogram.
2 Study Criteria
2.1 Thermal Loading
For system normal conditions describedby the POT event,thermal loading on BES transmission
lines and transformers is required to be within continuous ratings.
For contingency conditions describedby P1-P7 category planning events,thermal loading on
transmission lines and transformers should remain within 30-minute emergencyratings.
7 Facility outage events that are identified with "P"designations are referenced to the TPL-001-4 NERC standard.
5
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Case No.PAC-E-17-07
Page 8 of 20
Updated
Aeolus West Transmission Path
Transfer Cgpability Assessment
The thermal ratings of PacifiCorp's BES transmission lines and transformers are based on the
most recent PacifiCorp's Weak Link Transmission Database and Weak Link Transformer
Database.
Table 1:Generating ResourcesStudied
Existing Wyoming Thermal Existing East New Wyoming Wind
Generation Wyoming Wind Generation
Generation
2396 MW 1124 MW 1731 MW
Dave Johnston(DJ):717 MW (Foote Creek,Rock Eastern Wyoming (Aeolus,
Wyodak (PacifiCorp):268 River,High Plains,Shirley Basin,Windstar):
MW Seven Mile Hill,1270 MW
Jim Bridger (PacifiCorp):Dunlap,Root Creek,Northern Wyoming
141l MW Top of the World,(Bighorn Basin):240 MW
Glenrock,Three SouthwestWyoming (Uinta
Buttes,Chevron)County):221 MW
See Table 4.
2.2 Steady State Voltage Range
The steady state voltage ranges at all PacifiCorp BES buses shall be within acceptable limits
as established in PacifiCorp's Engineering Handbook section 1B.3 "Planning Standards for
Transmission Voltage""as shown below.
Table 2:Voltage Criteria
ContingencyConditionsOperatingSystemNormalConditions(PO)(P1-P7)Configuration Vmin (pu)Vmax (pu)Vmin (pu)Vmax (pu)
Looped 0.95 1.06 0.90 1.10
Radial 0.90 1.06 0.85 1.10
PacifiCorp Engineering Handbook "Planning Standards for Transmission Voltage,"April 8,2013.
*In some situations,voltages may go as high as 1.08 pu at non-load buses,contingent upon equipment rating
review.
6
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Case No.PAC-E-17-07
Page 9 of 20
Updated
Aeolus West Transmission Path
Transfer CapabilityAssessment
Steady state voltage ranges at all applicable BES buses on adjacent systems were screened
based on the limits establishedby WECC regional criterion as follows:
95%to 105%of nominal for PO event (system normal),
90%to l 10%of nominal for Pl -P7 events (contingency).
2.3 Post-Transient VoltageDeviation
Post-contingency steady state voltage deviation at each applicable BES load serving bus
(having no intermediate connection)shall not exceed 8%for Pl events.
2.4 Dynamic Stability Analysis Criteria
All voltages,frequencies and relative rotor angles are required to be stable and damped.
Cascading or uncontrolled separation shall not occur and dynamic voltage response shall be
within established limits.
2.5 Dynamic Voltage Response
Dynamic stabilityvoltage response criteria are based on WECC Regional Performance Criteria
WRl.3 through WRl.5 as follows:
Dynamic stability voltage response at the applicable BES buses serving load (having
no intermediate connection)shall recover to at least 80%of pre-contingency voltage
within 20 seconds of the initiating event for all Pl-P7 category events,for each
applicable bus serving load.
For voltage swings following fault clearing and voltage recovery above 80%,voltage
dips at each applicable BES bus serving load (having no intermediate buses)shall not
dip below 70%of pre-contingency voltage for more than 30 cycles or remain below
80%of pre-contingency voltage for more than two seconds for all Pl-P7 category
events.
For contingencies without a fault (P2-1 category event),voltage dips at each applicable
BES bus serving load (having no intermediate buses)shall not dip below 70%of pre-
contingency voltage for more than 30 cycles or remain below 80%of pre-contingency
voltage for more than two seconds.
The following criteria were used to investigate the potential for cascading and uncontrolled
islanding:
7
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Case No.PAC-E-17-07
Page 10 of 20
Updated
Aeolus West Transmission Path
Transfer Capability Assessment
Load interruption due to successive line tripping for thermal violations shall be
confined to the immediate impacted areas and shall not propagateto other areas.The
highest available emergencyrating is used to determine the tripping threshold for lines
or transformers when evaluating a scenario that may lead to cascading.
Voltage deficiencies caused by either the initiating event or successive line tripping
shall be confined to the immediate impacted areas,and shall not propagate to other
areas.
Positive damping in stability analysis is demonstratedby showing that the amplitude of power
angle or voltage magnitude oscillations after a minimum of 10 seconds is less than the initial
post-contingency amplitude.Oscillations that do not show positive damping within a 30-
second time frame shall be deemed unacceptable.
Stability studies shall be performed for planning events to determine whether the BES meets
the performance requirements.
Single contingencies (P1 category events):No generating unit shall pull out of
synchronism (excludes generatorsbeing disconnectedfrom the system by fault clearing
action or by a special protection system).
Multiple contingencies (P2-P7 category events):When a generator pulls out of
synchronism in the simulations,the resulting apparent impedance swings shall not
result in the trippingof any transmission system elements other than the generating unit
and its directly connected facilities.
Power oscillations are evaluated by exhibiting acceptable damping.The absence of
positive damping within a 30-secondtime frame is considered un-damped.
3 Base Case Development
3.1 Base Case Selection
The base case development process involves selecting an approvedWECC base case,updating
the models to representplannedtransmission facilities (D.2 Project)and existing and new wind
generation (see Table 1)facilities,and then tuning the cases to maximum transfer levels on the
WECC transmission path(s)being studied.For this study,the WECC approvedbase case 2021-
22 HW (created on August 19,2016)was selected.This case meets key criteria in that it is
close to the Projects'in-service date of October 31,2020,includes average load conditions
based on 2021 load projections and has an accompanying dynamic stability base case available.
This study focused on simultaneous transmission path interaction in the Wyoming area
8
i
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Case No.PAC-E-17-07
Page 11 of 20
Updgted
Aeolus West Transmission Pgth
Transfer Capability Assessment
between the Aeolus West and the TOT 4B transmission paths;however,other transmission
paths such as Yellowtail South (non-WECC path),Jim Bridger West,TOT lA and TOT 3 (See
AppendixA for path definitions)were monitored throughout the study.
The various critical components for this study purpose selected from the 2021-22 HW base
case are listed below:
Table 3:Wyoming Load,Generation and Platte Normal Open Configuration in Base Case
Load or Generation Amount (MW)
North Wyoming PAC Load (including Wyodak load 391 MWof42MW)
North Wyoming -WAPA Load 211 MW
Eastern Wyoming PAC Load (including DJ load of 56 474 MWMW)
Eastern Wyoming PAC Loads on WAPA System 95 MW
Central Wyoming Load (including JB load of 130 434 MWMW)
Yellowtail South Flow 192 MW
Yellowtail Generation 140/260 MW (Online/Max)
WAPA's Existing Small Generationl°in North
.26/50 MW(Online/Max)Wyommg
WAPA's Existing Small Generation"in Eastern
.484/584 MW(Online/Max)Wyommg
Wyodak Generation (PacifiCorp/Black Hills)350/380 MW (Online/Max)
Dry Fork Generation (Basin Electric)420/440 MW (Online/Max)
Gross Laramie River Generation I (WAPA's swing
.605 MW(Max)machme)
i
10 WAPA's small generation in north Wyoming includes;Boysen,Buffalo Bill,Heart Mountain,Shoshone,
Spring Mountain
"WAPA's small generation in eastern Wyoming includes;Alcova,Fremont,Glendo,Guernsy,Kortes,Seminoe,
CLR_l,SS_Genl AND CPGSTN
9
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Case No.PAC-E-17-07
Page 12 of 20
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Aeolus West Transmission Path
Transfer CapabilityAssessment
Load or Generation Amount (MW)
Gross Laramie River Generation II 590/605 MW(Online/Max)
Gross Dave Johnston(DJ)Generation 700/774 MW(Online/Max)
Total Existing PAC East Wyoming Windl2 Generation 885.7/1124 MW (Online/Max)
Rapid City DC W Tie 130 w2e (200 MW-bidirectional)
Stegall DC Tie 100 e2w (110 MW-bidirectional)
Sydney DC Tie 196 e2w (200 MW-bidirectional)
TOT 4A Flow 627 MW
TOT 4B Flow 469 MW
Jim Bridger (JB)Generation 2200 MW
Jim Bridger West Flow 2027 MW
TOT 3 Flow 1259.1 MW
TOT 1A Flow 195 MW
Platte -Mustang 115 kV Normal Open Point Platte -Normal Open
3.2 Generating Facility Additions
The transmission path assessment studies outlined in Section 4 were performed by utilizing
the resources identifiedin Table 4 to evaluatethe performance of the Aeolus West transmission
path.Transmission and generationprojects with an in-service date beyond 2020 were excluded
from the analysis.While Table 4 provides the general location of the resources included in the
study,Figure 2 provides an overview of PacifiCorp's Wyoming transmission system and
provides a visual illustration of the location of each of the existing and new generation (noted
in red)resources,and identifies the location of the Aeolus West and TOT 4B transmission path
constraints.
12 PAC eastern Wyoming wind generation includes;Root Creek,Three Buttes,Top of The World,Glenrock,
Rolling Hills,Dunlap.Seven Mile Hill,Foote Creek and High Plains wind generation
10
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Transfer Capability Assessment
Table 4:New Wyoming Wind Resources
LGIProposedNew ProjectQueue Point of InterconnectionWindFacilitiesSizeNumber
Northern Wyoming Q542 240 MW Frannie -Yellowtail 230 kV line(Bighorn Basm)
Q706 250 MW Aeolus 230 kVEasternWyoming
(Aeolus/Shirley Q707 250 MW Shirley Basin 230 kV
Basin/Windstar Q708 250 MW Shirley Basin 230 kV
Area)Q712 520 MW Windstar 230 kV
Canyon Compression -Railroad 138 kVQ715120MW.Southwest Wyoming lme
Canyon Compression -Railroad 138 kV(Uinta County)Q810 101 MW line
TOTAL 1731 MW
3.3 Base Case Modification and Tuning
The 2021-22HW base case was modified to reflect the most recent Foote Creek,High Plains,
Top of the World and Three Buttes wind generation modeling as per the recent MOD-032 data
submitted by each generator owner (GO).Transmission line impedances between Dave
Johnston and Standpipe were verified and updated and the transmission line ratings in the
2021-22 heavy winter case were modified to summer ratings,which represent the most
conservative thermal limitations.The Platte -Standpipe 230 kV dynamic line rating of
608/666/680 MVA was assumed during the analysis.
The generation resources listed in Table 4 were added to the base case and the existing
repowered wind farm generator models and collector system data were updated.The Aeolus
West path was stressed by maximizing the output on all of the existing and new wind
generation facilities.Output for the repowered wind generation facilities was limited to the
existing LGI agreement generation capacity levels.The additional generation in southeast
Wyoming was displaced with Jim Bridger,central and southern Utah generation.The Jim
Bridger generation output was maintained such that Jim Bridger West path flows were
maintained near 2400 MW.
As per the available data obtained for the various wind generation facilities at the time of this
study analysis,the base cases were reviewed and adjusted to ensure voltages in the collector
system of wind generation facilities were below 1.05 p.u.and that there was no reactive power
11
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Transfer Capability Assessment
GSU loop flow conditions for wind generation facilities that have multiple main generator
step-up GSU transformers.
Figure 2
Existing/Proposed Wyoming Generation Resources,and Transmission Constraints
PacifiCorp
Aeolus West/TOT 4B Wyoming
Transmission Constraints
NaughartLoad casos e 200 2 Mw
East Wyoming
Wyoming
koad og AEOLUSWESTITOT48 Umn:
1 ....See ---.......----..SimuneneousNomogram
This process involved tuning transformer and generator parameterssuch that generators were
producing appropriate reactive power output.Additionally,within the 230 kV transmission
system it was verified that the shunt reactive devices were accurately represented,voltage
profiles were normal,reactive power flows were within normal operating ranges and
transmission system voltage was maintained to match acceptable PacifiCorp Transmission
Voltage Schedules.
4 Path Studies
4.1 Aeolus West vs.TOT 4B
Based on the assumptions outlined above,the study demonstrated that the Aeolus West
maximum transfer capability limit is 1829 MW,while meeting all NERC and WECC
performance criteria.While this transfer level is 869 MW above the present TOT 4A (960
12
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Transfer Capability Assessment
MW")path limit for similar conditions,east to west transfers have effectively increased by
951 MW due to shifting the Platte area load (82 MW)east of the Aeolus West cut plane.The
Aeolus West path was stressed by using 3351 MW of total generation resources,which
includes thermal (Dave Johnston,717 MW -net),existing wind (1124 MW),and new wind
(1510 MW)resources.The 240 MW of new wind resource in Big Horn Basin was varied with
Wyodak generation as necessary.It was assumed that only the thermal generation at Dave
Johnston and Wyodak generating plants in eastern Wyoming would be adjusted to maintain
transfers on the Aeolus West and the TOT 4B transmission paths.
Table 5:Aeolus West and TOT 4B Corner Point Cases (See Figure 3)
Case Aeolus TOT 4B Limiting Element Outage
West (MW)
(MW)
1 1829 100 Platte-Latham 230 kV line Anticline -Aeolus 500
kV line outagewith
RAS
2 1803 300 Platte-Latham 230 kV line Anticline -Aeolus 500
kV line outage with
RAS
3 1777 500 Platte-Latham 230 kV line Anticline -Aeolus 500
kV line outage with
RAS
4 1763 607 Platte-Latham 230 kV line Anticline -Aeolus 500
kV line outage with
RAS
Dave Johnston South Tap -Casper230 kV CB
Refinery Tap -Casper 1l5 1H4001 failure causing
kV line Casper-Dave Johnston
230 kV and Casper
230/115 kV transformer
outage or Casper-Dave
Johnston 230 kV line
outage
5 1628 699 Platte-Latham 230 kV line Anticline -Aeolus 500
kV line outagewith
RAS
"Maximum nomogram point with normal open point at Platte utilizing the dynamic line rating on Platte -
Standpipe 230 kV line.
13
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Case Aeolus TOT 4B Limiting Element Outage
West (MW)
(MW)
Dave JohnstonSouth Tap -Casper230 kV CB
Refinery Tap -Casper 115 lH4001 failure causing
kV line Casper-Dave Johnston
230 kV and Casper
230/115 kV transformer
outage or Casper-Dave
Johnston 230 kV line
outage
6 1125 880 Yellowtail -Sheridan 230 kV N-0
line
See AppendixB for power flow plots.
The low voltage issue in the Big Horn Wyoming area is an existing issue for the Yellowtail -
Frannie 230 kV line outage or future Q0542 POI -Frannie 230 kV outage.This issue is
resolved by adding capacitor banks at various locations in north Wyoming.A project to install
a new 30 MVAr shunt capacitor bank at Grass Creek 230 kV,two new 20 MVAr shunt
capacitor banks at Frannieand a new 7.5 MVAr capacitor bank at Hilltop l15 kV are proposed.
In the study,one RAS scheme was identified for N-1 outages:
i.Aeolus RAS to trip approximately 630 MW of wind generation depending on pre-
outage flow conditions for any of the new transmission element outages between
Aeolus -Jim Bridger.
Study results are summarized in Table 5 and illustrated in Figure 3.In reviewing Figure 3,it
is evident that the Aeolus West and TOT 4B path interaction are minimized with the addition
of the D.2 Project,as indicated by the straight horizontal line (implying no path interaction)
when Aeolus West flows are below 1125 MW.The Aeolus West vs TOT 4B nomogram"knee
point"is at Aeolus West flows of 1763 MW (TOT 4B,607 MW).As TOT 4B flows increase
from that point,Aeolus West flows reduce;likewise,from the knee point as TOT 4B flows
decrease,Aeolus West flows increase.
14
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Aeolus West Transmission Path
Transfer Capability Assessment
Figure 3:Aeolus West Vs TOT 4B Nomogram
Wyoming System Operating Curve
2022 Heavy Winter Loads
Normal Open Point:Platte115 kV
Aeolus West Vs TOT 4B Nomogram
1000 1125,880
00 1628,699
600 1763,607o
500 1777,5(0
O 100 1803,:00
100 1829,100
0
0 200 400 600 800 1000 1200 1400 1600 1800 2000
Aeolus West Flow (MW)
4.2 Base Case Development
The 2021-22 HW WECC case was modified to simultaneously stress the Aeolus West and the
TOT 4B path flows.The Aeolus West path was stressed using all of eastern and north
Wyoming resources fora total of 3619 MW (existing and future)wind and net coal resources.
These resources were displaced with Jim Bridger and resources in central and southern Utah
such that the Jim Bridger West flows were maintained near 2400 MW.
The TOT 4B path flows were adjusted between a minimum of 100 MW and a maximum of
880 MW.Additional resources were exported from PACE to Montana and WAPA to Montana
to adjust flows across the TOT 4B path between 300 MW and 880 MW using Crossover,
Rimrock and Steam Plant phase shifting transformers in Montana.
The Shiprock,San Juan and Gladstone phase shifting transformers were locked to regulate
flow across the TOT 3 path between Colorado and Wyoming.
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Aeolus West Transmission Path
Transfer Capability Assessment
4.3 Dynamic Stability Analysis
The dynamic stability analysis was performed using PSS/E models provided by both General
Electric (GE)and Vestas's for the repowered and new wind generation.The generic model for
the Root Creek wind model was updated to the GEO501 model (GE 1.85 units).Top of the
World and Three Buttes wind farms in eastern Wyoming were updated to the GE 1.5 wind
turbine model provided by GE for PTI V33.A generic WECC model was used for the Latham
dynamic reactive device.
The stability study was focused in the eastern Wyoming region to demonstratethe acceptable
performance from various new wind farms in the region.The real power,reactive power and
voltage output from the new and the existing wind farm generatorswere reviewed to evaluate
their ability to support the transmission grid voltage and system stability during various outage
scenarios.Due to the combination of different wind turbine models,dynamic analysis also
ensuredthat no interaction issues were being observed.
The dynamic stability study was performed for one (worst case)nomogram point on the Aeolus
West vs.the TOT 4B nomogram curve,which reflected the heaviest Aeolus West flow
conditions.
Dynamic stability analysis was performed on selective critical outages based on anticipated
post fault impacts on the wind generation performance,especially for the portion of the system
with a calculated short circuit ratio of approximately 2.3.See Appendix C for the dynamic
stability analysis summary and dynamic plots.
5 SensitivityAnalysis
The sensitivity analysis focused on the evaluation of two different RAS generation tripping
scenarios to ascertain which scheme would be the most effective at tripping generation
following outage of the D.2 Project facilities between Bridger and Aeolus.
A dynamic stability sensitivity analysis was performed to evaluate the system impact and
generator performance for a single element outage on the D.2 segment between Aeolus 230
kV and Bridger 345 kV buses which requires a RAS for generator tripping.Two different sets
of generatortripping locations and tripping levels (approximately 630 MW)were selected.The
generation tripping of 607 MW,which includes High Plains,Seven Mile Hill,Q706 and
Dunlap wind generation was compared with generation tripping of 628 MW,which includes
High Plains,Q0706 and Q0707 wind generation.For summary results and plots,please see
dynamic simulation cases la -1f2 in Appendix C.
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Aeolus West Transmission Path
Transfer Capability Assessment
6 Study Conclusions
Technical studies demonstrated that with the addition of the planned D.2 Project facilities to
the Wyoming transmission system,system performance will meet all NERC and WECC
performance criteria.
Updated power flow studies demonstrate that by utilizing existing and planned southeast
Wyoming resources',the Aeolus West transmission path can transfer up to 1829 MW under
simultaneous transfer conditions with the TOT 4B transmission path,effectively6 increasing
the east to west transfer levels across Wyoming by 951 MW.Power flow findings also
indicated:
Dynamic voltage control is necessary at the Latham 230 kV substation to mitigate low
voltage conditions resulting from loss of Bridger/Anticline -Aeolus transmission
facilities.
Under certain operating conditions,one RAS scheme will need to be implemented to
trip generation following the outageof specific transmission facilities.
The location (and output level)of new and repowered wind resources can influence the
transfer capability level across the Aeolus West transmission path,the Aeolus West
and TOT 4B nomogram curve and the area under the nomogram curve.
Dynamic stability studies evaluated a wide range of critical system disturbances in eastern
Wyoming.The analyses identified two outages with poor voltage performance,and another
outage identifieda wind turbine modeling problem.These issues are all attributed to the wind
turbine models at the Q0706,Q0707 and Q0708 projects.PacifiCorp is working with the wind
turbine manufacture to resolve these issues.Aside from these issues,the studied outages
evaluated meet the dynamic performance criteria with the system being stable and damped.
17
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Page 20 of 20
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Aeolus West Transmission Path
Transfer Capability Assessment
Report Appendices
Appendix A -Path Definitions
Appendix B -Power Flow Plots
Appendix C -Dynamic Stability Results (Case C7)
18
NON-CONFIDENTIAL Monsanto Exhibit No.214
Case No.PAC-E-17-07
NON-CONFIDENTIAL
MONSANTO EXHIBIT NO.214
Monsanto Exhibit No.215
Case No.PAC-E-17-07
PACIFICORP rage i oris
TRANSMISSION
Large Generator Interconnection
Facilities Study Report
FINAL
Completed for
("InterconnectionCustomer")
Q0409
Proposed Point of Interconnection
PacifiCorp's Freezeout Substation at 230 kV
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TABLE OF CONTENTS
1.0 DESCRIPTION OF THE PROJECT.................................................I
2.0 STUDY SCOPE AND OBJECTIVES................................................l
3.0 STUDY ASSUMPTIONS ..........................................................1
4.0 PROPOSED POINT OF INTERCONNECTION .................................................2
5.0 SCOPE OF WORK ................................................3
5.1 Generating Facility...................................................3
5.1.1 Q0409 Collector Station 1 ..................................................4
5.1.2 Q0409 Collector Stations 2,3 and 4 ................................................6
5.2 Transmission Tie Line..........................................................................................9
5.2.1 INTERCONNECTIONCUSTOMERTO BE RESPONSIBLE FOR.....................................9
5.2.2 TRANSMISSIONPROVIDERTO BE RESPONSIBLE FOR .............................................9
5.3 Point of Interconnection (Freezeout Substation)...................................................10
5.3.1 INTERCONNECTIONCUSTOMERTO BE RESPONSIBLE FOR...................................10
5.3.2 TRANSMISSIONPROVIDERTO BE RESPONSIBLE FOR ...........................................10
5.4 Other..........................................................................................................11
5.4.1 TRANSMISSIONPROVIDERTO BE RESPONSIBLE FOR ...........................................11
6.0 CosT ESTIMATE....................................................11
7.0 SCHEDULE...................................................12
8.0 APPENDICES.............................................................................13
8.1 APPENDIX 1:HIGHER PRIORITY REQUESTS ................................................14
8.2 APPENDIX 2:PROPERTY REQUIREMENTS ................................................15
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1.0 DESCRIPTIONOF THE PROJECT
("Interconnection Customer")proposed interconnecting 320 MW of new generation to
PacifiCorp's ("Transmission Provider")Freezeout 230 kV substation located in Carbon County,
Wyoming.The project ("Project")will consist of 104 Vestas Vl12 3.075 MW wind turbines for
a total output of 320 MW.The requested commercial operation date is December 31,2018.The
Project will be split into four phases each with an output of 80 MW.
Interconnection Customer will operate each phase of this Project as a Qualifying Facility as
defined by the Public UtilityRegulatory Policies Act of 1978 (PURPA).
The Transmission Provider has assigned the overall Project "Q0409"and will refer to the four
phases of the Project as "Q0409A,""Q0409B,""Q0409C"and "Q0409D."
2.0 STUDYSCOPE AND OBJECTIVES
The objective of the facilities study is to:
complete a facilities analysis,which shall specify and estimate the cost of equipment,
engineering,procurement,and construction required to address issues as outlined in the
system impact study,and
provide a scope of work and an estimated cost and schedule for completing the scope of
work.
3.0 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 restudy this
request,as the results and conclusions contained within this study could significantly
change.
For study purposes there are two separatequeues:
o Transmission Service Queue:to the extent practical,all network upgrades that are
required to accommodate active transmission service requests will be modeled in
this study.
o Generation Interconnection Queue:Interconnection Facilities associated with
higher queue interconnection requests will be modeled in this study.
The Interconnection Customer's request for interconnection service in andof itself does
not convey transmission service.Only a Network Customer may make a request to
designate a generating resource as a Network Resource.Because the queue of higher
priority transmission service requests may be different when a Network Customer
requests network resource designation for this Generating Facility,the available
capacity or transmission modifications,if any,necessary to deliver 100%of the Project
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output to network load 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 generating facilities.Therefore,the need for
transmission modifications,if any,which are required to deliver 100%of Project output
to the Network Customer's network load will be evaluated (i.e.,no displacement of
other resources in the same area).
This study assumes the Project will be integrated into Transmission Provider's system
at the agreed upon and/or proposed Point of Interconnection.
The Interconnection Customer will construct and own any facilities required between
the Point of Interconnection and the Project unless specifically identified by the
Transmission Provider.
Generator tripping may be required for certain outages.
All facilities will meet or exceed the minimum Western Electricity Coordinating
Council ("WECC"),North American Electric Reliability Corporation ("NERC"),and
Transmission Provider performance and design standards.
A synchronous condenser at Standpipe Substation is planned to be in-service in June
2016 and is assumed to be in-service for the study.
The Energy Gateway West (2024)and Energy Gateway South (2024)projects are
assumed to be in service;the Dave Johnston to Amasa (future)to Heward to Aeolus
230 kV line is assumed to be rebuilt as part of the Gateway projects.Note that these
dates are inconsistent with the Q0409 Project's planned in-service date.
A separate,Transmission Provider owned control house will be installed at each
collector substation unless during design it is determined that the Transmission
Provider can utilize a portion of the Interconnection Customer's control houses.
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
4.0 PROPOSED POINTOF INTERCONNECTION
The Interconnection Customer's Project is to be interconnected through an existing 230 kV bay
position in the Transmission Provider's Freezeout substation.This will require the construction of
a new bay position to accommodate the relocation of the 230 kV Freezeout-Standpipe transmission
line along with the metering,communication and protection and control equipment for this line.
The new Q0409 230kV transmission line will occupy the vacated Freezeout -Standpipe position.
The Interconnection Customer will construct a double bundled 1272 ACSR 230kV radial
interconnection line approximately 33.75 miles long from the Freezeout substation to Q0409
collector substation 1.The Interconnection Customer will also be responsible for constructing the
additional230kV lines to connect the other phases of the Project to the Q0409 collector substation
1.Communications upgrades will be required at the Portland and Salt Lake Control Centers.
Figure 1 below,is a one-line diagram that illustrates the interconnection of the proposed Project
to the Transmission Provider's system.
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Shiriey Basin
Seven Mile Hill
I
Freezeout
Substation
Point of
interconnection
Q0409
Substation 3
Standpipe
315 Miles vm Q0409
Substation 4e3375Miles345kVMB1
Collector CircuitsQ0409
Substation 1
230 kV
MB1345kV
Collector Circuits
2 5 Miles 4 5 Miles
Q0409
-Substation 2
Collector Circu ts
Figure 1 System One Line Diagram
5.0 SCOPE OF WORK
5.1 Generating Facility
The followingoutlines the design,procurement,construction,installation,and ownership
of equipment at the Interconnection Customer's Generation Facility.
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5.1.1 Q0409 Collector Station 1
5.1.1.1 Interconnection Customer to be Responsible For
Design,procure and construct all facilities required for the Q0409 collector substation 1
except for those common facilities/components indicated as designed,procured or
constructed by the Transmission Provider.
Provide a CDEGS analysis and report to the Transmission Provider which indicates that
the Interconnection Customer's collector substation site 1 has been designed to meet safe
step and touch potential requirements.
Install 230kV,2000A circuit breakers to connect to the 230kV radial transmission line to
Freezeout substation.
Provide circuit breaker specifications to the Transmission Provider for review to ensure the
breakers are compatible with the Transmission Provider's protectionand control design.
Install all protection and control equipment providedby the Transmission Provider.
Install Transmission Provider supplied relay panel.
Design,procure and install line protective relays for the 230kV lines that make up the
network between collector substations 1,2,3 and 4.These relays will need to detect and
clear line faults in six cycles or less.
Install Transmission Provider supplied revenue metering panels,instrument transformers,
junctionboxes and secondary lead conductors.
It is recommended by the Transmission Provider that the InterconnectionCustomer install
metering by-pass switches to avoid generators being taken off line for meter testing,repair,
and service.
Supply an Ethernet phone line,or equivalent communications path,for retail sales and
generation accounting via the MV-90 translation system.This may be provided utilizing
the Transmission Provider's digital communication system.
Provide a separate graded,grounded and fenced area along the perimeter of the collector
station for the Transmission Provider to install a control house.The area will share a fence
and be connected to the collector substation.The control house shall have separate,
unencumbered access for the Transmission Provider.The control house will contain any
required metering,protection,SCADA and communications equipment.This area will also
contain the metering units,switches and deadend structure.
Provide AC station service to the Transmission Provider's control house from a station
service transformer mounted on a distribution pole.The control house will be outfitted with
a weather head to accept the station service drop.
Provide emergency AC power for the Transmission Provider's control house.
Supply all required datapoints hardwired to the Transmission Provider's RTU using DNP3
protocol to the Transmission Provider multiplex in accordance with the Transmission
Provider's interconnection policy.
The followingpoints are required from the InterconnectionCustomer's collector substation
1:
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Analows:
o Transformer real power
o Transformer reactive power
o Real power flow through 34.5 kV line feeder breaker 1
o Reactive power flow through 34.5 kV line feeder breaker 1
o Real power flow through 34.5 kV line feeder breaker 2
o Reactive power flow through 34.5 kV line feeder breaker 2
o Real power flow through 34.5 kV line feeder breaker 3
o Reactive power flow through 34.5 kV line feeder breaker 3
o Real power flow through 34.5 kV line feeder breaker 4
o Reactive power flow through 34.5 kV line feeder breaker 4
o A phase 230 kV transmission voltage
o B phase 230 kV transmission voltage
o C phase 230 kV transmission voltage
o Wind speed
Status:
o 230kV breaker 1
o 230kV breaker 2
o 230kV breaker 3
o 230kV breaker 4
o 230kV circuit switcher
o 34.5kV main breaker
o 34.5kV collector circuit breaker 1
o 34.5kV collector circuit breaker 2
o 34.5kV collector circuit breaker 3
o 34.5kV collector circuit breaker 4
o Line Relay Alarm
Design,procure,install and terminate ADSS fiber optic cable from a fiber optic cable splice
box on the last dead-end structure of the 230 kV tie line from the Point of Interconnection
substation.Route the cable into the Transmission Provider's collector substation control
building in an underground raceway.The raceway from the splice box (3"conduit
minimum)will terminate in a fiber optic patch panel in the control building.All fiber optic
cable and equipment between the Point of Interconnection substation and collector
substation 1 will be owned and maintained,at the Interconnection Customer's expense,by
the Transmission Provider.
Perform end to end check out of the fiber optic cable from the patch panels at the collector
substation to the patch panel located at the Point of Interconnection substation.
5.1.1.2 Transmission Provider to be Responsible For
Review the Interconnection Customer's circuit breaker specifications to ensure
compatibility with the Transmission Provider's protection and control design.
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Design and procure a transmission line protective relay panel and provide to
Interconnection Customer for installation.The panel will be owned and maintained,at the
InterconnectionCustomer's expense,by the Transmission Provider.
Install a control house adjacent to the collector station at an Interconnection Customer
supplied graded,grounded and fenced area.A list of the major equipment to be installed
is as follows:
o 3 -230kV,CT/PT combined metering units
o 2 -230kV,switches,meter disconnect,group operated
o 1 -line current differential relay panel
o 1 -Control house
o 1 -125VDC battery bank with charger
Complete wiring of outputs to the fiber communications system.
Design,procure,install,own,and maintain an RTU at the collector substation.
Provide a list of data inputs and outputs required for protection,control and data collection
in accordance with the Transmission Provider's interconnection policy.
Design and procure the collector substation metering panels.The collector substation
metering design packages will include two revenue quality meters,test switches,and all
SCADA metering data terminated at a metering interposition block.
Design,procure and own the interconnection revenue metering system including the
instrument transformers,metering panel,junctionbox and secondary metering wire.The
interchange metering will be designed bidirectional and rated for the total net generation
of the Project including metering the retail load (per tariff)deliveredto the customer.
Design,procure,install,own and maintain DMX fiber nodes and multiplex in the
Transmission Provider's control house.
Own and maintain,at the Interconnection Customer's expense,all fiber optic cable,
associated communications equipment and metering equipment.
Supply all specifications required for common equipment to facilitate design of the
collector station.
Perform final checkout and testing/commissioning of the interconnecting line protection
control systems in the collector station.
5.1.2 C10409 Collector Stations 2,3 and 4
5.1.2.1 Interconnection Customer to be Responsible For
Design,procure and construct all facilities required for Q0409 collector substations 2,3
and 4 except for those common facilities/components indicated as designed,procured or
constructed by the Transmission Provider.
Provide CDEGS analysis and reports to the Transmission Provider which indicates that
each of the Interconnection Customer's collector substation sites 2,3 and 4 have been
designed to meet safe step and touch potential requirements.
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Install 230kV,2000A circuit breakers to connect to the 230kV transmission line network
that connects collector substations 2,3 and 4.
Provide collector substation 2,3 and 4 circuit breaker specifications to the Transmission
Providerfor review to ensure the breakers are compatible with the Transmission Provider's
protection and control design.
Provide a separate graded,grounded and fenced area along the perimeter of each of the
collector substations for the Transmission Provider to install a control house.The area will
share a fence and be connected to each of the respective collector substations and have
separate,unencumbered access for the Transmission Provider.The control house will
contain any required metering,protection,SCADA and communications equipment.This
area will also contain the metering units,switches and deadend structure.
Provide AC station service to each of the Transmission Provider's control houses from a
station service transformer mounted on a distribution pole.The control house will be
outfitted with a weather head to accept the station service drop.
Provide emergency AC power to the Transmission Provider's control house.
Supply all required data points hardwired to the Transmission Provider's RTU using DNP3
protocol to the Transmission Provider multiplex in accordance with the Transmission
Provider's interconnection policy.
The followingpoints are required from each of the Interconnection Customer's collector
substations 2,3 and 4:
Analogs:
o Transformer real power
o Transformer reactive power
o Real power flow through 34.5 kV line feeder breaker 1
o Reactive power flow through 34.5 kV line feeder breaker 1
o Real power flow through 34.5 kV line feeder breaker 2
o Reactive power flow through 34.5 kV line feeder breaker 2
o Real power flow through 34.5 kV line feeder breaker 3
o Reactive power flow through 34.5 kV line feeder breaker 3
o Real power flow through 34.5 kV line feeder breaker 4
o Reactive power flow through 34.5 kV line feeder breaker 4
o Wind speed
Status:
o 230 kV breaker 1
o 230 kV breaker 2
o 230 kV circuit switcher
o 34.5 kV main breaker
o 34.5 kV collector circuit breaker 1
o 34.5 kV collector circuit breaker 2
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o 34.5 kV collector circuit breaker 3
o 34.5 kV collector circuit breaker 4
o Relay Alarm
Design,procure,install and own a fiber optic cable system between the collector
substations.Route the cable into each of the Transmission Provider's collector substation
control buildings in an underground raceway.The raceway will terminate in a fiber optic
patch panel.All fiber optic cable and communications equipment between the collector
stations will be owned and maintained by the Interconnection Customer.
Install Transmission Provider supplied revenue metering panels,instrument transformers,
junctionboxes and secondary lead conductors.
It is recommended by the Transmission Provider that the InterconnectionCustomer install
metering by-pass switches to avoid generators being taken off line for meter testing,repair,
and service.
Supply an Ethernet phone line,or equivalent communications path,for retail sales and
generation accounting via the MV-90 translation system.This may be provided utilizing
the Transmission Providers digital communication system.
Perform end to end check out of the fiber optic cable from the patch panels at each of the
collector substations to the patch panel located at the Point of Interconnection substation.
5.1.2.2 Transmission Provider to be Responsible For
Review the Interconnection Customer's circuit breaker specifications to ensure
compatibility with the Transmission Provider's protection and control design.
Install a control house in each of the collector substations at an Interconnection Customer
supplied graded,grounded and fenced area.A list of the major equipment required is as
follows:
o 3 -230kV,CT/PT combined metering unit
o 2 -230kV,switch,meter disconnect,group operated
o 1 -Control house
o 1 -125VDC battery bank with charger
Design,procure,install,own,and maintain an RTU at each of the Q0409 collector
substations 2,3,and 4 in the Transmission Provider's control houses.
Design,procure,install,own and maintain DMX fiber nodes and multiplex in the each of
the Transmission Provider's control houses.
Provide a list of data inputs and outputs required for protection,control and data collection
in accordance with the Transmission Provider's interconnection policy.
Design and procure the collector substation metering panels.The collector substation
metering design packages will include two revenue quality meters,test switches,and all
SCADA metering data terminated at a metering interpositionblock.
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Design,procure and own the interconnection revenue metering system including the
instrument transformers,metering panels,junctionboxes and secondary metering wire.
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.
Supply all specifications required for common equipment to facilitate design of the
collector station.
Perform final checkout and testing/commissioning of the interconnecting line protection
control systems in the Collector Stations.
5.2 Transmission Tie Line
The followingoutlines the design,procurement,construction,installation,and ownership
of equipment associated with the radial line connecting the Interconnection Customer's
Generating Facility to the Transmission Provider's Point of Interconnectionsubstation.
5.2.1 INTERCONNECTIONCUSTOMERTO BE RESPONSIBLE FOR
Obtain all necessary permits,easements,and rights of way for the construction of the
230kV radial interconnection line from the Freezeout substation to the Q0409 Collector
Substation 1.
Design,procure,and construct an approximately33.75 mile,double bundled 1272 ACSR
230 kV radial transmission line from the Freezeout substation to the Q0409 collector
substation 1.
Construct the last Interconnection Customer owned structure and conductor span to the
Transmission Provider's standards.The Transmission Providerwill terminate the last span
of Interconnection Customer owned conductor into Freezeout substation.If the
InterconnectionCustomer's transmission line crosses other Transmission Provider lines,it
must cross under any existing transmission line(s).
Install OPGW fiber optic cable from the Point of Interconnection substation to collector
substation 1.Terminate the OPGW fiber optic cable on the last dead-end structure of the
230kV radial interconnection line outside the Freezeout substation fence using an
appropriate fiber optic splice box.All fiber optic cable and equipment on the tie line will
be owned and maintained by the Transmission Provider at the Interconnection Customer's
expense.
Perform end to end checkout of the installed fiber optic cable circuitry between the
collector substations and Point of Interconnection substation.Final checkout and
acceptance shall be performed by the Transmission Provider.
5.2.2 TRANSMISSIONPROVIDERTO BE RESPONSIBLE FOR
Provide specifications for the installation and testing of the fiber optic cable installation
between the collector and Point of Interconnection substations.
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Own and maintain,at the Interconnection Customer's expense,al fiber optic cable and
associated equipment on the tie line.
Review the design of the last transmission line structure outside the Point of
Interconnection substation to ensure compatibility with the substation termination
structure.
Pull in the last span of the Interconnection Customer owned 230kV conductor and shield
wire and terminate at the Freezeout substation.The Interconnection Customer's
transmission line must cross under any existing lines.
Perform final checkout and acceptance of the fiber optic communications system.
5.3 Point of Interconnection (Freezeout Substation)
The followingoutlines the design,procurement,construction,installation,and ownership
of equipment at the Point of Interconnection.
5.3.1 INTERCONNECTIONCUSTOMERTO BE RESPONSIBLE FOR
Obtain all necessary permits,lands,rights of way and easements required for the
interconnection of the Q0409 230kV transmission line.
5.3.2 TRANSMISSIONPROVIDERTO BE RESPONSIBLE FOR
Procure and install ADSS fiber optic cable from the fiber optic splice box on the last
transmission line structure of the Interconnection Customer's 230kV radial transmission
line in conduit or cable tray into the Freezeout substation control building.
Design,procure,install,own and maintain DMX fiber nodes and install multiplex in the
Point of Interconnection substation control house.
Design,procure and install a transmission line protective relay panel for line fault
detection.These relays are for the protection of the radial transmission line to the Q0409
collector substations.
Design,procure and install a relay for under/over voltage and over/under frequency
protection of the system.If an out of operating range condition occurs,a signal will be sent
over the fiber optic cable to trip open all of the Q0409 34.5kV feeder breakers at the
collector substations.
Design,procure and construct a new bay position to accommodate the relocation of the
230kV Freezeout-Standpipe transmission line along with the metering,communication and
protection and control equipment for this line.The new Q0409 230kV transmission line
will occupy the vacated Freezeout -Standpipe position.A list of the major equipment
required is as follows:
>1 -245kV,circuit breaker
>2 -230kV,switch,breaker disconnect,group operated,vertical break,manually operated
>1 -230kV,switch,line disconnect,group operated,vertical break,with motor operator,
with grounding blade
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>3 -230kV,CT/PT metering unit
>3 -144kV MCOV surge arrester
Design,procure,install and own the interconnection revenue metering system including
the instrument transformers,metering panel,junction box and secondary metering wire.
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.
Install the metering panel in the Point of Interconnection control building and complete all
cable terminations on panel.
Listed below is the data required from Point of Interconnection substation.
Analows:
o Net Generation real power
o Net Generator reactive power
o Interchange energy register
5.4 Other
The followingoutlines the design,procurement,construction,installation,and ownership
of equipment past the Point of Interconnection.
5.4.1 TRANSMISSIONPROVIDERTO BE RESPONSIBLE FOR ,
Upgrade the communications at the Transmission Provider's Portland and Salt Lake
control centers to accommodate the addition of the Q0409 Project.
Design,procure necessary equipment and construct a 3.5 mile rebuild of the 230kV
Aeolus-Freezeout transmission line.The line will be rebuilt to allow the existing OPGW
fiber to remain in service during construction as an extended outage will not be possible.
Design a Local Area Protection Scheme ("LAPS")to trip the Q0409 Project for an outage
of the Aeolus-Freezeout 230kV line.
Procure,construct and install all necessary equipment to implement the LAPS.
Design and install necessary generator tripping/load reduction schemes that will be
required to insure system stability during system disturbances.
If necessary,present for approval any generator tripping/load reduction schemes to the
WECC Remedial Action Scheme Reliability Subcommittee ("RASRS").
6.0 CosT ESTIMATE
The followingestimate represents only scopes of work that will be performed by the
Transmission Provider.Costs for any work being performed by the Interconnection Customer are
not included.
InterconnectionCustomer Collector Substations -Metering,Communications,$4,829,000
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Protection &Control Equipment and Control Houses
Freezeout Substation -New Bay Position,Metering,Communications and $1,619,000
Protection &Control Equipment
Freezeout Substation -Relocate Existing Standpipe Line $379,000
Freezeout -Aeolis Transmission Line -Rebuild Line $2,955,000
Control Centers -Modify Communications $19,000
Total Estimate Cost $9,801,000
Note:Costs for any excavation,duct installation and easements shall be borne by the
InterconnectionCustomer and are not included in this estimate.This estimate is as accurate as
possibly given the level of detailed study that has been completed to date and approximates the
costs incurred by Transmission Provider to interconnect this Generator Facility to Transmission
Provider's electrical distribution or transmission system.The Interconnection Customer will be
responsible for all actual costs,regardless of the estimated costs communicated to or approved
by the InterconnectionCustomer.
7.0 SCHEDULE
The following schedule has been developed based on the Interconnection Customer's date of
application for this Project of January 25,2012 and the requirement that the Project be complete
within ten years of the application as well as the requirement that the Transmission Provider's
Energy Gateway South and Aeolus to Populous portion of Gateway West projects come into
service as currently planned in 2024.Interconnecting the Project before the Energy Gateway
projects are in service would create system emergency conditions.Thus,the Project will require
the Energy Gateway projects to be in-service in order to maintain system reliability.Should the
scheduled in-service dates for the Transmission Provider's Gateway projects be modified the
dependent dates for this Project must also be modified accordingly.
Execute InterconnectionAgreement June 1,2016
Provision of Financial Security January 1,2020
InterconnectionCustomer Design Information Provided January 1,2020
*Transmission Provider Engineering &Procurement Commences February 1,2020
**Interconnection Customer Energy Imbalance Market Modeling March 1,2020
Data Submittal
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Transmission Provider Engineering Design Complete June 1,2020
InterconnectionCustomer Property/Permits/ROW Procured July 1,2020
Transmission Provider Construction Begins August 1,2020
InterconnectionCustomer Construction Complete October 1,2021
InterconnectionCustomer's Facilities Receive Backfeed Power January 15,2022
Transmission Provider Energy Gateway Projects Complete September 1,2024
Transmission Provider Construction Complete October 1,2024
Initial Synchronization/Generation Testing November 1,2024
Commercial Operation December 15,2024
*As applicable and determined by the Transmission Provider,within 60 days of the
Interconnection Customer's authorization for the Transmission Provider to begin engineering,the
InterconnectionCustomer shall provide a detailed short circuit model of its generation system.
This model must be constructed using the ASPEN OneLine short circuit simulation program and
contain all individual electrical components of the Interconnection Customer's generation system.
**Any design modifications to the Interconnection Customer's Generating Facility after this date
requiring updates to the Transmission Provider's network model may result in a minimum of 3
months added to all future milestones including Commercial Operation.
Please note,due to the requirement for the Transmission Provider's Gateway West and Gateway
South projects to be in service prior to the Interconnection Customer's Project commencing
commercial operation the time required to perform the scope of work identified in this report does
not support the Interconnection Customer's requested Commercial Operation date of December
31,2018
8.0 APPENDICES
Appendix 1:Higher Priority Requests
Appendix 2:Property Requirements
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8.1 APPENDIX 1:HIGHER PRIORITYREQUESTS
All active higher priority transmission service and/or generator interconnection requests will be
considered in this study and are identified below.If any of these requests are withdrawn,the
Transmission Provider reserves the right to restudy this request,as the results and conclusions
contained within this study could significantly change.
Transmission/Generation Interconnection Queue Requests considered:
Q0199 (200 MW)
Q0200 (100 MW)
Q0201 (100 MW)
Q0267 (88 MW)
Q0290 (252 MW)
Q0306 (80 MW)
Q0375 (230 MW)
Q0407 (79.8 MW)
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8.2 APPENDIX2:PROPERTY REQUIREMENTS
Property Requirements for Point of Interconnection Substation
Requirements for rights of way easements
Rights of way easements will be acquired by the Interconnection Customer in the Transmission
Provider's name for the construction,reconstruction,operation,maintenance,repair,replacement
and removal of Transmission Provider's InterconnectionFacilities that will be owned and operated
by PacifiCorp.Interconnection Customer will acquire all necessary permits for the project and will
obtain rights of way easements for the project on Transmission Provider's easement form.
Real Property Requirements for Point of Interconnection Substation
Real property for a point of interconnection substation will be acquired by an Interconnection
Customer to accommodate the Interconnection Customer's project.The real property must be
acceptable to Transmission Provider.Interconnection Customer will acquire fee ownership for
interconnectionsubstation unless Transmission Providerdetermines that other than fee ownership
is acceptable;however,the form and instrument of such rights will be at Transmission Provider's
sole discretion.Any land rights that Interconnection Customer is planningto retain as part of a fee
property conveyance will be identified in advance to Transmission Provider and are subject to the
Transmission Provider's approval.
The InterconnectionCustomer must obtainall permits required by all relevant jurisdictions for the
planned use including but not limited to conditional use permits,Certificates of Public
Convenience and Necessity,California Environmental Quality Act,as well as all construction
permits for the project.
Interconnection Customer will not be reimbursed through network upgrades for more than the
market value of the property.
As a minimum,real property must be environmentally,physically,and operationally acceptable to
Transmission Provider.The real property shall be a permitted or permittable use in all zoning
districts.The Interconnection Customer shall provide Transmission Providerwith a title report and
shall transfer property without any material defects of title or other encumbrances that are not
acceptable to Transmission Provider.Property lines shall be surveyed and show all encumbrances,
encroachments,and roads.
Examples of potentially unacceptable environmental,physical,or operational conditions could
include but are not limited to:
1.Environmental:known contamination of site;evidence of environmental
contamination by any dangerous,hazardous or toxic materials as defined by any
governmental agency;violation of building,health,safety,environmental,fire,
land use,zoning or other such regulation;violation of ordinances or statutes of
any governmental entities havingjurisdiction over the property;underground or
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above ground storage tanks in area;known remediation sites on property;ongoing
mitigation activities or monitoring activities;asbestos;lead-based paint,etc.A
phase I environmental study is required for land being acquired in fee by the
Transmission Provider unless waived by Transmission Provider.
2.Physical:inadequate site drainage;proximityto flood zone;erosion issues;
wetland overlays;threatened and endangered species;archeological or culturally
sensitive areas;inadequate sub-surface elements,etc.Transmission Provider may
require Interconnection Customer to procure various studies and surveys as
determined necessary by Transmission Provider.
Operational:inadequate access for Transmission Provider's equipment and vehicles;existing
structures on land that require removal prior to building of substation;ongoing maintenance for
landscaping or extensive landscape requirements;ongoing homeowner's or other requirements or
restrictions (e.g.,Covenants,Codes and Restrictions,deed restrictions,etc.)on property which
are not acceptable to the Transmission Provider.
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20000-520-EA-17 /Rocky Mountain Power Page 1 of 1
February 28,2018
WIEC Data Request 17.7 -
WIEC Data Request 17.7
Please refer to the Supplemental Direct Testimony of Mr.Rick Link at page 7,lines 5-14.
(a)Please identifythe referencedqualifying facilities,including the project
interconnection queue numbers.
(b)Are there any other qualifying facilities that haveidentified a point of interconnection
on Segment D.2 that are higher in the queue than those wind facilities identified in the
Final Short List?If so,please identify the project interconnection queue numbers,
indicate the capacity of each project (MW),and explain how the Company has
accounted for the transmission capacity necessary to bring such qualifying facilities
online.
(c)Are there any other qualifying facilities that have identified a point of interconnection
on Segment D.2 that have signed interconnection agreements,but that have not yet
come online?If so,please identify the project interconnection queue numbers,
indicate the capacity of each project (MW),and explain how the Company has
accounted for the transmission capacity necessary to bring such qualifying facilities
online.
Response to WIEC Data Request 17.7
(a)Mud Springs Project LLC,Horse Thief Project LLC,and Pryor Caves Project LLC.
The project interconnection queue numbers are Q0542A,Q0542B,and Q0542C.
(b)Yes.Project interconnection queue numbers Q0409A,Q0409B,Q0409C,and
Q409D.Each project associated with the identified queue numbers is 80 megawatts
(MW).The system impact studies (SIS)for these qualifyingfacility (QF)projects
require elements of Energy Gateway beyondjust the Aeolus-to-Bridger/Anticline
Segment D.2.Consequently,the Company does not need to reserve interconnection
capacity enabled by the Aeolus-to-Bridger/Anticline Segment D.2 line for these
specific QF projects.
(c)Please refer to the Company's response to subpart (b)above.
Respondent:Bruce Griswold
Witness:Rick Link