BCRUA_R-19-04-24-5C RESOLU'T'ION NO. R-19-04-24-5C
WHEREAS, the Brushy Creek Regional Utility Authority, Inc. ("BCRUA") desires to
enter into an agreement with Pedernales Electric Cooperative, Inc. regarding BCRUA's Regional
Water Treatment and Transmission System (Temporary Power Project) Phase 2, Now Therefore
BE IT RESOLVED BY THE BOARD OF DIRECTORS OF THE BRUSHY
CREEK REGIONAL UTILITY AUTHORITY:
That the Board President is hereby authorized and directed to execute on behalf of the
BCRUA an Agreement with Pedernales Electric Cooperative, Inc. Regarding Phase 2 of the
BCRUA's Regional Water Treatment and Transmission System (Temporary Power Project), a
copy of same being attached hereto as Exhibit "A" and incorporated herein for all purposes.
The Board of Directors hereby finds and declares that written notice of the date, hour,
place and subject of the meeting at which this Resolution was adopted was posted and that such
meeting was open to the public as required by law at all times during which this Resolution and
the subject matter hereof were discussed, considered and formally acted upon, all as required by
the Open Meetings Act, Chapter 551, Texas Government Code, as amended.
RESOLVED this 24th day of April, 2019.
ANDREA NAVARRETTE, President
Brushy Creek Regional Utility Authority
ATTEST:
RE E FLORES, Sliere ry
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AGREEMENT REGARDING PHASE 2
OF THE BCRUA'S
REGIONAL WATER TREATMENT AND TRANSMISSION SYSTEM
(TEMPORARY POWER PROJECT)
This Agreement("Agreement") is entered into by and between the Brushy Creek Regional Utility
Authority, Inc. ("BCRUA"), a local government corporation composed of the Texas home-rule
cities of Cedar Park,Leander,and Round Rock(individually,the"City";collectively,the"Cities")
and Pedernales Electric Cooperative, Inc. ("PEC"), a Texas electric cooperative corporation
formed under Chapter 161 of the Texas Utilities Code.
RECITALS
WHEREAS, BCRUA was created by the Cities to design,construct and operate a regional
water transmission and treatment system to provide the Cities with drinking water; and
WHEREAS, BCRUA has completed Phase I of the regional system including a floating
raw water pump station located on Lake Travis, a water treatment plant located in Cedar Park,and
associated transmission pipelines; and
WHEREAS, Phase 2 of the BCRUA regional system is required to meet future water
demands for the Cities and to provide a dependable method of accessing water from Lake Travis
during times of severe drought; and
WHEREAS, the Phase 2 water project consists of a deep-water intake and maintenance
building located within the Village of Volente, a pump station located adjacent to the Lower
Colorado River Authority Sandy Creek Park,and tunneled water conveyance pipelines(the"Water
Project"); and
WHEREAS,the Water Project is located within the PEC service area and requires electric
distribution upgrades, improvements, and line extensions ("EIectric Project") and upgrades and
expansion of the PEC Nameless Substation ("Substation Project") across certain parcels in
Williamson and Travis Counties,Texas; and
WHEREAS,the Water Project,the Electric Project and Substation Project include various
phases; and
WHEREAS, BCRUA has completed preliminary design of the Water Project and
commenced easement acquisition for the Water Project and the Phase 2 Electric Project -
Temporary Power, hereinafter referred to as the "Temporary Power Project", (as defined herein);
and
WHEREAS, for the Iast two years BCRUA has relied on preliminary design and routing
recommendations produced by M&S Engineering, Inc. ("M &S")and reviewed and accepted for
purposes of preliminary routing by PEC and serve as the basis for the ongoing easement acquisition
program; and
00422448.00cx:sis
WHEREAS, the initial phase of the Electric Project includes (a) providing temporary
electric service to BCRUA's contractor in order for such contractor to construct a portion of the
Water Project and (b) relocating the electric facilities at the pump station site (collectively,
"Temporary Power Project"), each of which is expected to be completed by March 31, 2021 and
prior to commencement of construction of the Water Project; and
WHEREAS, all remaining phases of the Electric Project and Substation Project must be
completed prior to commissioning and final acceptance of the Water Project.
NOW, THEREFORE, in consideration of the foregoing premises and the mutual
covenants and agreements herein contained, BCRUA, the Cities, and AEC agree as follows:
1. Temporary Power Project. This Agreement mainly addresses the Temporary Power
Project requirements and responsibilities. The parties acknowledge that other phases of
the Electric Project and the Substation Project to serve the Water Project will require
additional agreements between the parties. The Temporary Power Project is expected to
serve a load of up to 5 MVA.
2. Preliminary Design. The preliminary design of the Temporary Power Project has been
completed along the designated route from 1431 along Trails End Road to the Water
Project pump station on Lime Creek Road ("Preliminary Design") and is based on the
currently known route and PEC specifications and is attached on Exhibit A hereto and
incorporated herein.The Preliminary Design route is subject to any changes that may arise
due to easement acquisitions for the Temporary Power Project. It is anticipated that the
portion of the Water Project requiring the Temporary Power Project will be served from
the existing PEC Nameless Substation.
3. Easement Acquisition.
a. BCRUA and M & S have previously delivered preliminary routing maps of the
entire Water Project and the Temporary Power Project to PEC that detail the
affected landowners and properties. PEC has existing easement rights for its
existing facilities. The parties acknowledge that PEC had no immediate plans to
upgrade these facilities. While some of these existing easements may permit the
Temporary Power Project, the parties acknowledge that some of these easements
are likely not sufficient for the upgrade of the existing facilities for the Temporary
Power Project.
b.
To the extent that the existing easements are not sufficient for the Temporary Power
Project, BCRUA and its member Cities will be responsible for the acquisition of
the easements and right of way necessary for the Temporary Power Project.
However, to the extent that the Temporary Power Project additionally provides
upgrades to the PEC electric system, PEC shall be responsible For 50% of the
administrative costs relating to surveying, researching and updating easements for
the Temporary Power Project, but PEC's cost shall not exceed $50,000.00. PEC
acknowledges and agrees that BCRUA's acquisition of easements or right of way
2
for the Temporary Power Project are required to serve a portion of the Water
Project, and are for the construction, maintenance and operation of the Temporary
Power Project for a portion of the Water Project which is to be undertaken as a
public benefit. PEC acknowledges that BCRUA through its member Cities may
utilize eminent domain and condemnation proceedings to acquire the needed
easements. Easements acquired by BCRUA and its member Cities pursuant to this
Section 3 shall either be granted directly to FEC or assigned or otherwise
transferred to AEC by the condemning authority at no cost to PEC, other than the
contribution described in this Section 3. To the extent that eminent domain and
condemnation proceedings must be used to obtain any easement or right of way,
the BCRUA through its member Cities agrees to comply with all applicable laws
for the use of any eminent domain authority. PEC acknowledges that easement
acquisition and the potential associated use of eminent domain and condemnation
is being completed in order for FEC to serve a portion of the Water Project which
is expected to benefit residents in certain cities for which PEC provides electric
service.
C.
PEC agrees to cooperate with BCRUA's and its contractor's efforts to obtain
easements for the Temporary Power Project to serve a portion of the Water Project,
and further, BCRUA and its consultants, with PEC's cooperation, shall respond to
property owner questions and comments as required. With respect to such
cooperation PEC shall be responsible for no more than $50,000 of the
administrative costs relating to researching existing easements, reviewing design
locations for facilities for the Temporary Power Project and comparing designs to
existing easements. BCRUA acknowledges that PEC may retain outside
consultants to assist PEC in these efforts, and such expenditures by PEC to third-
parties shall be deducted from the$50,000.
4. Final Design. BCRUA and PEC agree to work cooperatively to implement final design of
the Temporary Power Project according to the following allocation of responsibilities:
a. Final Design Tasks tivilh BCRUA in Lead Role. BCRUA agrees to lead design of
the Water Project and Temporary Power Project. BCRUA agrees to maintain a
contract with M & S to complete final design of the Temporary Power Project.
BCRUA agrees to provide a final design of the Temporary Power Project in
segments or phases for PEC's review.
b. Final Design Tasks with PEC in Lead Role. PEC agrees to review, comment, and
provide written final design acceptance of final design of the Temporary Power
Project provided by BCRUA or its consultant assuming such designs meet PEC's
system requirements and specifications. Upon written final design acceptance of
the Temporary Power Project by PEC and provided no further design changes are
required, BCRUA will no longer have any responsibility as to securing the design
and engineering of the Temporary Power Project.
3
5. Construction. To the extent that any easement acquisition or any condemnation
proceeding or litigation proceeding delays or stops construction of the Temporary Power
Project, BCRUA shall be responsible for any demobilization costs assessed by the
contractor or consultant against PEC and any resulting re-mobilization costs assessed by
the contractor or consultant. It is anticipated that construction of the Temporary Power
Project may involve multiple construction contracts that are awarded at different times
based on the schedule requirements of the Water Project. As to the Temporary Power
Project, PEC intends to use PEC approved contractors for the construction. BCRUA
acknowledges that PEC is the sole certificated provider of electric distribution services in
the territory in which the Temporary Power Project is to be constructed.
6. Permitting. BCRUA agrees to obtain all applicable permits as required for construction
and any necessary vegetation management, including any permit required by the Balcones
Canyonland Conservation Plan for the portion of the Water Project to be served by the
Temporary Power Project. To the extent that any permitting requirements delays or stops
construction of the Temporary Power Project, BCRUA shall be responsible for any
demobilization costs assessed by the contractor or consultant against PEC and any resulting
re-mobilization costs assessed by the contractor or consultant against PEC.BCRUA further
agrees to submit the requisite service applications to PEC for project commencement.
7. Payment and Costs.
a. PEC anticipates providing cost estimates to BCRUA in phases for costs of the
construction of the Temporary Power Project. The cost estimates will generally
include costs for labor and materials and associated overheads for the design and
construction for all components, including any costs for vegetation management,
of the Temporary Power Project necessary to support this portion of the Water
Project. The initial cost estimate for construction is expected to include the costs
of vegetation management for the Temporary Power Project. Within forty-five(45)
days prior to commencement of the initial phase of construction of the Temporary
Power Project, PEC shall notify BCRUA of the estimated costs of labor and
materials required for that phase of the Temporary Power Project. Upon receipt of
a cost estimate, BCRUA agrees to pay PEC the estimated costs for labor and
materials and associated overheads included therein in advance prior to PEC
commencing that phase of construction. To the extent that FEC has not received
payment by BCRUA for any phase prior to construction of that phase, PEC shall
not proceed with the Temporary Power Project, and BCRUA shall be responsible
for any demobilization costs assessed by the contractor or consultant against PEC
and any resulting re-mobilization costs assessed by the contractor or consultant.
BCRUA acknowledges that this Agreement does not address any costs for other phases
of the Electric Project or Substation Project.
b. Any changes to the routing or design of any segment or phase of the Temporary
Power Project after DEC's acceptance may affect costs. AEC agrees to bear any
4
additional costs resulting from any changes by PEC to the routing or design to
accommodate PEC's system improvements or to provide supplemental benefits to
PEC. BCRUA agrees to bear any additional costs from changes to the routing or
design not associated with PEC system improvements or not providing
supplemental benefits to PEC.
c. Costs of the Temporary Power Project submitted to the BCRUA shall be in
accordance with the Tariff and Business Rules of PEC in effect as of the date of
construction.
d. Pursuant to the existing Tariff and Business Rules of PEC, PEC shall exercise
prudent judgment in determining the conditions under which a specific overhead
line extension will be made and shall view each case individually and with terms
and conditions deemed reasonable by PEC. All amounts paid to AEC as
contribution in aid of construction shall be non-refundable.
8. Communication. BCRUA and PEC agree to hold periodic project status information
meetings. PEC's official point of contact for the Temporary Power Project is the Cedar
Park Electrical Distribution Design & Planning Manager. BCRUA's official point of
contact is the BCRUA General Manager. BCRUA and AEC agree to include these
designated points of contact in the chain of communication for all significant decisions and
recommendations prepared by design engineers and other parties and representatives.
9. Schedule. The current Water Project schedule anticipates that the Temporary Power
Project be completed no later than March 31, 2021. Design and construction of the
Temporary Power Project is expected to take approximately 18 months. The parties
acknowledge that the timeframe is estimated and is subject to receipt of the necessary
easements as described herein and any other land rights and applicable permits for the
Temporary Power Project prior to construction commencing for the Temporary Power
Project, each to be obtained by BCRUA. Notwithstanding the inclusion of a date for the
energization of the Temporary Power Project, PEC shall not be liable for any failure to
meet any service date contained herein.
10. Substation Project. The parties agree that the Nameless Substation requires a redesign to
include additional capacity in order to serve the completed Water Project expected in 2025.
The preliminary designs for the Nameless Substation redesign options are included as
Exhibit B attached hereto and incorporated herein. Selection of a redesign option will be
determined no later than November 30, 2020 to allow BCRUA to prepare Funding
applications.
11. Power Supply Redundancy. The Water Project requires a level of power supply
redundancy for the health of the citizens served by the BCRUA and its member Cities.
When the completed Water Project is in service (expected in 2025), the existing City of
Cedar Park, City of Leander and BCRUA floating raw water intake facilities will be
decommissioned. Upon completion of the Water Project, the parties acknowledge that the
BCRUA wishes to reserve capacity in substation and feeders. To reserve substation and
feeder capacity up to a connected load of 7,800 horsepower with a maximum single motor
5
size of approximately 3,600 horsepower on a VFD starter, PEC shall require a payment in
accordance with its Tariff and Business Rules then in effect.
12. Rates for Temporary Power. The rates for the portion of the Water Project to be served
by the Temporary Power Project will be in accordance with the conditions of the Tariff and
Business Rules of PEC then in effect as of the date of energization of the Temporary Power
Project. At least 6 months prior to energization, BCRUA shall provide the load profile for
the portion of the Water Project to be served by the Temporary Power Project, and PEC
will evaluate such profile and conduct any cost of service studies to determine if the Large
Power customer classification under the existing Tariff and Business Rules of PEC with an
expected demand of more than 75kW but less than 10,000 kW would apply to the
Temporary Power Project.
13. Compliance with Laws.
a. During the term of the Agreement, the parties will perform in compliance,
conformance, and accordance with all applicable laws, rules, and regulations of
the United States,and of any state or political subdivision thereof.
b. In accordance with Chapter 2270,Texas Government Code,a governmental entity
may not enter into a contract with a company for goods or services unless the
contract contains written verification from the company that it: (1)does not boycott
Israel; and (2) will not boycott Israel and will not boycott Israel during the term of
this contract. The signatory executing this Agreement on behalf of Vendor verifies
Vendor does not boycott Israel and will not boycott Israel during the term of this
Agreement.
14. Liability; No Waiver of Immunities.
a. PEC does not assume any liability for any property damage, injuries or death in
connection with the design, engineering or construction of the Water Project or
entry onto third-party property in connection with the Water Project or with respect
to any easement acquisition by BCRUA for the Temporary Power Project. TO THE
EXTENT PERMITTED BY LAW, BCRUA HEREBY AGREES TO
INDEMNIFY, DEFEND AND HOLD PEC AND ITS DIRECTORS, OFFICERS,
EMPLOYEES AND AGENTS HARMLESS FROM AND AGAINST ANY AND
ALL LOSS, LIABILITY, CLAIM, DAMAGE, COST OR EXPENSE
(INCLUDING REASONABLE LEGAL FEES AND EXPENSES)ARISING OUT
OF OR IN CONNECTION WITH THE DESIGN, ENGINEERING OR
CONSTRUCTION OF THE WATER PROJECT OR ENTRY ONTO THIRD-
PARTY PROPERTY IN CONNECTION WITH THE WATER PROJECT OR
WITH RESPECT TO ANY EASEMENT ACQUISITION FOR, THE
TEMPORARY POWER PROJECT.
b. BCRUA does not assume any Iiability for any property damage, injuries or death
in connection with the construction of the Temporary Power Project or entry onto
third-party property in connection with the construction of the Temporary Power
Project or upon written acceptance of PEC of the final design of the Temporary
Power Project, the design and engineering of the Temporary Power Project. TO
6
THE EXTENT PERMITTED BY LAW, PEC HEREBY AGREES TO
INDEMNIFY, DEFEND AND HOLD BCRUA AND ITS DIRECTORS,
OFFICERS,EMPLOYEES AND AGENTS HARMLESS FROM AND AGAINST
ANY AND ALL LOSS, LIABILITY, CLAIM, DAMAGE, COST OR EXPENSE
(INCLUDING REASONABLE LEGAL FEES AND EXPENSES)ARISING OUT
OF OR IN CONNECTION WITH THE CONSTRUCTION OF THE
TEMPORARY POWER PROJECT OR ENTRY ONTO THIRD-PARTY
PROPERTY IN CONNECTION WITH THE CONSTRUCTION OF THE
TEMPORARY POWER PROJECT OR UPON ITS WRITTEN ACCEPTANCE
OF THE FINAL DESIGN OF THE TEMPORARY POWER PROJECT, THE
DESIGN AND ENGINEERING OF THE TEMPORARY POWER PROJECT.
c. Subject to Section 17 below, nothing herein this Agreement shall be deemed to
waive, modify or alter to any extent any defense or immunity available at law or in
equity to BCRUA or PEC, or their past or present officers, employees, or agents,
nor to create any legal rights or claim on behalf of any non-party.
15. Term. The term of this Agreement is for a period of three years from the Effective Date
unless otherwise earlier terminated by the parties.
16. Entire Agreement. This Agreement represents and contains the entire agreement and
understanding between the parties with respect to the subject matter herein and supersedes
any and all prior or contemporaneous oral and/or written agreements and understandings.
17. Governing Law. This Agreement shall be construed and enforced in accordance with
Texas law. The Parties acknowledge that Subchapter 1, Chapter 271 of the Texas Local
Government Code is a legislative waiver of any sovereign immunity with respect to this
Agreement, and each City waives immunity to suit for the purpose of adjudicating any
claims under this Agreement. Venue for the litigation of any dispute arising hereunder
shall be in Williamson County, Texas.
18. Counterparts.This Agreement may be executed in any number of counterparts,and it will
not be necessary.
Executed to be effective this day of , 2019(the "Effective Date").
SIGNATURES ON FOLLOWING PAGES
7
PEDERNALES ELECTRIC COOPERATIVE, INC.
By:
Julie C. Parsley, Chief Executive Officer
Date:
BRUSHY CREEK REGIONAL UTILITY AUTHORITY, INC.
By:
Andrea Navarrette, President
Date:
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TECHNICAL MEMORANDUM 2-7
Date: June 5, 2018 � QL
Project: Nameless Substation Evaluation
enwascortue
To: SCRUA Design Oversight Committee
From: M&S Engineering I Brian Meuth, P.E. �I
NAMELESS SUBSTATION EVALUATION
1.0 PURPOSE
The purpose of this technical memorandum is to generally describe the three options being
considered for the Nameless Substation Expansion. Nameless Substation is owned by Pedernales
Electric Cooperative(PEC). The substation needs to be expanded in order to serve the electrical
needs of the Brushy Creek Regional Utility Authority(BCRUA)deep water Intake facility on Lake
Travis.
2.0 BACKGROUND
M&S Engineering conducted an evaluation of upgrade alternatives whose results were presented in
Technical memorandum 12-1(TM 12-1),dated June 1,2016. TM 12-1 recommended the Nameless
Substation Expansion(along with associated Nameless Route 1 distribution line)which was selected
by BCRUA.
3.0 INTRODUCTION
3.1 Nameless.Srr6shrtion t:xistbt CnrrQteratian
The existing substation layout is shown in Exhibit 1. The total property owned is shown along with
the existing substation fence that encloses the existing substation. The substation is fed by two 138
kV transmission lines. The line from the south originates at Lago Vista Substation and the line to the
north originates at Leander Substation as indicated in Exhibit 1. The 138 kV equipment in the
substation is generally described as follows:
• Both lines land on a common deadend structure.
• There are two 138 kV circuit breakers that provide protection to the 138 kV transmission
lines(breaker 14030 protects the Leander line and breaker 19020 protects the Lago Vista
line)and 138 kV bus protection.
• There are two 138/25 kV transformers(each with its own protective device)and associated
distribution bays that each separately tap the bus loop in between the circuit breakers.
EXHIBIT Cimas Parkway,sults 150,Austin,Tx 78746
No.8053 1 TBPLs Registration No,10032500
-2— June 5,2018
As stated above the circuit breakers electrically protect the bus and the transmission lines. The
existing configuration Is such that if a fault occurs on any of the bus in between breakers 19030 and
19020 both of these breakers will trip to Isolate this faulted section of bus. In this event both
transformers would be de-energized until the fault could be cleared and the bus restored to service.
3.2 Option rfor the F4aurion
The options for expansion as identified by PEC are Options 1,2 and 3 and are illustrated in Exhibits 2,
3 and 4 respectively.
3.2.1 Option 1
Option 1 is illustrated In Exhibit 2. Option 1 does not require additional land to be procured. In this
option the unused property owned by PEC to the north of the existing northernmost substation
fence would be utilized to accommodate some of the additional equipment.
The 138 kV equipment shown in the dotted box could effectively be reused with the deadend to land
the southern transmission line. The two existing breakers could remain In place,along with small
portions of the existing bus. Note that the northern transmission line source would be relocated
onto a new deadend. Option 11s generally described as a modified ring bus configuration in that
each source(138 kV line)or load(transformer tap)is sectionalized by a circuit breaker on either side
-with the exception of transformer 1 and the Logo Vista line. New 138 kV breakers are added on
either side of the new transformer(noted as transformer 3). The addition of these two breakers
compartmentalizes the taps for transformers 2 and 3. As stated above the Logo Vista line to the
south would share a tap location with a transformer 1. Both the existing transformers would have to
be relocated and reoriented along with their respective distribution bays. The control house would
be replaced and relocated and new transformer 3 to feed the BCRUA intake facility would be pointed
to the east. Transformer 3 would feed an enclosed metal clad switchgear(metal clad switch gear is a
more compact alternative to typical outdoor bay construction)via an underground feed and the
control house would be to the north.
3.2.2 Option 2
Option 2 is illustrated in Exhibit 3 and is rather like Option 1 with the exception that the new
transformer is oriented to the north and the control house is to the east. The modified ring bus
configuration(as Illustrated In Options 1 and Option 2)improves the load protection relative to the
existing layout in case of a bus fault In that only one tap would be removed from service in the event
of a bus fault. Again note that the Logo Vista line and transformer 1 share a tap location.
3.23 Option 3
Option 3 is illustrated in Exhibit 4. For this option 100 feet of additional land to the east and 70 feet
to the north will be required beyond the existing fence. In this layout the existing deadend and
southern transmission line(Logo Vista),the existing breakers 19020,and the existing transformer 1
with its associated distribution bay remain in their current locations(as shown in the dotted box).
Electrically this option is a true ring bus in that each tap or source is compartmentalized by breakers.
The bus loop is elongated to the east where circuit breakers and an additional transformer tap
location are added for the relocated transformer and associated distribution bay. That is,they no
longer would both be removed from service for a single bus fault. In comparison to the other two
options,this layout uses more of the existing equipment without the necessity of relocation. The
-3— June 5,2018
drawback is that additional property is required to the east and north. Further note that a dry creek
currently runs along the eastern side of the substation and this would have to be accommodated.
The assessment of the civil engineering aspects of this required additional land encroaching into the
creek is beyond the scope of this memorandum.
4.0 BREAKDOWN OF OPTIONS
In the following sections each option is discussed Individually and an engineer's opinion of probable
cost is presented for each of three components;civil,transmission and substation.
4.1 Option 1
The costs associated with the components of this option are roughly itemized in Exhibit 5.
4.1.1 Civil
The unused portion of land owned by PEC that will be used for this option Is trapezoidal in shape and
is located to the north of the existing substation site(See Exhibit 1). The drainage was assumed to
be northeastern in direction. It was assumed that the southwestern corner of the trapezoidal land
section was 8"lower in grade than the northwestern portion of the existing substation area. As the
drainage is to the northeast,the entire site would be filled to the usable limits. For this portion of
land to be maximized,a retaining wall would be planned along the eastern and northern faces
(where applicable)of the new/relocated substation fence.
4.1.2 Transmission
The north circuit is relocated onto a new deadend that taps the modified ring bus. The layout
concept is that the circuit would originate at the deadend and proceed approximately 200 feet to the
north,then turn 90 degrees west and proceed to a point where another pole would be located that
would be in the northern trapezoidal property and back in line with the original transmission line
right of way and route. Therefore,for the purposes of the transmission line,no additional property
or easements are required. This idea is predicated on the assumption that the existing deadend will
adequately handle the loads for a single circuit pulling to the south.
The transmission upgrades are summarized by the addition of two new self-supporting anchor
bolted steel mono-pole ninety-degree dead ends and their associated foundations,along with the
corresponding wire work. The transmission conductor will remain unchanged as 795 ACSR.
4.1.3 Substation
The substation changes are as Illustrated in Exhibit 2 and as generally described in the Option 1
description above. Note that the control building will be replaced with a new control building in a
new location. Transformer 3 will be the northern most transformer and will feed a metal clad
switchgear rather than an outdoor distribution bay. Note that the southernmost transformer and
the southern transmission line are protected by the same breakers.
4.2 Option 2
The costs associated with the components of this option are roughly itemized in Exhibit 5.
4.2.1 Civil.and Transmission
The civil and transmission components and associated costs are identical to Option 1.
-4— June 5,2418
4.2.2 Substation
This option is similar to option 1 with the exception of the control house location and the orientation
of the third transformer.
4.3 Option 3
The costs associated with the components of this option are roughly Itemized In Exhibit 5.
4.3.1 Civil
A cost estimate was generated by a third party under contract with PEC. The work product delivered
by PEC including a cost estimate,civil layout,and property boundary is attached as Appendix A. The
land acquisition cost for this option has been estimated by BCRUXs land agent,Lori Bible with Cobb
Fendley.
4.3.2 Transmission
The transmission components and associated costs are identical to Options 1 and 2.
4.3.3 Substation
This option elongates the bus loop to the east and effectively uses more of the existing facilities than
Options 1 and Option 2 as shown in the dotted box on Exhibit 4. However,the additional land
required to the east will result in major civil design effort. Also note In this option that no metal clad
switchgear Is required for the distribution bay of the third transformer. Finally,this layout provides
better load segregation with all three transformer taps and line sources being compartmentalized by
breakers.
5.0 Cost Summary
Table 1 summarizes the total estimated costs for each option.
Table 1—Nameless Substation Expansion Cost Summary
Option Total Estimated Cost
1 $6,979,470
2 $6,901,015
3 $8,754,011
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ORIGINAL EXECUTED DOCUMENT
TO FOLLOW. . .
AGREEMENT REGARDING PHASE 2
OF THE BCRUA'S
REGIONAL WATER TREATMENT AND TRANSMISSION SYSTEM
(TEMPORARY POWER PROJECT)
This Agreement("Agreement") is entered into by and between the Brushy Creek Regional Utility
Authority, Inc. ("BCRUA"), a local government corporation composed of the Texas home-rule
cities of Cedar Park, Leander,and Round Rock(individually,the"City"; collectively,the"Cities")
and Pedernales Electric Cooperative, Inc. ("PEC"), a Texas electric cooperative corporation
formed under Chapter 161 of the Texas Utilities Code.
RECITALS
WHEREAS, BCRUA was created by the Cities to design,construct and operate a regional
water transmission and treatment system to provide the Cities with drinking water; and
WHEREAS, BCRUA has completed Phase 1 A of the regional system including a floating
raw water pump station located on Lake Travis, a water treatment plant located in Cedar Park,and
associated transmission pipelines; and
WHEREAS, Phase 2 of the BCRUA regional system is required to meet fixture water
demands for the Cities and to provide a dependable method of accessing water from Lake Travis
during times of severe drought; and
WHEREAS, the Phase 2 water project consists of a deep-water intake and maintenance
building located within the Village of Volente, a pump station located adjacent to the Lower
Colorado River Authority Sandy Creek Park,and tunneled water conveyance pipelines(the"Water
Project"); and
WHEREAS,the Water Project is located within the PEC service area and requires electric
distribution upgrades, improvements, and line extensions ("Electric Project") and upgrades and
expansion of the FEC Nameless Substation ("Substation Project") across certain parcels in
Williamson and Travis Counties, Texas; and
WHEREAS, the Water Project,the Electric Project and Substation Project include various
phases; and
WHEREAS, BCRUA has completed preliminary design of the Water Project and
commenced easement acquisition for the Water Project and the Phase 2 Electric Project -
Temporary Power, hereinafter referred to as the "Temporary Power Project", (as defined herein);
and
WHEREAS, for the last two years BCRUA has relied on preliminary design and routing
recommendations produced by M&S Engineering, Inc. ("M&S")and reviewed and accepted for
purposes of preliminary routing by PEC and serve as the basis for the ongoing easement acquisition
program; and
00422448.DOCX:sls
WHEREAS, the initial phase of the Electric Project includes (a) providing temporary
electric service to BCRUA's contractor in order for such contractor to construct a portion of the
Water Project and (b) relocating the electric facilities at the pump station site (collectively,
"Temporary Power Project"), each of which is expected to be completed by March 31, 2021 and
prior to commencement of construction of the Water Project; and
WHEREAS, all remaining phases of the Electric Project and Substation Project must be
completed prior to commissioning and final acceptance of the Water Project.
NOW, THEREFORE, in consideration of the foregoing premises and the mutual
covenants and agreements herein contained, BCRUA, the Cities, and PEC agree as follows:
1. Temporary Power Project. This Agreement mainly addresses the Temporary Power
Project requirements and responsibilities. The parties acknowledge that other phases of
the Electric Project and the Substation Project to serve the Water Project will require
additional agreements between the parties. The Temporary Power Project is expected to
serve a load of up to 5 MVA.
2. Preliminary Design. The preliminary design of the Temporary Power Project has been
completed along the designated route from 1431 along Trails End Road to the Water
Project pump station on Lime Creek Road ("Preliminary Design") and is based on the
currently known route and PEC specifications and is attached on Exhibit A hereto and
incorporated herein. The Preliminary Design route is subject to any changes that may arise
due to easement acquisitions for the Temporary Power Project. It is anticipated that the
portion of the Water Project requiring the Temporary Power Project will be served from
the existing FEC Nameless Substation.
3. Easement Acquisition.
a. BCRUA and M & S have previously delivered preliminary routing maps of the
entire Water Project and the Temporary Power Project to PEC that detail the
affected landowners and properties. PEC has existing easement rights for its
existing facilities. The parties acknowledge that AEC had no immediate plans to
upgrade these facilities. While some of these existing easements may permit the
Temporary Power Project, the parties acknowledge that some of these easements
are likely not sufficient for the upgrade of the existing facilities for the Temporary
Power Project.
b.
To the extent that the existing easements are not sufficient for the Temporary Power
Project, BCRUA and its member Cities will be responsible for the acquisition of
the easements and right of way necessary for the Temporary Power Project.
However, to the extent that the Temporary Power Project additionally provides
upgrades to the PEC electric system, PEC shall be responsible for 50% of the
administrative costs relating to surveying, researching and updating easements for
the Temporary Power Project, but PEC's cost shall not exceed $50,000.00. PEC
acknowledges and agrees that BCRUA's acquisition of easements or right of way
for the Temporary Power Project are required to serve a portion of the Water
Project, and are for the construction, maintenance and operation of the Temporary
Power Project for a portion of the Water Project which is to be undertaken as a
public benefit. PEC acknowledges that BCRUA through its member Cities may
utilize eminent domain and condemnation proceedings to acquire the needed
easements. Easements acquired by BCRUA and its member Cities pursuant to this
Section 3 shall either be granted directly to PEC or assigned or otherwise
transferred to PEC by the condemning authority at no cost to FEC, other than the
contribution described in this Section 3. To the extent that eminent domain and
condemnation proceedings must be used to obtain any easement or right of way,
the BCRUA through its member Cities agrees to comply with all applicable laws
for the use of any eminent domain authority. AEC acknowledges that easement
acquisition and the potential associated use of eminent domain and condemnation
is being completed in order for PEC to serve a portion of the Water Project which
is expected to benefit residents in certain cities for which PEC provides electric
service.
C.
PEC agrees to cooperate with BCRUA's and its contractor's efforts to obtain
easements for the Temporary Power Project to serve a portion of the Water Project,
and further, BCRUA and its consultants, with PEC's cooperation, shall respond to
property owner questions and comments as required. With respect to such
cooperation PEC shall be responsible for no more than $50,000 of the
administrative costs relating to researching existing easements, reviewing design
locations for facilities for the Temporary Power Project and comparing designs to
existing easements. BCRUA acknowledges that PEC may retain outside
consultants to assist PEC in these efforts, and such expenditures by PEC to third-
parties shall be deducted from the $50,000.
4. Final Design. BCRUA and PEC agree to work cooperatively to implement final design of
the Temporary Power Project according to the following allocation of responsibilities:
a. Final Design Tasks wish BCRUA in Lead Role. BCRUA agrees to lead design of
the Water Project and Temporary Power Project. BCRUA agrees to maintain a
contract with M & S to complete final design of the Temporary Power Project.
BCRUA agrees to provide a final design of the Temporary Power Project in
segments or phases for PEC's review.
b. Final Design Tasks with PEC in Lead Role. PEC agrees to review,comment, and
provide written final design acceptance of final design of the Temporary Power
Project provided by BCRUA or its consultant assuming such designs meet PEC's
system requirements and specifications. Upon written final design acceptance of
the Temporary Power Project by PEC and provided no further design changes are
required, BCRUA will no longer have any responsibility as to securing the design
and engineering of the Temporary Power Project.
3
5. Construction. To the extent that any easement acquisition or any condemnation
proceeding or litigation proceeding delays or stops construction of the Temporary Power
Project, BCRUA shall be responsible for any demobilization costs assessed by the
contractor or consultant against PEC and any resulting re-mobilization costs assessed by
the contractor or consultant. It is anticipated that construction of the Temporary Power
Project may involve multiple construction contracts that are awarded at different times
based on the schedule requirements of the Water Project. As to the Temporary Power
Project, PEC intends to use PEC approved contractors for the construction. BCRUA
acknowledges that PEC is the sole certificated provider of electric distribution services in
the territory in which the Temporary Power Project is to be constructed.
G. Permitting. BCRUA agrees to obtain all applicable permits as required for construction
and any necessary vegetation management, including any permit required by the Balcones
Canyonland Conservation Plan for the portion of the Water Project to be served by the
Temporary Power Project. To the extent that any permitting requirements delays or stops
construction of the Temporary Power Project, BCRUA shall be responsible for any
demobilization costs assessed by the contractor or consultant against PEC and any resulting
re-mobilization costs assessed by the contractor or consultant against PEC. BCRUA further
agrees to submit the requisite service applications to PEC for project commencement.
7. Payment and Costs.
a. PEC anticipates providing cost estimates to BCRUA in phases for costs of the
construction of the Temporary Power Project. The cost estimates will generally
include costs for labor and materials and associated overheads for the design and
construction for all components, including any costs for vegetation management,
of the Temporary Power Project necessary to support this portion of the Water
Project. The initial cost estimate for construction is expected to include the costs
of vegetation management for the Temporary Power Project. Within forty-five(45)
days prior to commencement of the initial phase of construction of the Temporary
Power Project, PEC shall notify BCRUA of the estimated costs of labor and
materials required for that phase of the Temporary Power Project. Upon receipt of
a cost estimate, BCRUA agrees to pay PEC the estimated costs for labor and
materials and associated overheads included therein in advance prior to PEC
commencing that phase of construction. To the extent that PEC has not received
payment by BCRUA for any phase prior to construction of that phase, PEC shall
not proceed with the Temporary Power Project, and BCRUA shall be responsible
for any demobilization costs assessed by the contractor or consultant against PEC
and any resulting re-mobilization costs assessed by the contractor or consultant.
BCRUA acknowledges that this Agreement does not address any costs for other phases
of the Electric Project or Substation Project.
b. Any changes to the routing or design of any segment or phase of the Temporary
Power Project after DEC's acceptance may affect costs. PEC agrees to bear any
4
additional costs resulting from any changes by PEC to the routing or design to
accommodate DEC's system improvements or to provide supplemental benefits to
PEC. BCRUA agrees to bear any additional costs from changes to the routing or
design not associated with PEC system improvements or not providing
supplemental benefits to PEC.
c. Costs of the Temporary Power Project submitted to the BCRUA shall be in
accordance with the Tariff and Business Rules of PEC in effect as of the date of
construction.
d. Pursuant to the existing Tariff and Business Rules of FEC, PEC shall exercise
prudent judgment in determining the conditions under which a specific overhead
line extension will be made and shall view each case individually and with terms
and conditions deemed reasonable by PEC. All amounts paid to PEC as
contribution in aid of construction shall be non-refundable.
8. Communication. BCRUA and PEC agree to hold periodic project status information
meetings. PEC's official point of contact for the Temporary Power Project is the Cedar
Park Electrical Distribution Design & Planning Manager. BCRUA's official point of
contact is the BCRUA General Manager. BCRUA and PEC agree to include these
designated points of contact in the chain of communication for all significant decisions and
recommendations prepared by design engineers and other parties and representatives.
9. Schedule. The current Water Project schedule anticipates that the Temporary Power
Project be completed no later than March 31, 2021. Design and construction of the
Temporary Power Project is expected to take approximately 18 months. The parties
acknowledge that the timeframe is estimated and is subject to receipt of the necessary
easements as described herein and any other land rights and applicable permits for the
Temporary Power Project prior to construction commencing for the Temporary Power
Project, each to be obtained by BCRUA. Notwithstanding the inclusion of a date for the
energization of the Temporary Power Project, PEC shall not be liable for any failure to
meet any service date contained herein.
10. Substation Project. The parties agree that the Nameless Substation requires a redesign to
include additional capacity in order to serve the completed Water Project expected in 2025.
The preliminary designs for the Nameless Substation redesign options are included as
Exhibit B attached hereto and incorporated herein. Selection of a redesign option will be
determined no later than November 30, 2020 to allow BCRUA to prepare funding
applications.
11. Power Supply Redundancy. The Water Project requires a level of power supply
redundancy for the health of the citizens served by the BCRUA and its member Cities.
When the completed Water Project is in service (expected in 2025), the existing City of
Cedar Park, City of Leander and BCRUA floating raw water intake facilities will be
decommissioned. Upon completion of the Water Project,the parties acknowledge that the
BCRUA wishes to reserve capacity in substation and feeders. To reserve substation and
feeder capacity up to a connected load of 7,800 horsepower with a maximum single motor
5
size of approximately 3,600 horsepower on a VFD starter, PEC shall require a payment in
accordance with its Tariff and Business Rules then in effect.
12. Rates for Temporary Power. The rates for the portion of the Water Project to be served
by the Temporary Power Project will be in accordance with the conditions of the Tariff and
Business Rules of PEC then in effect as of the date of energization of the Temporary Power
Project. At least 6 months prior to energization, BCRUA shall provide the load profile for
the portion of the Water Project to be served by the Temporary Power Project, and PEC
will evaluate such profile and conduct any cost of service studies to determine if the Large
Power customer classification under the existing Tariff and Business Rules of PEC with an
expected demand of more than 75kW but less than 10,000 kW would apply to the
Temporary Power Project.
13. Compliance with Laws.
a. During the term of the Agreement, the parties will perform in compliance,
conformance, and accordance with all applicable laws, rules, and regulations of
the United States, and of any state or political subdivision thereof.
b. In accordance with Chapter 2270,Texas Government Code,a governmental entity
may not enter into a contract with a company for goods or services unless the
contract contains written verification from the company that it: (1)does not boycott
Israel; and (2) will not boycott Israel and will not boycott Israel during the term of
this contract. The signatory executing this Agreement on behalf of Vendor verifies
Vendor does not boycott Israel and will not boycott Israel during the term of this
Agreement.
14. Liability; No Waiver of Immunities.
a. PEC does not assume any liability for any property damage, injuries or death in
connection with the design, engineering or construction of the Water Project or
entry onto third-party property in connection with the Water Project or with respect
to any easement acquisition by BCRUA for the Temporary Power Project. TO THE
EXTENT PERMITTED BY LAW, BCRUA HEREBY AGREES TO
INDEMNIFY, DEFEND AND HOLD PEC AND ITS DIRECTORS, OFFICERS,
EMPLOYEES AND AGENTS HARMLESS FROM AND AGAINST ANY AND
ALL LOSS, LIABILITY, CLAIM, DAMAGE, COST OR EXPENSE
(INCLUDING REASONABLE LEGAL FEES AND EXPENSES)ARISING OUT
OF OR IN CONNECTION WITH THE DESIGN, ENGINEERING OR
CONSTRUCTION OF THE WATER PROJECT OR ENTRY ONTO THIRD-
PARTY PROPERTY IN CONNECTION WITH THE WATER PROJECT OR
WITH RESPECT TO ANY EASEMENT ACQUISITION FOR, THE
TEMPORARY POWER PROJECT.
b. BCRUA does not assume any liability for any property damage, injuries or death
in connection with the construction of the Temporary Power Project or entry onto
third-party property in connection with the construction of the Temporary Power
Project or upon written acceptance of PEC of the final design of the Temporary
Power Project, the design and engineering of the Temporary Power Project. TO
6
THE EXTENT PERMITTED BY LAW, PEC HEREBY AGREES TO
INDEMNIFY, DEFEND AND HOLD BCRUA AND ITS DIRECTORS,
OFFICERS, EMPLOYEES AND AGENTS HARMLESS FROM AND AGAINST
ANY AND ALL LOSS, LIABILITY, CLAIM, DAMAGE, COST OR EXPENSE
(INCLUDING REASONABLE LEGAL FEES AND EXPENSES)ARISING OUT
OF OR IN CONNECTION WITH THE CONSTRUCTION OF THE
TEMPORARY POWER PROJECT OR ENTRY ONTO THIRD-PARTY
PROPERTY IN CONNECTION WITH THE CONSTRUCTION OF THE
TEMPORARY POWER PROJECT OR UPON ITS WRITTEN ACCEPTANCE
OF THE FINAL DESIGN OF THE TEMPORARY POWER PROJECT, THE
DESIGN AND ENGINEERING OF THE TEMPORARY POWER PROJECT.
c. Subject to Section 17 below, nothing herein this Agreement shall be deemed to
waive, modify or alter to any extent any defense or immunity available at law or in
equity to BCRUA or PEC, or their past or present officers, employees, or agents,
nor to create any Iegal rights or claim on behalf of any non-party.
15.Term. The term of this Agreement is for a period of three years from the Effective Date
unless otherwise earlier terminated by the parties.
16. Entire Agreement. This Agreement represents and contains the entire agreement and
understanding between the parties with respect to the subject matter herein and supersedes
any and all prior or contemporaneous oral and/or written agreements and understandings.
17. Governing Law. This Agreement shall be construed and enforced in accordance with
Texas law. The Parties acknowledge that Subchapter 1, Chapter 271 of the Texas Local
Government Code is a legislative waiver of any sovereign immunity with respect to this
Agreement, and each City waives immunity to suit for the purpose of adjudicating any
claims under this Agreement. Venue for the litigation of any dispute arising hereunder
shall be in Williamson County, Texas.
18. Counterparts.This Agreement may be executed in any number of counterparts,and it will
not be necessary.
Executed to be effective thio4day of , 2019 (the"Effective Date").
SIGNATURES ON FOLLOWING PAGES
PEDE AL F O ERATIVE, INC.
By:
ie Pa ley, Chief Exec tive Officer
Date:
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BR Y CR E ONAL UTILITY AUTHORITY, INC.
B .
Andrea Navarrette, President
Date: —
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TECHNICAL MEMORANDUM 2-7
Date: June 5, 2018
Project: Nameless Substation Evaluation i
IMAN Scott Mt
WWI
To: BCRUA Design Oversight Committee Ix 1%
From: M&S Engineering Brian Meuth, P-E_ 5i B
NAMELESS SUBSTATION EVALUATION
1.0 PURPOSE
The purpose of this technical memorandum is to generally describe the three options being
considered for the Nameless Substation Expansion. Nameless Substation is owned by Pedernales
Electric Cooperative(PEC). The substation needs to be expanded in order to serve the electrical
needs of the Brushy Creek Regional Utility Authority(BCRUA)deep water intake facility on Labe
Travis.
2.0 BACKGROUND
M&S Engineering conducted an evaluation of upgrade alternatives whose results were presented in
Technical memorandum 12-1(TM 12-1),dated June 1,2016. TM 12-1 recommended the Nameless
Substation Expansion(along with associated Nameless Route 1 distribution line)which was selected
by BCRUA.
3.0 INTRODUCTION
3.1 Namelerr Substation Exifling Corrfrguralien
The existing substation layout is shown in Exhibit 1. The total property owned is shown along with
the existing substation fence that encloses the existing substation. The substation is fed by two 138
kV transmission lines. The line from the south originates at Lago Vista Substation and the line to the
north originates at Leander Substation as indicated In Exhibit 1. The 138 kV equipment in the
substation is generally described as follows;
• Both lines land on a common deadend structure.
• There are two 138 kV circuit breakers that provide protection to the 138 kV transmission
lines(breaker 19430 protects the Leander line and breaker 19020 protects the Lago Vista
line)and 138 kV bus protection.
• There are two 138/25 kV transformers(each with its own protective device)and associated
distribution bays that each separately tap the bus loop in between the circuit breakers.
E::I
Cimas Parkway,Suite 150,Austin,TX 78746
No.8053 1 TBPLS Registration No.10032500
-2— June 5,2018
As stated above the circuit breakers electrically protect the bus and the transmission lines. The
existing configuration is such that if a fault occurs on any of the bus in between breakers 19030 and
19020 both of these breakers will trip to isolate this faulted section of bus. In this event both
transformers would be de-energized until the fault could be cleared and the bus restored to service.
3.2 0,bdons for the Expansion
The options for expansion as identified by PEC are Options 1,2 and 3 and are illustrated in Exhibits 2,
3 and 4 respectively.
3.2.1 Option 1
Option 1 Is illustrated in Exhibit 2. Option 1 does not require additional land to be procured. In this
option the unused property owned by FEC to the north of the existing northernmost substation
fence would be utilized to accommodate some of the additional equipment.
The 138 kV equipment shown in the dotted box could effectively be reused with the deadend to land
the southern transmission line. The two existing breakers could remain In place,along with small
portions of the existing bus. Note that the northern transmission line source would be relocated
onto a new deadend. Option 1 is generally described as a modified ring bus configuration in that
each source(138 kV line)or load (transformer tap)is sectionalized by a circuit breaker on either side
—with the exception of transformer 1 and the Lago Vista line. New 138 kV breakers are added on
either side of the new transformer(noted as transformer 3). The addition of these two breakers
compartmentalizes the taps for transformers 2 and 3. As stated above the Lago Vista line to the
south would share a tap location with a transformer 1. Both the existing transformers would have to
be relocated and reoriented along with their respective distribution bays. The control house would
be replaced and relocated and new transformer 3 to feed the BCRUA intake facility would be pointed
to the east. Transformer 3 would feed an enclosed metal clad switchgear(metal clad switch gear is a
more compact alternative to typical outdoor bay construction)via an underground feed and the
control house would be to the north.
3.2.2 Option 2
Option 2 Is illustrated in Exhibit 3 and is rather like Option 1 with the exception that the new
transformer Is oriented to the north and the control house is to the east. The modified ring bus
configuration(as illustrated in Options 1 and Option 2)improves the load protection relative to the
existing layout in case of a bus fault in that only one tap would be removed from service in the event
of a bus fault. Again note that the Lago Vista line and transformer 1 share a tap location.
3.2.3 Option 3
Option 3 is illustrated in Exhibit 4. For this option 100 feet of additional land to the east and 70 feet
to the north will be required beyond the existing fence. In this layout the existing deadend and
southern transmission line(Lago Vista),the existing breakers 19020,and the existing transformer 1
with its associated distribution bay remain In their current locations(as shown in the dotted box).
Electrically this option is a true ring bus In that each tap or source is compartmentalized by breakers.
The bus loop is elongated to the east where circuit breakers and an additional transformer tap
location are added for the relocated transformer and associated distribution bay. That is,they no
longer would both be removed from service for a single bus fault. In comparison to the other two
options,this layout uses more of the existing equipment without the necessity of relocation. The
-3- June 5,2418
drawback is that additional property is required to the east and north. Further note that a dry creek
currently runs along the eastern side of the substation and this would have to be accommodated.
The assessment of the civil engineering aspects of this required additional land encroaching into the
creek is beyond the scope of this memorandum.
4.0 BREAKDOWN OF OPTIONS
In the following sections each option is discussed individually and an engineer's opinion of probable
cost is presented for each of three components;civil,transmission and substation.
4.1 Operon 1
The costs associated with the components of this option are roughly itemized in Exhibit 5.
4.1.1 Civil
The unused portion of land owned by PEC that will be used forthis option is trapezoidal in shape and
is located to the north of the existing substation site(See Exhibit 1). The drainage was assumed to
be northeastern in direction. It was assumed that the southwestern corner of the trapezoidal land
section was 8"lower in grade than the northwestern portion of the existing substation area. As the
drainage Is to the northeast,the entire site would be filled to the usable limits. For this portion of
land to be maximized,a retaining wall would be planned along the eastern and northern faces
(where applicable)of the new/relocated substation fence.
4.1.2 Transmission
The north circuit Is relocated onto a new deadend that taps the modified ring bus. The layout
concept is that the circuit would originate at the deadend and proceed approximately 200 feet to the
north,then turn 90 degrees west and proceed to a point where another pole would be located that
would be in the northern trapezoidal property and back in line with the original transmission line
right of way and route. Therefore,for the purposes of the transmission line,no additional property
or easements are required. This Idea is predicated on the assumption that the existing deadend will
adequately handle the loads for a single circuit pulling to the south.
The transmission upgrades are summarized by the addition of two new self-supporting anchor
bolted steel mono-pole ninety-degree dead ends and their associated foundations,along with the
corresponding wire work. The transmission conductor will remain unchanged as 795 ACSR.
4.1.3 Substation
The substation changes are as illustrated in Exhibit 2 and as generally described in the Option 1
description above. Note that the control building will be replaced with a new control building in a
new location. Transformer 3 will be the northern most transformer and will feed a metal clad
switchgear rather than an outdoor distribution bay. Note that the southernmost transformer and
the southern transmission line are protected by the same breakers.
4.2 option 2
The costs associated with the components of this option are roughly itemized in Exhibit 5.
4.2.1 Civil and Transmission
The civil and transmission components and associated costs are identical to Option 1.
-4- June 5,2018
4.2.2 Substation
This option is similar to option 1 with the exception of the control house location and the orientation
of the third transformer.
4.3 Option 3
The costs associated with the components of this option are roughly itemized In Exhibit S.
4.3.1 Civil
A cost estimate was generated by a third party under contract with PEC. The work product delivered
by PEC including a cost estimate,civil layout,and property boundary is attached as Appendix A. The
land acquisition cost for this option has been estimated by BCRUA's land agent,Lori Bible with Cobb
Fendley.
4.3.2 Transmission
The transmission components and associated costs are identical to Options 1 and 2.
4.3.3 Substation
This option elongates the bus loop to the east and effectively uses more of the existing facilities than
Options 1 and Option 2 as shown in the dotted box on Exhibit 4. However,the additional land
required to the east will result in major civil design effort. Also note In this option that no metal clad
switchgear is required for the distribution bay of the third transformer. Finally,this layout provides
better load segregation with all three transformer taps and line sources being compartmentalized by
breakers.
5.0 Cost Summary
Table 1 summarizes the total estimated costs for each option.
Table 1—Nameless Substation Expansion Cost Summary
Option Total Estimated Cost
1 $6,979,470
2 $6,901,015
3 $8,754,011
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