DESERT SOUTHWEST REGION TEN-YEAR PLAN Customer … · 1 desert southwest region ten-year plan customer preview meeting fiscal year 2018-2027 mid-cycle customer meeting: june 7, 2017

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DESERT SOUTHWEST REGION

TEN-YEAR PLAN

Customer Preview Meeting

Fiscal Year 2018-2027

MID-CYCLE CUSTOMER MEETING: JUNE 7, 2017

DESERT SOUTHWEST REGIONAL OFFICE 615 S. 43RD AVE

PHOENIX, AZ

POWERING THE ENERGY FRONTIER

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TABLE OF CONTENTS

TAB #1 - WELCOME

MEETING AGENDA .......................................................................................................................... 3

TABLE OF ACRONYMS ................................................................................................................... 4

TAB #2 - SOUTHLINE PROJECT

SOUTHLINE PROJECT...................................................................................................................... 5

TAB #3 - PROCESS IMPROVEMENTS

CUSTOMER TECHNICAL COMMITTEE ........................................................................................ 7

BUDGET FLOW CHART ................................................................................................................... 8

10 YEAR PLAN PROCESS FLOW CHART ..................................................................................... 9

SEED FUNDING FLOW CHART .................................................................................................... 10

TAB #4 - 10 YEAR PLAN PREVIEW

GILA-WELLTON MOHAWK INTERSTATE-8 CROSSING REBUILD ...................................... 11

GILA 161KV SUBSTATION REBUILD 230KV ............................................................................ 14

PARKER-HEADGATE ROCK & PARKER-BOUSE T-LINE REROUTE .................................... 17

LAST YEARS 10 YEAR PLAN ....................................................................................................... 19

PROPOSED FY18-20 PROJECT STARTS ...................................................................................... 21

COOLIDGE-VALLEY FARMS 115KV TRANSMISSION LINE .................................................. 22

KOFA-DOME TAP 161KV TRANSMISSION LINE ...................................................................... 23

DOME TAP-GILA 161KV TRANSMISSION LINE ....................................................................... 29

BOUSE-KOFA 161KV TRANSMISSION LINE ............................................................................. 34

TAB #5 - ANALYSIS OF ALTERNATIVES (AoA) STUDIES

BLYTHE-PARKER #2 TRANSMISSION LINE ............................................................................. 39

TAB #6 - RRADs

REPLACEMENTS, RETIREMENTS, ADDITIONS, & DELETIONS (RRADs) ........................... 43TAB #7 - APPENDICES

APPENDICES .................................................................................................................................... 53

10 YEAR CAPITAL PLAN


0 YEAR CAPITAL PLAN

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MEETING AGENDA

Conference Call Bridge:

To access the conference call bridge, please dial (800)-283-2963; when requested enter

conference code number 27360 and then enter #. When requested provide your name.

Objective(s):

To preview and solicit feedback from Parker-Davis Project (P-DP) and Intertie Customers

on WAPA DSW’s draft 10-Year Capital Plan. Have an open exchange on the proposed

projects, emerging issues, and developments.

Agenda:

1. Welcome

a. Introduce Teresita Amaro, New Engineering-Construction Manager

2. Southline Project Update

3. 10 Year Plan Process Improvementsa. Customer Technical Committee (CTC)

b. Budget Flow Chartc. Process Flow Chart

d. Appropriated “Seed” Funding

e. Customer open discussion

4. 10 Year Plan Preview

a. Project Updates

• Customer open discussionb. Proposed FY18-20 Project Starts

• Customer open discussion5. Analysis of Alternatives (AoA) Studies

a. Customer open discussion6. FY17 Budget vs. Execution

a. Customer open discussion7. Replacements, Retirements, Additions, & Deletions (RRADs)

a. Customer open discussion8. Review Action Items

9. Next Steps

a. August, 2017 – TYP Presentation

b. October, 2017 – Prepayment Presentation & Vote


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TABLE OF ACRONYMS APS…………………………………….…………………………….ARIZONA PUBLIC SERVICE

BOR…………………………………...…………………………….BUREAU OF RECLAMATION

CAP…………………………………………………….………...CENTRAL ARIZONA PROJECT

CPC…………………………………………………………..CAPITAL PLANNING COMMITTEE

CTC……………………………………………………..CUSTOMER TECHNICAL COMMITTEE

CX………………………………………………...……………...….CATEGORICAL EXCLUSION

CIP……………………………………………..…CRITICAL INFRASTRUCTURE PROTECTION

DOE…………………………..………………………………..……..DEPARTMENT OF ENERGY

DSW……………………………..………………………….……DESERT SOUTHWEST REGION

EA………..……………………………………………………ENVIRONMENTAL ASSESSMENT

E&OC……………………………………………..ENGINEERING & OPERATING COMMITTEE

GFE…………….………………………….…………GOVERNMENT FURNISHED EQUIPMENT

IDIQ………………………………...……….INDEFINITE DELIVERY/INDEFINITE QUANTITY

JPA………………………………………………………………JOINT PLANNING AGREEMENT

KCMIL…………………………………………….……THOUSANDS CIRCULAR MILLIMETER

MDCC……………………………...MAINTENANCE DESIGN CONSTRUCTION COMMITTEE

NEPA…………………………….…………….....NATIONAL ENVIRONMENTAL POLICY ACT

NERC…………………..…….NORTH AMERICAN ELECTRIC RELIABILITY CORPORATION

NESC……………………………………………...……...NATIONAL ELECTRIC SAFETY CODE

NHPA…………………..…………………………NATIONAL HISTORIC PRESERVATION ACT

NRHP…………………..……………………..…NATIONAL REGISTER OF HISTORIC PLACES

OGW……………..…………………………………………………..OVERHEAD GROUND WIRE

O&M………………………………………………………..OPERATIONS AND MAINTENANCE

OPGW………………………………..…………………..OPTICAL OVERHEAD GROUND WIRE

PAD………………………………………………..……………………….PARKER SUBSTATION

PCB…………………………………………………………….POLYCHLORINATED BIPHENYL

PCN…………………………………….……………………………….….PRE-PAYMENT FUNDS

P-DP……………………………………………………….....…………PARKER-DAVIS PROJECT

ROW………………………………………………………………………………..RIGHT OF WAY

SCE………………………………………………...……...….SOUTHERN CALIFORNIA EDISON

SF6………………………………..………………………………….…SULFUR HEXAFLUORIDE

TYP……………………………………………………………………….……….TEN YEAR PLAN

WAPA……………………………………………WESTERN AREA POWER ADMINISTRATION

WCF………….……………………………………………..WESTERN CONSTRUCTION FUNDS

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SOUTHLINE PROJECT

Project Status

• Received comments from numerous P-DP Customers

– Support WAPA’s participation in the proposed Southline Transmission Project as

described

– Recognize significant benefits to WAPA Customers including improved reliability,

increased capacity, and substantial rate mitigation

– Agree that WAPA’s share of New Build capacity should be integrated as P-DP

capacity

– All of WAPA’s share of O&M costs belong in the P-DP transmission rate

– Need more information on firm commitments for Southline’ s capacity to assess

project’s economic viability

– Continue to include P-DP Customers in the process, appreciate WAPA’s efforts

• Executed a Preconstruction Agreement

– Provides for WAPA support of preconstruction activities (e.g., technical,

engineering, environmental)

– Does not obligate WAPA to participate in project construction

• Negotiating draft Participation Agreement

Figure 1 Southline Project Line Segments

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Participation Agreement Overview

• Term of 40 years from commercial operations date with 20 year renewal available

• WAPA and SL to negotiate “Key Agreements” such as Construction, O&M, Ownership,

Lease(s), and Communications & Security agreements

• Establishes an Engineering & Operating Committee (E&OC)

– Facilitation of the development, construction, and operation of the project

– Oversight of project budgets, planning, O&M functions

• Budgets – Each key agreement will provide for own budget. Collectively all budgets roll up

to a project budget managed by the E&OC

• Termination & Wind-Up – provisions for wind-up under termination scenarios:

– Prior to construction (based on lack of financing)

– Termination during 40-year term

– At natural termination date

• Defaults & Remedies – defines events of default and the remedies available

– Provides for a WAPA buy-out option of anything SL owns in the upgrade segment

Figure 2 Southline Project Area Map

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10 YEAR PLAN PROCESS IMPROVEMENTS

CUSTOMER TECHNICAL COMMITTEE

On April 26th, 2017 DSW staff met with the Customer Technical Committee (CTC) for the first

time to kick off a joint effort to discuss the CTC project proposal and the development of an

improved and enhanced Joint Planning Agreement (JPA). Through teamwork and active

participation DSW and the CTC, in collaboration with the greater customer group, will work on

process improvements, capital planning procedures, and agreements governing the 10 Year Plan

process.

The mutual goal of the CTC and DSW is to develop and strengthen the collaborative efforts in

developing and executing DSW’s capital program. Through these efforts, DSW is focused on

working to improve business practices and find new ways to create value for our Customers.

With customer concurrence and in collaboration with the CTC and its mission, DSW will continue

to provide safe secure, reliable and affordable energy and transmission services to our Customers.

This and future Customer 10 Year Plan meetings will provide updates on the goals, developments,

and accomplishments of this partnership.

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DSW Customers WAPA Staff

DSW Stakeholders

DSW 10 Year Capital PlanProcess, Responsibilities, & Flow

(Rev. 2017.05.23)

DSW REGIONAL MANAGERPerforms final review and approval of TYP project recommendations. Approves DSW Ten Year Plan.

WESTERN MDCC

DSWPREPAYMENT CUSTOMERS

Appropriations$ Prepayments$

DSW RATES

APPROVED TYP

CPC TECHNICAL SUB-TEAM -

Subject Matter Experts (SMEs) from all DSW departments as applicable Receives mission needs and project requests, identifies alternatives for study team. Analyzes study alternatives for the best-value solution(s) for all stakeholders; Prioritizes recommended projects based on WAPA prioritization criteria and submits to CPC for final review and approval. Executes Project Request Form.

CPC FINANCIAL SUB-TEAM -

Funding Managers, Rates Analyst, Budget Analyst, Accountants, & Finance Specialist

Reviews proposed recommended projects in conjunction with CPC & CPCTS, assesses the funding and budgetary impacts on the TYP. Provides final rates analysis on recommended TYP to CPC.

CAPITAL PLANNING COMMITTEE (CPC)-

Managers from Finance, Maintenance, Marketing, Environmental, CRSP, Operations, Transmission Services, Administrative, DSW MDCC Rep.

-Solicits mission needs and project requests from stakeholders; Forwards requests with business merit to technical sub-team for review & analysis; Approval of sub-team recommendations; Incorporates approved projects and priorities into TYP; Forwards recommended TYP to DSW Regional Manager for final review and approval.

KEYCPC Capital Planning CommitteeTYP Ten Year Plan AoA Analysis of Alternatives Study BC Boulder Canyon ProjectCAP Central Arizona ProjectCRSP Colorado River Storage ProjectMDCC Maintenance Design Construction Council

Customer Engagement and Feedback

Solicited through TYP meetings

DSW VP Transmission System Asset ManagementPerforms first level review; Determines need for AoA; Fast tracks emergency projects.

START

DecisionMaintenance/In-House Work

Emergency O&M

Email: [email protected]

CUSTOMER TECHNICAL COMMITTEE (CTC) -

Small customer group established on Nov. 2016 to work with WAPA DSW to jointly develop new and improved DSW business practices to meet the needs of Arizona Customers and DSW alike.

Feedback

Feedback

CAPITAL IMPROVEMENTAoA Study Initiated

SUBMIT PROJECT REQUEST FORM

Feedback

RECOMMENDED TYP

WAPA Staff

WAPA Staff

WAPA Staff

DSW Customers

PROPOSED TYP

TYP Prepayment

Vote Meeting

(October)

TYP Presentation

Meeting (August)

TYP PreviewMeeting

(June)

Mid-Cycle TYP

Meeting (February)

Customer10 Year Plan

Meeting Cycle

Meeting Cycle Varies by Customer Group

9

ASSESSMENT PHASE

AoA STUDY PHASE

Assessment PhaseINPUT(S)1. Draft Project Request Form is received from internal DSW stakeholder and/or an external stakeholder (customers)

SCOPE 1. DSW VP Transmission Asset ManagementDetermines first level review. DSW Capital Planning Committee (CPC) in concert with the Customer Technical Committee (CTC), CPC Financial Sub-team, and CPC Technical Sub-team will identify the requirements of the Project Request Form.

OUTPUT(S)1. Executed final Project Request Form with mission need, identified alternatives, functional requirements, and challenges/risks.

Decision Milestone

PRE-CONSTRUCTION PHASE(100% Design)

DSW CPC Technical Sub-team

Start~3 Months Typical

~50%-75% DesignVaries By Project

AoA Initiated~3-6 Months Typical

$ Funding Vehicle

CONSTRUCTION PHASE

TIMELINE NOT TO SCALE

PCN FUNDING

VOTE

DSW 10 Year Capital Plan Seed Funding Process Flow

AoA Complete~12 Months Typical

PROJECT DESIGN PHASE (~50%-75% Design)

AoA Study PhaseINPUT(S)1. Executed Project Request Form2. WAPA Appropriated Funding

SCOPE 1. DSW AoA study team uses the ProjectRequest Form to perform AoA study work and reports to the CPC Technical Sub-team on progress. 2. Finance to determine availability ofappropriated Seed funding

OUTPUT(S)1. Final draft of AoA Study withrecommended alternative for project scope.

Project Design PhaseINPUT(S)1. Final draft AoA Study2. WAPA Appropriated Funding

SCOPE 1. Finance to determine availability ofappropriated Seed funding 2. Develop project design package based onrecommended alternative. Drawings and specifications to ~50%-75%. 3. Update the project cost estimate peridentified design parameters.

OUTPUT(S)1. Updated Total Project Budget2. ~50%-75% Design Package3. Project scope and cost presentation toPrepayment (PCN) customers for funding approval.

Pre-Construction PhaseINPUT(S)1. Prepayment Approved funding perupdated total project budget2. ~50%-75% Design Package

SCOPE 1. Complete design package to 100% fordelivery to procurement2. Pre-construction activities: lands,environmental, surveys, etc. 3. Solicit construction contract

OUTPUT(S)1. All procurement acquisition documentssubmitted2. 100% design package

DSW CPC Financial Sub-team

Customer Technical Committee (CTC)

Construction PhaseINPUT(S)1. Funding Via Contract Exhibit A

SCOPE 1. Construct the project within thebudget and schedule constraints.

OUTPUT(S)1.Energized capital improvement 2.All key contract agreements executed (e.g., O&M, Ownership)

DSW CPC Approve

Decision Milestone

CLOSEOUTPHASE

DSW Capital Planning Committee (CPC)

ASSESSMENT PHASE & AoA STUDY PHASE PARTICIPANTS

100% DesignVaries By Project

FINISH

PREPAYMENT CUSTOMER FUNDING (VOTE REQUIRED)$APPROPRIATED SEED FUNDING $

STUDM FUNDING $

PREPAYMENT CUSTOMER FUNDING (VOTE REQUIRED)$STUDM FUNDING $

OPTION 1

OPTION 2

REVISED 6/5/2017

STUDM FUNDING $

PREPAYMENT (PCN) SEED FUNDING$

PCN FUNDING

VOTE

PREPAYMENT CUSTOMER FUNDING (VOTE REQUIRED)$

PCN FUNDING

VOTE

OPTION 3

CloseoutINPUT(S)1. Contract agreements (e.g., O&M)

OUTPUT(S)1.Finacial closeout package

PCN FUNDING

VOTE

Q - Annual QuarterAoA – Analysis of AlternativesPCN – Prepayment Funding

Project Request

Form Received

10

11

ACTIVE PROJECT UPDATES

GILA-WELLTON MOHAWK INTERSTATE-8 CROSSING REBUILD *DSW’s First Project in the new pilot program to utilize “seed funding”

Status

The AoA Study was completed in September 2016. Preliminary design work is underway, and is

anticipated to be 75% complete along with a revised estimate at next meeting in early August.

Justification for Project

The need for the Project can be summarized by its end goals; increased reliability of transmission,

reduction of risk to public and maintenance personnel, and a reduction in future maintenance costs.

The original wooden structures were erected in 1956 and are well beyond the recommended

lifespan. Many of the poles display visual symptoms of advanced external shell rot, along with

weathering and large cracks. Poles in this condition are unsafe for line personnel to climb and

perform maintenance on.

Figure 3 Interstate 8 east and westbound crossings, and “island” containing 4 structures

Consequently, maintenance personnel are forced to use bucket trucks to access pole tops. Since

portions of this line are located in remote desert pass areas, it can be difficult or impossible to get

heavy equipment near the structures to perform required maintenance work without substantial

provisions.

12

Structures located within the island are the original wood poles, and the span between structures 9-5

and 9-6 (as shown in Figure 1 above) is currently in violation of phase-to-ground clearance

requirements established by the North American Electric Reliability Corporation (NERC). Pole

failures at the I-8 crossings could pose significant risk to highway traffic and public safety.

Original Scope of Work (Identified in AoA)

Includes the removal of 28 existing wood structures, primarily along miles 7 through 10 of the Gila

(GLA)-Wellton-Mohawk (WML) 161kV Transmission Line, and replace these with up to 21 steel

monopoles. Project length encompasses approximately 2.8 miles and will complete the replacement

of the 13 mile line connecting Gila and Wellton Mohawk Substations. Approximately 10 miles of

the transmission line were replaced by WAPA maintenance crews in the last year. Due to the

inaccessibility resulting from rugged terrain and segmented access created by Interstate 8, the use of

helicopter construction is expected for approximately 1 mile of line (see Figures 1-3). Remaining

construction sites to the west are expected to be accessed through road blading.

Figure 5 Path to structure 9/4

Scope Changes (Identified in “Seed Funding” Design Phase)

A 48-count optical ground wire (OPGW) will be installed along the length of GLA-WML as a

means to improve system operations and communications along this backbone transmission line.

By including fiber installation in the scope of this project, future savings will be realized as it would

require additional helicopter use through multiple contracts to install at a later date.

The addition of fiber will require WAPA to apply to the BLM for an additional FLPMA right-of-

way grant, which may also result in additional environmental activities. An excerpt from 43 CFR

2807 states:

Figure 4 View I-8 and structure 9/5 from

west (near 9/6)

13

B. Substantial Deviation. A substantial deviation is a proposed use or location not authorized in

an existing grant, or a change in the authorized types of use. The holder must apply for the

proposed additional ROW use/area and obtain a grant amendment or additional grant.

i. 1. Determination. In determining whether a proposed change in use is a substantial

deviation from the currently authorized use, the AO should consider those activities that

are normally required to operate and Maintain the facility, what is actually authorized

by the grant, and proposed changes in the capacity of the facility.

2. Examples. Substantial deviation occurs when:

a. Adding a water line to a road ROW,

b. Adding a fiber-optic line to an existing electric distribution line,

c. Addition of a building or tower to a communication site,

d. Replacement of a transmission line static wire with fiber-optic communication cable, or

e. A user placing equipment, such as a back-up generator, outside a communication site

owner’s facility.

The addition of fiber to the scope of work resulted in the need to replace three structures just west

of the WML Substation. As with the rest of the GLA-WML Transmission Line, these original

structures are in need of replacement and are placed at such angles that fiber installation is not

feasible. The three existing structures (see Figure 4) will be replaced by two new 3-pole structures.

Figure 6 Proposed New Structures 12/6 and 12/7

Existing maintenance roads between structures 6/7 and 8/4 will be improved. A road currently

exists between those structures; however, it is not suitable for vehicular travel. The road will be

scraped and leveled as needed to allow vehicular use. By maintaining these roads, it is expected

that there will be reduced helicopter-related costs when replacing these structures.

Budget Summary WAPA is still developing project cost estimates for each of the identified alternatives above and

will be prepared to report on those cost in the next 10 Year Plan Customer Meeting tentatively

scheduled for August.

14

GILA 161KV SUBSTATION REBUILD 230KV

Status

Substation design continues and is approximately 75% complete. The estimated design completion

date was pushed into Q1 2018 to allow for a proper water-flow analysis to be completed to ensure

the significant earthwork involved in construction would not significantly increase water flow into

the nearby canal (see Figure 5). Both environmental and lands-related activities are nearly

complete.

Figure 7 Gila Substation Aerial View

Project History

The Gila Substation was originally constructed in 1949 and operates at 161kV, 69kV, 34.5kV, and

4.16kV. The 34.5kV yard was expanded in 1999. All the yards are arranged in a main-and-transfer

configuration, except for the 4.16kV yard. The new yard will be built as a breaker and half

configuration, operating at 161kV, while being constructed to 230-kV standards.

Constructing to 230kV standards allows for increased energy capacity with minimal disruption of

service for future outages. The existing 161kV yard will not be demolished as part of this contract.

Once the new 161kV system is operational, the existing 161kV yard would need to be removed to

create space for the future 69kV and 34.5kV yards. Both of these yards are in poor condition and

present safety and clearance risks to equipment and personnel, requiring WAPA to take outages on

adjacent bays.

15

Figure 8 Existing Gila 161-kV Yard

During the 161kV design study, the amperage ratings of the existing PCBs, CTs and CCVTs were

found to be inadequate; requiring the purchase of new equipment. A new service building will be

erected to house the operational equipment and a new 34.5/4.16kV transformer will be installed to

ensure reliability for the Yuma-Mesa pumping plant and operation of the substation.

The existing communication system is analog and WAPA now operates on a digital configuration.

To meet this requirement, upgrades at three relay sites and Gila substation are needed. All proposed

construction changes are meant to ensure system reliability, minimize repair and construction

interruptions, and reduce potential future costs.

16

Figure 9 Potential Future 161-kV Yard Location

Scope of Work Summary

There are no significant changes in project scope of work since the previous 10 Year Plan meeting.

Budget Summary

In 2013, the original budget estimate was $12,000,000. In July 2016, the estimate was increased to

$18,994,500 as the work required to complete the project became more detailed. As of June 2017,

the estimate remains unchanged. A full budget update with executed cost will be provided in the

next customer 10 Year Plan meeting.

Expected Energization Date

The Gila 161kV Substation rebuild to 230kV is projected to be energized and in-service in the third

quarter of fiscal year 2020.

17

PARKER-HEADGATE ROCK & PARKER-BOUSE T-LINE REROUTE

Project Status

WAPA has met with Colorado River Indian Tribe (CRIT) and presented both of the alignments as

alternatives. A public scoping meeting will be held in mid-July 2017 to formally present the new

alignment alternatives. The feedback from the public meeting will help guide WAPA in its

alignment decision. WAPA continues to investigate both alignments for the rebuild of the 161kV

line.

Project Scope

This transmission line re-route project consists of replacing the existing line from Parker to

Headgate Rock, part of the Parker to Blythe system, and from Parker to Bouse, part of the Parker to

Gila system. The rebuild will upgrade the existing wooden pole structures that, having exceeded

their useful life cycle, are currently showing signs of advanced degradation, and will require

replacement. A new 230kV transmission system replacing the existing 161kV circuits had been

originally proposed, but considering load demand and system forecasting models in the service

region, an in-kind 161kV system has been selected as the new construction design for this project.

The line will be configured as a double circuit shortly after departing from the Parker Substation for

the proposed alignment on the California side of the Colorado River. Once across the river, single

circuit transmission lines will be constructed 3 miles southeast to connect with the existing Parker-

Bouse circuit, and southwest to Headgate Rock Substation pending final routing approval.

Figure 10 Right-of-way along the Parker-Bouse/Headgate Rock 161kV lines

18

Scope of Work Summary

Several options are now being considered with regard to routing and re-use of existing rights-of-

way in an effort to control and reduce total cost to the project. Following Government to

Government Consultation, WAPA has received a new proposed and preferred Colorado River

crossing location from CRIT. The new river crossing is further upstream than the original crossing

location and utilizes CRIT land.

Including the new proposed CRIT crossing, there are currently a total of three river crossing

alternatives. All three crossings will be reviewed during the ongoing National Environmental Policy

Act (NEPA) and design processes.

The next steps for WAPA are to conduct all environmental surveys and complete the draft design.

WAPA is continuing to coordinate with CRIT to advance the project while also investigating other

new alignment options that will still meet the purpose and needs of the project.

Budget Summary

The original budget estimate was $17,900,000 in fiscal year 2013. As of May 2017, $403,000 has

been executed. A full budget update with executed cost will be provided in the next customer 10

Year Plan meeting.

Expected Energization Date

Given the undefined alignment, the energization date is difficult to determine. Once the public

scoping meeting is held and a preferred alignment has been chosen, an estimated energization date

will be provided to the Customers.

DSW Ten Year Plan - Construction ProjectsFY17 FY18 FY19 FY20 FY21

REF # PROJECT Fund Notes

PCN

Budget 5/

Total Project

Budget 5/

Estimate

FY17-26 5/

PROJECTED

TOTAL 5/

17PD 17N 17TOT 18PD 18N 18TOT 19PD 19N 19TOT 20PD 20N 20TOT 21PD 21N 21TOT 22PD

1 Parker Substation 161kV Switch Replacement PCN Canceled - Return of Prepayment Funds 1,250 1,250 25

2 Facility Rating Mitigation Year 3 (Low Priority) PCN Canceled - Return of Prepayment Funds 16,000 16,000 99

3 Parker Substation 161kV Breaker Replacement WCF On Hold- Pending Study Effort 1,168 1,168

4 Gila-Knob Transmission Line WCF Complete - Close-out Legal Delays 4,031 4,704 145 2,170 145 145

5 Black Point Mesa Reroute PCN Complete - Close-out Legal Delays 1,326 2,300 164 2,300 164 164

6 Parker-Headgate Rock/Bouse 161kV Reroute PCN Active - Planning/Design Only 17,620 18,426 17,209 18,426 860 860 1,721 4,991 6,712 2,237 6,023 8,260 860 172 1,033 344 344

7 Mead Substation Stage 15 WCF In Closeout 7,971 150 8,121 150 150

8 Mead CCVTs Structure Replacement PCN In Closeout 975 975 128 975 128 128

9 ED4-ED2 115-kV Transmission Line Rebuild PCN In Closeout 2,287 7,186 108 7,186 108 108

10 Mesa Substation Remediation PCN Active 3,535 4,291 795 4,291 785 785 10 10

11 Gila-North Gila, Gila-Knob 161kV T-Line Reroute PCN Active 3,618 4,283 2,245 4,283 500 1,575 2,075 150 150 20 20

12 Facility Rating Mitigation Year 2 (Medium Priority) PCN Active 8,525 8,910 1,140 8,910 650 200 850 244 46 290

13 Gila-Gila Valley 34.5kV Laterals Rebuild WMF Active 5,384 5,326 5,384 745 4,300 5,045 195 86 281

14 Gila Substation 161kV to 230kV Rebuild PCN Active 17,224 18,995 14,679 18,995 1,200 11,250 12,450 950 350 1,300 775 50 825 104 104

15 Tucson Substation Rebuild PCN Active 7,000 8,758 2,218 8,758 850 585 1,435 583 50 633 100 100 50 50

16 Liberty Series Capacitor Bank Replacement PCN Active 10,372 10,372 10,364 10,372 950 7,000 7,950 450 1,614 2,064 250 100 350

17 Crossman Peak Microwave Facility PCN Active 4,525 4,525 3,985 4,525 275 650 925 275 2,600 2,875 132 132 53 53

18 Gila-Wellton Mohawk Interstate-8 Crossing Rebuild WCF Active 6,341 6,341 6,341 500 800 2,600 3,400 766 2,100 2,866 75 75

19 Kofa-Dome Tap 161kV Rebuild WCF Projected FY18 Start - Study Complete 4,730 4,730 4,730 690 3,281 3,971 609 50 659 100 100

20 Dome Tap-Gila 161kV Rebuild WCF Projected FY18 Start - Study Complete 7,336 7,336 7,336 850 1,450 2,300 750 3,400 4,150 650 100 750 136 136

21 Bouse-Kofa 161kV Rebuild WCF Projected FY19 Start - Study Complete 31,100 31,100 31,100 311 311 933 12,440 13,373 1,244 14,928 16,172 311

22 Mead Substation Replace Transformer (KU2A) WCF Projected FY20 Start - Active Study 5,000 5,000 5,000 200 4,000 4,200 300 450 750 50

23 Parker-Blythe 161kV #2 Rebuild WCF Projected FY21 Start - Active Study 45,000 45,000 45,000 450 450 1,350

24 Parker Substation 161kV Rebuild WCF No study 10,500 10,500 10,500 525 525 1,050

25 Blythe-Gold Mine Tap 161kV Rebuild WCF No study 30,000 29,700

26 Gold Mine Tap Knob 161kV Rebuild WCF REMOVE FROM PLAN- RRADS WIP 15,000 15,000

27 Blythe-Headgate Rock #1 line 161kV Rebuild WCF No study 23,900 10,516

28 Gila-Wellton Mohawk (remaining 161kV rebuild) WCF REMOVE FROM PLAN- RRADS WIP 5,200 2,132

29 Rogers-Coolidge 230kV Reconductor WCF No study 6,000 2,460

8,011 25,560 33,071 6,918 17,068 23,986 5,950 11,723 17,673 3,025 16,712 19,738 2,999 15,378 18,377 2,7611/

PD values reflect Federal and Non-Construction Contractor Labor2/

NPD Values Reflect Equipment and Construction Costs Planning Spend-Plan Profile (% of Total Project Cost)3/

PF = Previous Pre-payment Collection Pending Funding Approval Program (PD)4/

PC = Previous Pre-payment Collection Approved Year 1 5%5/

Values include Unapproved FY17 Pre-payment Requested Funds Year 2 10% 29%

Year 3 13% 35%

Planning Assumptions for Projects That Have Not Completed AoA Study Phase: Year 4 5% 1%

Year 5 2%

Planning Spend-Plan Profile (% of Total Project Cost)

Program (PD)

Year 1 7% 34%

Year 2 6% 50%

Year 3 3%


Program (PD)

Year 1 1%

Year 2 3% 40%

Year 3 4% 48%

Year 4 1% 2%

Year 5 1%

(1) Project start dates are scheduled based on urgency derived from MDCC priority ranking

and projected available funding and resources

(2) Prior to AoA Studies, Proposed Project Fiscal Year Spend-Plans are Calculated Using

5 Year Profile (See chart on right)

(3) AoA Studies are conducted under O&M

(4) Until Studies Are completed, Total Project Cost Are Strictly High Level Conceptual

WAPA DSW FY17-26 TYP19

10 YEAR PLAN PREVIEW

LAST YEARS 10 YEAR PLAN

DSW Ten Year Plan - Construction Projects

REF # PROJECT Fund Notes

PCN

Budget 5/

Total Project

Budget 5/

Estimate

FY17-26 5/

PROJECTED

TOTAL 5/

1 Parker Substation 161kV Switch Replacement PCN Canceled - Return of Prepayment Funds 1,250 1,250 25

2 Facility Rating Mitigation Year 3 (Low Priority) PCN Canceled - Return of Prepayment Funds 16,000 16,000 99

3 Parker Substation 161kV Breaker Replacement WCF On Hold- Pending Study Effort 1,168 1,168

4 Gila-Knob Transmission Line WCF Complete - Close-out Legal Delays 4,031 4,704 145 2,170

5 Black Point Mesa Reroute PCN Complete - Close-out Legal Delays 1,326 2,300 164 2,300

6 Parker-Headgate Rock/Bouse 161kV Reroute PCN Active - Planning/Design Only 17,620 18,426 17,209 18,426

7 Mead Substation Stage 15 WCF In Closeout 7,971 150 8,121

8 Mead CCVTs Structure Replacement PCN In Closeout 975 975 128 975

9 ED4-ED2 115-kV Transmission Line Rebuild PCN In Closeout 2,287 7,186 108 7,186

10 Mesa Substation Remediation PCN Active 3,535 4,291 795 4,291

11 Gila-North Gila, Gila-Knob 161kV T-Line Reroute PCN Active 3,618 4,283 2,245 4,283

12 Facility Rating Mitigation Year 2 (Medium Priority) PCN Active 8,525 8,910 1,140 8,910

13 Gila-Gila Valley 34.5kV Laterals Rebuild WMF Active 5,384 5,326 5,384

14 Gila Substation 161kV to 230kV Rebuild PCN Active 17,224 18,995 14,679 18,995

15 Tucson Substation Rebuild PCN Active 7,000 8,758 2,218 8,758

16 Liberty Series Capacitor Bank Replacement PCN Active 10,372 10,372 10,364 10,372

17 Crossman Peak Microwave Facility PCN Active 4,525 4,525 3,985 4,525

18 Gila-Wellton Mohawk Interstate-8 Crossing Rebuild WCF Active 6,341 6,341 6,341

19 Kofa-Dome Tap 161kV Rebuild WCF Projected FY18 Start - Study Complete 4,730 4,730 4,730

20 Dome Tap-Gila 161kV Rebuild WCF Projected FY18 Start - Study Complete 7,336 7,336 7,336

21 Bouse-Kofa 161kV Rebuild WCF Projected FY19 Start - Study Complete 31,100 31,100 31,100

22 Mead Substation Replace Transformer (KU2A) WCF Projected FY20 Start - Active Study 5,000 5,000 5,000

23 Parker-Blythe 161kV #2 Rebuild WCF Projected FY21 Start - Active Study 45,000 45,000 45,000

24 Parker Substation 161kV Rebuild WCF No study 10,500 10,500 10,500

25 Blythe-Gold Mine Tap 161kV Rebuild WCF No study 30,000 29,700

26 Gold Mine Tap Knob 161kV Rebuild WCF REMOVE FROM PLAN- RRADS WIP 15,000 15,000

27 Blythe-Headgate Rock #1 line 161kV Rebuild WCF No study 23,900 10,516

28 Gila-Wellton Mohawk (remaining 161kV rebuild) WCF REMOVE FROM PLAN- RRADS WIP 5,200 2,132

29 Rogers-Coolidge 230kV Reconductor WCF No study 6,000 2,460

1/ PD values reflect Federal and Non-Construction Contractor Labor

2/ NPD Values Reflect Equipment and Construction Costs Planning Spend-Plan Profile (% of Total Project Cost)

3/ PF = Previous Pre-payment Collection Pending Funding Approval Program (PD)

4/ PC = Previous Pre-payment Collection Approved Year 1 5%

5/ Values include Unapproved FY17 Pre-payment Requested Funds Year 2 10% 29%

Year 3 13% 35%

Planning Assumptions for Projects That Have Not Completed AoA Study Phase: Year 4 5% 1%

Year 5 2%


Program (PD)

Year 1 7% 34%

Year 2 6% 50%

Year 3 3%


Program (PD)

Year 1 1%

Year 2 3% 40%

Year 3 4% 48%

Year 4 1% 2%

Year 5 1%

(1) Project start dates are scheduled based on urgency derived from MDCC priority ranking

and projected available funding and resources

(2) Prior to AoA Studies, Proposed Project Fiscal Year Spend-Plans are Calculated Using

5 Year Profile (See chart on right)

(3) AoA Studies are conducted under O&M

(4) Until Studies Are completed, Total Project Cost Are Strictly High Level Conceptual

FY22 FY23 FY24 FY25 FY26

22N 22TOT 23PD 23N 23TOT 24PD 24N 24TOT 25PD 25N 25TOT 26PD 26N 26TOT

622 933 311 311

50

18,000 19,350 1,800 21,600 23,400 450 900 1,350 450 450

3,045 4,095 1,365 3,675 5,040 525 105 630 210 210

300 300 900 12,000 12,900 1,200 14,400 15,600 300 600 900

1,050 5,100 6,150 900 7,500 8,400 450 450

239 239 717 9,560 10,277

364 1,768 2,132

420 2,040 2,460

21,667 24,428 3,776 25,275 29,051 2,925 18,105 21,030 2,760 21,900 24,660 750 600 1,350

WAPA DSW FY17-26 TYP20

10 YEAR PLAN PREVIEW

LAST YEARS 10 YEAR PLAN

21

PROPOSED FY18-20 PROJECT STARTS

REF # PROJECT NAME

MDCC

SCORE

PROJECT COST

(Conceptual - Predesign)

PROJECTED IN-

SERVICE DATE

POWER

SYSTEM

1 Coolidge- VAF 115kV Transmissioin Line 3.575 AoA Study In Progress AoA Study In Progress PD-P

2 Kofa-Dome Tap 161kV Transmissioin Line 3.400 $4,730,000 Fiscal Year Q4, 2021 PD-P

3 Dome Tap-Gila 161kV Transmissioin Line 3.400 $7,336,000 Fiscal Year Q3, 2021 PD-P

4 Bouse-Kofa 161kV Transmissioin Line 3.400 $31,000,000 Fiscal Year Q4, 2024 PD-P

5 Mead Substation KU2A Transformer N/A AoA Study In Progress AoA Study In Progress Intertie

6 Parker-Blythe 161kV #2 Transmissioin Line 3.150 N/A N/A PD-P

7 Parker 161 kV Substation 3.000 N/A N/A PD-P

8 Blythe-Headgate Rock (#1 line) 161kV

Transmissioin Line

2.875 N/A N/A PD-P

9 Rogers-Coolidge 230kV Transmissioin Line 2.600 N/A N/A PD-P

10 Tucson-Oracle115kV Transmissioin Line 2.550 N/A N/A PD-P

FISCAL YEAR 2018 PROPOSED START(S)

FISCAL YEAR 2019 PROJECTED START(S)

FISCAL YEAR 2020 PROJECTED START(S)

FISCAL YEAR 2021+ PROJECTIONS

MDCC Maintenance, Design, Construction, Committee

PD-P Parker Davis Project

AoA Analysis of Alternatives Study

22

COOLIDGE-VALLEY FARMS 115KV TRANSMISSION LINE Project Description

WAPA is currently in the process of completing an Analysis of Alternatives (AoA) study on the

Coolidge-Valley Farms (COL-VAF) 115kV transmission line. This line segment runs east from

COL Substation for approximately 6 miles. The transmission line feeds southern Arizona loads at

115kV. The line has been in service since 1950s and WAPA has been evaluating a rebuild effort

since 2013.

Project Justification

The Coolidge-Valley Farms-Oracle line is a congested marketing path that serves loads on southern

Arizona’s 115kV transmission system. Rebuilding the line and adding OPGW would comply with

current NERC policy, mitigate two (2) NERC Facility Ratings violations (phase-to-ground

clearance violations), and relieve congestion to continue to serve load growth into the future. The

project would also address wood pole replacement requirements.

Pole Inspection Data (total of 55 poles):

• 34.5% of Poles Rated at A

• 23.6% of Poles Rated at B

• 34.5% of Poles Rated at C

• 7.3% of Poles Rated at D

Proposed Project Scope This project would consist of removing conductors, insulators, hardware and several wood H-

structures. The project would also include any required right-of-way work to repair deteriorated

access roads. Structures will be upgraded to accommodate new conductor that would satisfy

current and future system needs.

The proposed Alternatives in the AoA are as follows:

Alternative #1- Status Quo (Maintenance only)

Alternative #2 - Upgrade conductor (TBD), wood poles 115kV, OPGW.

Alternative #3 - Upgrade conductor (Drake 795 ACSS), upgrade structures (light duty steel),

115kV, OPGW.

Alternative #4- Upgrade conductor (Drake 795 ACSS), upgrade structures (steel monopole),

double circuit, 115kV/69kV under-build, OPGW.

Alternative #5- Upgrade conductor (Drake 795 ACSS), upgrade structures (steel monopole),

double circuit, 115kV double circuit, OPGW.

All alternatives would increase capacity to meet the minimum requirements while also providing

additional capacity to market. There are limiting factors in the station equipment at each substation

that also need to be upgraded for the line capacity ratings to be realized.

Project Predesign Estimate (Conceptual)

WAPA is still developing project cost estimates for each of the identified alternatives above and

will be prepared to report on those cost in the next 10 Year Plan Customer Meeting tentatively

scheduled for August of this year.

23

KOFA-DOME TAP 161KV TRANSMISSION LINE Project Description

WAPA performed an Analysis of Alternatives (AoA) study on the Kofa-Dome Tap 161-kV

Transmission Line to investigate the mitigation of eight confirmed NERC violations, conductor

limitations, and the evaluation of numerous maintenance concerns surrounding aging wood poles

and right-of-way access.

Figure 11 Kofa-Dome Tap 161-kV Transmission Line

The Kofa-Dome Tap (KOF-DME) Transmission Line is located in western Arizona and runs in a

north-south orientation between the respective substations. The existing transmission line consists

of a mix of light duty steel poles and wooden H-frame structures.

24


Failing wooden pole H-frame structures

Eight NERC phase-to-ground clearance violations

OPGW communication requirements

The KOF-DME 161kV Transmission Line built in 1943 has had most of the wood H-Frame

structures replaced with light duty steel H-Frame structures. The transmission line now consists of

50 light duty steel structures and eight wooden structures. The line consists of approximately seven

miles of 300 kcmil hollow core copper conductor, and two steel OGWs. Maintenance inspections

have identified five existing structures that need replacing (four wood, one steel).

Figure 12 Kofa Dome Tap Wooden Structure 90-6’

The addition of an optical ground wire (OPGW) will allow for the future communication bandwidth

needs to be met. Security is currently in the process of installing live feed video cameras and

Information Technology (IT) networks at substations; these additional data requirements will

eventually exceed the current available communications bandwidth provided via microwave.

25

Figure 13 Wood Pole Deterioration in Structure 90-6

Proposed Project Scope The proposed alternative is Alternative #3.

This alternative will change the inspection requirements from once a year to once every three years.

This alternative will also provide one OPGW which will give a separate and redundant

communications path for metering, relay protection, and communications as recommended by

NERC.

The Alternatives reviewed in the AoA are as follows:

Alternative #1- Status Quo (Maintenance only)

The transmission line would remain in its present condition with eight confirmed NERC violations.

Deteriorated wood structures would be replaced by WAPA’s maintenance group as inspection

results indicate the need.

Alternative #2- Reconductor KOF-DME

After receiving environmental clearances remove 7.34 miles of 300 kcmil hollow core copper

conductor and one steel overhead ground wire (OGW). Install 7.34 miles of 336.4 kcmil ACSS

conductor and new hardware and polymer insulators. Install 7.34 miles of OPGW.

Replace light duty steel H-Frame structures and wood pole structures with taller light duty steel H-

Frame structures as needed to correct NERC violations.

26

Alternative #3- Rebuild with Light Duty Steel H-Frame Structures

Identical to Alternative #2 with the additional replacement of all wooden structures with light duty

steel H-Frame structures.

Alternative #4- Rebuild to 230-kV Standards

After receiving environmental clearances and acquiring additional right-of-way, remove 7.34 miles

of 300 kcmil hollow core copper conductor, two steel OGWs, insulators and hardware. Remove

eight wooden H-Frame structures, and 50 light duty steel H-Frame structures. Install 7.34 miles of

954 kcmil ACSR, one OPGW, single circuit 230-kV steel monopoles, polymer insulators, and

hardware.

Alternative #5- Install Inset Structures

Install eleven light duty steel H-Frame inset structures, eight are needed to correct NERC violations,

and three are needed to replace deteriorated wooden H-Frame structures.


Kofa-Dome Tap Alternative #3 Conceptual Budget

Install 7.34 miles of 336.4 kcmil ACSS conductor, hardware and polymer insulators.

Install 7.34 miles of OPGW. Replace light duty steel H-Frame structures to correct

NERC violations. Replace all wood pole structures with light duty steel H-Frame

structures.

TOTAL

Administrative $298,000

Design $172,000

Construction $1,910,000

Government Furnished Equipment (GFE)* $1,371,000

Commissioning $132,000

Environmental $59,000

Subtotal $3,942,000

Contingency (20%) $788,000

Total Project Budget $4,730,000

Note: Estimate does NOT include any provisions for potential ROW negotiations with BLM.

*OPGW is ~2.8% of Total Project Estimate

27

Project Proposed Rate Impact

The available rate impact summarized below was calculated in the summer of 2016 and will be

updated based upon a revalidated project schedule and anticipated energization date for the next

customer meeting tentatively scheduled for August of this year.

28

Project Predesign Conceptual Schedule

Projected Start: Fiscal Year Q2, 2018

Projected In-service Date: Fiscal Year Q4, 2021

Kofa-Dome Tap Alternative #3 Conceptual Schedule

Install 7.34 miles of 336.4 kcmil ACSS conductor, hardware and polymer insulators. Install 7.34 miles of OPGW. Replace light duty steel H-Frame structures to correct NERC violations.

Replace all wood pole structures with light duty steel H-Frame structures.

Activity Duration YR1 YR2 YR3 YR4

Planning 3 Months

Design and Specification 12 Months

Government Furnished Equipment GFE 12 Months

Procurement of Construction Contract 6 Months Notice to Proceed 0.25 Months

Contractor Mobilization and Submittals 2 Months

Construction 16 Months

No Outage May 1st – September 30th 10 Months

Commissioning 2.5 Months

In Service 0.25 Months Closeout 3 months Total Project Duration 42 Months

29

DOME TAP-GILA 161KV TRANSMISSION LINE Project Description

The Analysis of Alternatives (AoA) investigated and provided an assessment of potential

modifications to the Dome Tap-Gila (DME-GLA) 161kV transmission line. The DME-GLA

transmission line segment is part of the overall Parker-Gila transmission line built in 1943, which

runs through western Arizona.

The DME-GLA transmission line is a 7.57 mile segment of the Parker-Gila 161kV transmission

line. The line is part of the 161kV system that provides power from the Parker Dam, and feeds

Wellton-Mohawk Irrigation and Drainage District (WMIDD), the U.S. Army, and other entities.

The line is constructed with three 300 kcmil hollow core copper conductors, two steel OGWs,

wooden H-Frame structures and light duty steel H-frame structures, only 16 wooden structures

remain.

Figure 14 Dome Tap-Gila 161kV Light Duty Steel & Wood Structures


Failing wood pole structures

Eight NERC phase-to-ground clearance violations

Various highway (US95), canal, and railroad crossings requiring upgraded dead-end structures

There are currently 43 right-of-way (ROW) issues that need to be addressed for proper

vehicular access to structure pads.

The original wooden structures on the DME-GLA transmission line have been in service for over

70 years. Of the 66 structures supporting this section of the transmission line, 50 have been

replaced with light duty steel H-frame structures. The remaining 16 wooden transmission structures

are showing signs of shell rot and surface cracking and require replacement.

Review of the transmission line without a full design prompted the recommendation to use 336.4

kcmil “Oriole” ACSS as the recommended replacement conductor of choice for DME-GLA.

Stringing with ACSS wire eliminated approximately 80% of NERC violations in the DME-GLA

segment because it can be strung with higher tension

However, the design phase will further investigate the most cost effective, highest capacity

conductor compatible with the existing tangent structures for optimal return on investment.

30

Proposed Project Scope

The proposed alternative is Alternative #3.

This Alternative’s steel pole transmission line will meet all expected future loading and have

reduced maintenance for the next 50 years. This Alternative will also provide one optical ground

wire which will give a separate and redundant communications path for metering, relay protection,

communications and security.

The Alternatives reviewed in the AoA are as follows:

Alternative #1: Status Quo (Maintenance Only)

Under the no action alternative, The DME-GLA Transmission line continues in its present condition

with eight NERC violations. WAPA maintenance forces would continue to replace failed wooden

poles with new wooden poles upon failure. Crews would need to evaluate the line with greater

frequency and emergency work would increase in prevalence, elevating risk.

Alternative #2: Reconductor

Replacing the existing copper conductor with aluminum ACSS sized to have equal or greater

ampacity as 300 kcmil hollow core copper conductors. The structural integrity of 336.4 kcmil

“Oriole” ACSS will allow the new conductor to be pulled tighter, removing 80% of the existing

NERC violations. This alternative installs ten light-duty steel H-Frame structures for additional

height clearances or as needed to fix NERC violations. This alternative will also provide a separate

and redundant communications path via an OPGW for metering, relay protection security, and

communications as recommended by NERC.

Alternative #3: Replace Wood Structures and Reconductor

Install light duty steel H-Frame structures in place of the remaining16 wooden structures. This will

match the current 50 newer light duty steel H-Frame steel structures installations already made to

the line segment. Replacing the existing copper conductor with aluminum ACSS sized to have

equal or greater ampacity as 300 kcmil hollow core copper conductors. The structural integrity of

336.4 kcmil “Oriole” ACSS will allow the new conductor to be pulled tighter, removing 80% of the

existing NERC violations. This alternative installs ten light-duty steel H-Frame structures for

additional height clearances or as needed to fix NERC violations. This alternative will also provide

a separate and redundant communications path via an OPGW for metering, relay protection

security, and communications as recommended by NERC.

Alternative #4: Rebuild to 230-kV standards operate at 161kV

Install steel single circuit mono-pole structures in place of the 66 structures currently in the line

segment. Replace the existing copper conductor with new 954 kcmil ACSR conductor to remove

all of the existing NERC violations. This alternative will also provide a separate and redundant

communications path via OPGW for metering, relay protection, and communications as

recommended by NERC. Install polymer insulators and 230kV hardware on the new single circuit

steel monopoles to create a new transmission segment that will require a smaller ROW and fewer

line structures.

31

Alternative #5: Inset Structures (Fix NERC violations)

Western will create new access ROW roadways and pads to enable the inset of eight light-duty steel

H-frame structures between existing transmission line structures as necessary to correct phase-to-

ground clearance issues.


Dome Tap-Gila Alternative #3- Conceptual Estimate Replace 16 deficient wood structures with light duty steel, add light duty steel inset

structures to fix NERC violations, reconductor with ACSS, and add OPGW.

TOTAL

Administrative $693,000

Design $274,000


Government Furnished Equipment (GFE)* $2,835,000



Subtotal $6,113,000

Contingency (20%) $1,223,000


Note: *OPGW is ~1.85% of Total Project Estimate

32





33

Project Predesign Conceptual Schedule Projected Start: Fiscal Year Q2, 2018


Dome Tap-Gila Alternative #3- Conceptual Schedule

Replace 16 deficient wood structures with light duty steel, add light duty steel inset structures to fix NERC violations, re-conductor with ACSS, and add OPGW.

Activity Duration YR1 YR2 YR3 YR4

Planning 1 Months



Procurement of Construction Contract 6 Months

Notice to Proceed 0.25 Months

Contractor Mobilization and Submittals 2 Months Construction 14 Months

No Outage May 1st - September 30th 10 Months


In Service 0.25 Months

Closeout 3 months Total Project Duration 40 Months

34

BOUSE-KOFA 161KV TRANSMISSION LINE Project Description

The Analysis of Alternatives (AoA) investigated potential modifications to the Bouse-Kofa (BSE-

KOF) 161-kV Transmission Line to mitigate 107 NERC Violations. This Transmission Line is

located in western Arizona running south from Bouse substation to Kofa substation. Bouse

substation is located just north of the Junction of AZ Highways 72 and 95 in La Paz county. Kofa

substation is located approximately 16 miles northeast of the city of Yuma in Yuma County.

The transmission line, originally built in 1943 has had most of the wood H-Frame structures

replaced with light duty steel H-Frame structures. With the partial replacement of wooden

structures and a reroute around the city of Quartzsite, this line segment now has 584 light duty steel

H-Frame structures, 82 wood H-Frame structures, and 44 steel 230-kV single circuit monopoles.

There are 75.6 miles of 300 kcmil hollow core copper conductor, 8.4 miles of 954 kcmil ACSR

conductor, and 0.2 miles of 477 kcmil ACSR conductor.


Replace remaining wooden structures with light duty steel

106 NERC phase-to-ground clearance violations, 1 phase-to-OGW clearance violation

Establish separate and redundant communication path on OPGW

There are 106 cases of line to ground clearances and one case of line to OGW of a crossing line

clearance not meeting the minimum clearance required by the National Electrical Safety Code

(NESC) and NERC.

The addition of an optical ground wire (OPGW) will allow for the future communication bandwidth

needs to be met. Security is currently in the process of installing live feed video cameras and

Information Technology (IT) networks at substations; these additional data requirements will

eventually exceed the current available communications bandwidth.


The proposed alternative is Alternative #3.

This preferred alternative will mitigate all 107 NERC violations and will have an added benefit of

changing the inspection requirement from once every year to once every three years.

The Alternatives reviewed in the AoA are:

Alternative #1- Status Quo (Maintenance Only)

The Bouse-Kofa 161-kV Transmission Line would remain in its present condition with 107 NERC

violations. Deteriorated wood structures would be replaced by WAPA’s maintenance group as

inspection results indicate the need.

35

Alternative #2- Reconductor and Correct NERC violations


conductor, 0.2 miles of 477 kcmil ACSR, and 84.2 miles of steel OGW. Install 75.8 miles of 336.4

kcmil ACSS conductor, hardware and polymer insulators. Install 84.2 miles of OPGW. This

installs light-duty steel H-Frame structures as needed for additional height clearances and to correct

all NERC violations.

Alternative #3- Rebuild with Light Duty Steel H-Frame Structures


conductor, 0.2 miles of 477 kcmil ACSR, and 84.2 miles of steel OGW. Install 75.8 miles of 336.4

kcmil ACSS, hardware and polymer insulators. Install 84.2 miles of OPGW. This alternative

replaces all wood with light duty steel structures. Various existing steel structures would also be

replaced to achieve additional height clearances or as needed to fix NERC violations.

Alternative #4- Rebuild to 230-kV Standards

After receiving environmental clearances and acquiring additional ROW, remove 75.6 miles of 300

kcmil hollow core copper conductor, 0.2 miles of 477 ACSR, two steel OGWs, insulators and

hardware. Remove 8.4 miles of ½ inch steel OGW, 82 wood H-Frame structures, and 585 light

duty steel H-Frame structures. Install 75.8 miles of 954 kcmil ACSR, 84.2 miles of OPGW, single

circuit 230-kV steel monopoles, polymer insulators, and hardware.

Alternative #5- Install Steel Inset Structures

Install light duty steel H-Frame inset structures as needed to correct NERC violations, and light

duty steel H-Frame structures as needed to replace deteriorated wood H-Frame structures.

36

Figure 15 Bouse-Kofa Area Map

37

Figure 16 Bouse-Kofa Wooden Structure No. 25-8


Bouse-Kofa Alternative #3 Conceptual Estimate

Upgrade 75.8 miles of 336.4 kcmil ACSS conductor, Install 84.2 miles of

OPGW, replace light duty steel H-Frame structures with taller ones as

needed to correct NERC violations, replace all wood pole structures with

light duty steel H-Frame structures.

TOTAL

Administrative $1,022,000

EVMS* $2,970,000

Design $183,000


Government Furnished Equipment (GFE)** $10,794,000



Subtotal $25,939,000

Contingency (20%) $5,188,000


*Earned Value Management System (EVMS) is a project management system required by the

Department of Energy to manage cost and schedule on projects having a Total Project Cost (TPC)

over $20 million.**OPGW is 2.9% of Total Project Cost.

38





39

Project Predesign Conceptual Schedule Projected Start: Fiscal Year Q2, 2019


Bouse-Kofa Alternative #3 Conceptual Schedule

Upgrade 75.8 miles of 336.4 kcmil ACSS conductor, Install 84.2 miles of OPGW, replace light duty steel H-Frame structures with taller ones as needed to correct NERC violations, replace all wood pole structures with light duty steel H-Frame structures.

Activity Duration YR1 YR2 YR3 YR4 YR5 YR6

Planning 3 Months



Procurement of Construction Contract 12 Months

Notice to Proceed 0.25 Months

Contractor Equipment and Submittals 3 Months

Construction 36 Months

No Outage May 1st - September 30th 15 Months


In Service 0.25 Months

Closeout 3 months

Total Project Duration 66 Months

40

ANALYSIS OF ALTERNATIVES (AoA) STUDIES

BLYTHE-PARKER #2 TRANSMISSION LINE Background

Currently proposed for an FY2021 project start, this line segment is actively being studied in the

AoA process. The Blythe to Parker Transmission line (BLY-PAD) is a 161-kV line single circuit

line spanning 64 miles. Built in 1951, this segment runs through eastern California passing through

mountainous terrain, low desert, cultivated fields, low hills, and residential areas. The line traverses

BLM land, BIA land and borders wilderness areas.

It is a single circuit, 954 kcmil ACSR conductor, supported by 521 wooden H-frame structures, and

has two overhead ground wires. The line is part of the 161kV system that provides power from the

Parker and Headgate Rock dams.

Project Justification:

The bulk of the wooden structures are in service long past their engineered lifespan, and are

exhibiting condition-related deterioration consistent with their age and the low desert environment.

A fiber strength analysis was performed on the 521 wood structures, consisting of 1077 wooden

poles along this line. Of the poles checked in the Polux® study, 80% of the wood poles require

replacement. The breakdown of those results are below.

Blythe-Parker #2 Transmission Line

Polux® Wood Pole Testing Results (Douglas Fir)

RESULTS Wood Pole Total

1077

Percent of

Total

Pass

(remaining strength is above 4680 PSI or 65% of the

design strength)

214 20%

Recommend Replace

(remaining strength falling below 4680 PSI or 65%

of the design strength)

602 56%

Rejected

(remaining strength falling below 3600 PSI or 50%

of the design strength

256 24%

The wood poles display symptoms of advanced external shell rot, weathering, and large cracks.

The shell rot introduces reliability and safety concerns because of the reduction of the amount of

wood available to bear the load of the conductors and hardware. Damage to the outer layer can

allow the ingress of fungus and insects that cause internal decay, as well as increase risk for line

personnel to climb the poles. Maintenance personnel are forced to use bucket trucks to access pole

tops. Since much of this line is located in remote desert areas, it can be difficult to get heavy

equipment near the facilities.

NERC required all transmission line owners/operators to perform a Facility Rating Analysis of all

transmission lines over 100kV in order to determine the as-built condition and de-rate the line to

that condition, or to mitigate the condition to achieve the design rating. There are currently nine

cases of phase-to-ground clearances violations.

41

Additionally there are also a number of miscellaneous maintenance issues encountered including

broken insulators, insulators showing damage due to flashover, and loose or missing hardware. The

problems discussed above take on added significance because of the difficulty accessing the line.

Some structures have no road access, and in certain areas nearby road improvements have blocked

the right-of-way completely. In many cases, the right-of-way will require grading improvements

before it can be accessed by vehicles. Additionally, it can be a lengthy process to obtain

environmental clearance to perform even emergency maintenance.


The rebuild of the BLY-PAD Transmission Line will consist of completely removing conductors,

insulators, hardware, and all failing structures. An AoA study is being performed to analyze the

various alternatives to rebuilding the this line segment to meet the WAPA mission statement,

providing safe, secure, reliable, and affordable transmission service to its Customers.

The proposed Alternatives to be reviewed in the AoA are:

Alternative #1- Status Quo (Maintenance Only)

Under the no action alternative, WAPA maintenance forces would continue to replace failed wood

poles with new wooden poles upon failure. This option has a low probability of success due to the

magnitude of work required and WAPA’s limited amount of maintenance resources for such an

expansive scope of work. This alternative would not fix the nine NERC violations and will require

additional work in order to retrofit the line design and fix the violations. WAPA would also lack a

redundant communications path by means of an OPGW path.

Alternative #2- 161kV Replace-in-kind with upgraded steel structure dead-ends every <10 miles.

This alternative will evaluate replacing all 522 failing wooden poles with new wooden H-frame

structures with steel cross arms. WAPA would also design and install upgraded steel dead-end

structures at adequate distances to mitigate against cascading failure. The existing conductor would

be utilized and an OPGW fiber line would be added to establish a redundant communication path.

The nine NERC violations would also be mitigated using possible light duty steel structures or taller

wooden H-frame structures to gain sufficient clearance distances.

Alternative #3- 161kV with upgraded light duty steel H-Frame structures

This alternative will evaluate replace all 522 failing wooden structures with new light steel H-frame

structures. WAPA will replace the existing conductor, ground wire, insulators, and hardware.

OPGW fiber line would be added to establish a redundant communication path. The nine NERC

violations would also be mitigated with taller structures to gain sufficient clearance distances.

Alternative #4- 161kV with upgraded steel monopoles on entire line

This alternative will evaluate replacing all wooden structures with new steel monopole structures.

WAPA will replace the existing conductor, ground wire, insulators, and hardware. OPGW fiber line

would be added to establish a redundant communication path. The nine NERC violations would

also be mitigated with taller structures to gain sufficient clearance distances.

42

Alternative #5- Rebuild with steel monopoles using 230-kV specifications and standards (operated

at 161kV).

This alternative will evaluate replacing all wooden structures with new steel monopole double

circuit structures with new Pheasant 1272 ACSS conductor and insulators installed on one circuit.

OPGW fiber line would be added to establish a redundant communication path. The nine NERC

violations would also be mitigated with taller pole structures to gain sufficient clearance distances.

Risks

Extensive environmental and some right-of-way work will be required as part of the development

process due to the deteriorated state of access roads along this line, the age of previous cultural and

biological surveying, and existing corridor encroachments. With the permissions from these efforts

in place and a line survey completed, design work can begin. Western can begin procuring the

support structures once the design has progressed far enough. When the materials are delivered and

the contract has been awarded, the contractor will begin by improving access. With this access in

place, the contractor will then proceed with the line rebuild. Once the new facilities are complete

and commissioned, the line can be returned to service.

Benefits

Replacing the aging wooden H-frame support structures and conductors on the Blythe-Parker

Transmission Line will increase the reliability of service by reducing the risk of line outages due to

structure and support failures. This line segment represents a critical backbone element of WAPA’s

161kV transmission system. In addition, the level of maintenance effort and associated cost will be

reduced while safety for maintenance personnel and the public is improved.

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Y1

9 N

PD

BO

UL

DE

R C

AN

YO

N

RE

F.

NO

. P

RO

JE

CT

DE

SC

RIP

TIO

NL

OC

AT

ION

S

PO

WE

R

SY

ST

EM

FY

17

BU

DG

ET

SU

BM

ISS

ION

FY

18

BU

DG

ET

SU

BM

ISS

ION

FY

19

BU

DG

ET

SU

BM

ISS

ION

1A

rmy T

ap

/ S

en

ato

r W

ash

Lin

eA

TP

/SE

WG

GC

L$

15

0,0

00

$6

00

,00

0$

75

0,0

00

$1

0,0

00

$2

90

,00

0$

30

0,0

00

$0

$0

$0

G5

20

0 T

OT

AL

S$

15

0,0

00

$6

00

,00

0$

75

0,0

00

$1

0,0

00

$2

90

,00

0$

30

0,0

00

$0

$0

$0

2G

ila-G

ila V

alle

y L

ate

ral

Re

bu

ilds

GL

A/G

IVG

GC

L$

44

8,4

16

$3

,90

5,2

02

$4

,35

3,6

18

$5

0,0

00

$1

,25

0,0

00

$1

,30

0,0

00

$0

$0

$0

3G

ila-N

ort

h G

ila 6

9kV

Re

bu

ild

GL

A/N

GA

GG

CL

$3

,00

0$0

$3

,00

0$

33

1,7

31

$3

51

,80

0$

68

3,5

31

$2

5,6

50

$6

63

,35

0$

68

9,0

00

G5

60

0 T

OT

AL

S$

45

1,4

16

$3

,90

5,2

02

$4

,35

6,6

18

$3

81

,73

1$

1,6

01

,80

0$

1,9

83

,53

1$

25

,65

0$

66

3,3

50

$6

89

,00

0

LE

VE

E T

OT

AL

S$

60

1,4

16

$4

,50

5,2

02

$5

,10

6,6

18

$3

91

,73

1$

1,8

91

,80

0$

2,2

83

,53

1$

25

,65

0$

66

3,3

50

$6

89

,00

0

1"S

ON

" -

HV

AC

Un

it

Re

pla

ce

me

nt

SO

N

GG

CS

$8

,61

7$0

$8

,61

7$0

$0

$0

$0

$0

$0

2W

FD

- 2

42

We

ll F

ield

Tra

nsfo

rme

r R

ep

lace

me

nt

WF

DG

GC

S$

5,8

85

$0

$5

,88

5$0

$0

$0

$0

$0

$0

G5

20

0 T

OT

AL

S$

14

,50

2$0

$5

,88

5$0

$0

$0

$0

$0

$0

3C

om

mu

nic

atio

n S

yste

m

Ad

ditio

ns

SO

N

GG

CS

$6

5,1

71

$2

,16

0$

67

,33

1$0

$0

$0

$0

$0

$0

G5

30

0 T

OT

AL

S$

65

,17

1$

2,1

60

$6

7,3

31

$0

$0

$0

$0

$0

$0

4S

on

ora

We

llfie

ld T

ran

sfo

rme

rsS

ON

G

GC

S$

10

0,0

00

$0

$1

00

,00

0$0

$0

$0

$0

$0

$0

G5

60

0 T

OT

AL

S$

10

0,0

00

$0

$1

00

,00

0$0

$0

$0

$0

$0

$0

LE

VE

E T

OT

AL

S$

17

9,6

73

$2

,16

0$

17

3,2

16

$0

$0

$0

$0

$0

$0

LE

VE

E

SA

LIN

ITY

Pre

par

ed 6

/1/2

017

44

FY

17

PD

F

Y1

7 N

PD

F

Y1

8 P

D

FY

18

NP

D

FY

19

PD

F

Y1

9 N

PD

BO

UL

DE

R C

AN

YO

N

RE

F.

NO

. P

RO

JE

CT

DE

SC

RIP

TIO

NL

OC

AT

ION

S

PO

WE

R

SY

ST

EM

FY

17

BU

DG

ET

SU

BM

ISS

ION

FY

18

BU

DG

ET

SU

BM

ISS

ION

FY

19

BU

DG

ET

SU

BM

ISS

ION

1W

are

ho

use

/Wo

rksp

ace

with

BO

RG

CG

GC

R$

10

0,0

00

$2

00

,00

0$

30

0,0

00

$5

0,0

00

$2

,45

0,0

00

$2

,50

0,0

00

$2

1,4

18

$9

78

,58

2$

1,0

00

,00

0

2K

V2

D 2

4/4

-kV

Tra

nsfo

rme

r

Re

pla

ce

me

nt

GC

GG

CR

$0

$0

$0

$1

0,0

00

$4

90

,00

0$

50

0,0

00

$2

15

,24

4$

10

,00

0$

22

5,2

44

3

Re

pla

ce

me

nt

of

6 B

yp

ass

Bre

ake

rs (

FL

G 1

94

& 5

94

,

KA

Y 1

08

6 &

13

86

, a

nd

PP

K

21

92

& 2

29

9)

FL

G/P

PK

/KA

YG

GC

R$0

$0

$0

$0

$0

$0

$2

59

,62

7$

1,1

00

,37

3$

1,3

60

,00

0

4

Re

pla

ce

me

nt

of

GC

34

5kV

Bre

ake

rs (

12

92

, 3

49

2,

55

96

,

5682)

GC

GG

CR

$0

$0

$0

$0

$0

$0

$0

$0

$0

5

Re

pla

ce

me

nt

of

PP

K 3

45

kV

Bre

ake

rs (

21

99

, 2

29

2,

11

96

,

1492)

PP

KG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

6R

ep

lace

me

nt

of

GC

23

0kV

Bre

ake

rs (

74

82

, 7

28

2,

80

82

)G

CG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

7R

ep

lace

me

nt

of

PP

K 3

45

kV

Bre

ake

rs (

15

96

& 1

69

2)

PP

KG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

8R

ep

lace

me

nt

of

GC

34

5kV

Bre

ake

rs (

19

4 &

59

4)

GC

GG

CR

$0

$0

$0

$0

$0

$0

$0

$0

$0

9R

ep

lace

me

nt

of

GC

34

5kV

Bre

ake

rs (

10

92

, 1

19

6,

32

92

)G

CG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

10

Re

pla

ce

me

nt

of

GC

23

0kV

Bre

ake

rs (

76

82

, 7

98

2)

GC

GG

CR

$0

$0

$0

$0

$0

$0

$0

$0

$0

G5

00

0 T

OT

AL

S

$1

00

,00

0$

20

0,0

00

$3

00

,00

0$

60

,00

0$

2,9

40

,00

0$

3,0

00

,00

0$

49

6,2

90

$2

,08

8,9

54

$2

,58

5,2

44

11

Te

st

Eq

uip

me

nt

MO

VP

GG

CR

$2

,93

0$

76

,23

8$

79

,16

8$0

$1

20

,00

0$

12

0,0

00

$0

$6

0,0

00

$6

0,0

00

12

"GC

" -

Acce

ss R

oa

d U

pg

rad

eG

CG

GC

R$

5,0

00

$0

$5

,00

0$0

$0

$0

$0

$0

$0

13

"GC

S"

- H

VA

C U

nit

Re

pla

ce

me

nt

GC

GG

CR

$2

,99

0$0

$2

,99

0$0

$0

$0

$0

$0

$0

14

"KA

Y"

- H

VA

C U

nit

Re

pla

ce

me

nt

KA

YG

GC

R$

7,0

89

$0

$7

,08

9$0

$0

$0

$0

$0

$0

15

"LH

V"

- H

VA

C U

nit

Re

pla

ce

me

nt

LH

VG

GC

R$

7,0

98

$0

$7

,09

8$0

$0

$0

$0

$0

$0

16

"PP

K"

- H

VA

C U

nit

Re

pla

ce

me

nt

PP

KG

GC

R$

7,0

00

$0

$7

,00

0$0

$0

$0

$0

$0

$0

17

"PP

K"

- K

U1

A T

ran

sfo

rme

r

Re

pla

ce

me

nts

PP

KG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

18

23

0kV

Dis

co

nn

ect

Re

pla

ce

me

nts

Ba

ys 2

3 a

nd

33

PP

KG

GC

R$

45

,00

0$

5,0

00

$5

0,0

00

$0

$0

$0

$0

$0

$0

19

Re

pla

ce

me

nt

of

FX

Ca

pa

cito

r

Ma

inte

na

nce

Bre

ake

rsP

PK

/RG

SG

GC

R$

1,0

00

$0

$1

,00

0$0

$0

$0

$0

$0

$0

20

Em

erg

en

cy B

rea

ke

r

Re

pla

ce

me

nt

PP

K 1

49

2P

PK

GG

CR

$1

70

,00

0$

33

0,0

00

$5

00

,00

0$0

$0

$0

$0

$0

$0

21

36

2-K

V B

rea

ke

r R

ep

lace

me

nt

PP

KG

GC

R$0

$2

28

,62

6$

22

8,6

26

$0

$0

$0

$0

$0

$0

G5

20

0 T

OT

AL

S

$2

48

,10

7$

63

9,8

64

$8

87

,97

1$0

$1

20

,00

0$

12

0,0

00

$0

$6

0,0

00

$6

0,0

00

CO

LO

RA

DO

RIV

ER

ST

OR

AG

E P

RO

JE

CT

Pre

par

ed 6

/1/2

017

45

FY

17

PD

F

Y1

7 N

PD

F

Y1

8 P

D

FY

18

NP

D

FY

19

PD

F

Y1

9 N

PD

BO

UL

DE

R C

AN

YO

N

RE

F.

NO

. P

RO

JE

CT

DE

SC

RIP

TIO

NL

OC

AT

ION

S

PO

WE

R

SY

ST

EM

FY

17

BU

DG

ET

SU

BM

ISS

ION

FY

18

BU

DG

ET

SU

BM

ISS

ION

FY

19

BU

DG

ET

SU

BM

ISS

ION

G5

3 -

Co

mm

un

ica

tio

n P

roje

cts

22

Co

mm

Site

Bu

ildin

g

Re

pla

ce

me

nt

With

En

viro

nm

en

tal

TO

WG

GC

R$147

$0

$147

$9

0,0

00

$1

0,0

00

$1

00

,00

0$0

$0

$0

23

Mic

row

ave

Up

gra

de

s W

ith

En

viro

nm

en

tal

JP

K-P

SM

/

JP

K-G

CM

GG

CR

$1

0,0

00

$4

0,0

00

$5

0,0

00

$0

$0

$0

$0

$0

$0

24

Co

mm

To

we

r R

ep

lace

me

nt

-

Mic

row

ave

Site

GC

GG

CR

$1

05

,00

0$

75

,00

0$

18

0,0

00

$3

35

,00

0$

17

,00

0$

35

2,0

00

$0

$0

$0

25

Co

mm

Site

Bu

ildin

g

Re

pla

ce

me

nt

With

En

viro

nm

en

tal

MG

SG

GC

R$0

$0

$0

$0

$0

$0

$7

2,9

63

$0

$7

2,9

63

26

Gle

n C

an

yo

n M

icro

wa

ve

To

we

r

Re

pla

ce

me

nt

GC

MG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

27

Po

we

r S

yste

m R

ep

lace

me

nt

TB

DG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

28

Re

mo

te T

ern

ima

l U

nit (

RT

U)

Re

pla

ce

me

nt

FL

GG

GC

R$0

$0

$0

$0

$0

$0

$8

3,2

66

$6

3,7

71

$1

47

,03

7

29

RT

U R

ep

lace

me

nt

(RT

AC

)L

HV

GG

CR

$0

$0

$0

$0

$0

$0

$0

$0

$0

30

RT

U R

ep

lace

me

nts

(Co

mm

un

ica

tio

n S

ite

s)

EL

D/C

AN

GG

CR

$0

$0

$0

$0

$0

$0

$4

5,8

21

$3

9,1

79

$8

5,0

00

31

RT

U R

ep

lace

me

nts

(Co

mm

un

ica

tio

n S

ite

s)

PS

M/G

CS

GG

CR

$0

$0

$0

$0

$0

$0

$0

$0

$0

32

RT

U R

ep

lace

me

nts

(Co

mm

un

ica

tio

n S

ite

s)

TB

DG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

$0

33

WIN

/CIP

7 S

ecu

rity

Re

lay

En

cry

ptio

nM

UL

TI-

SIT

ES

GG

CR

$2

9,2

00

$800

$3

0,0

00

$1

9,0

00

$1

,00

0$

20

,00

0$

18

,69

3$

1,3

07

$2

0,0

00

34

Me

ter

Re

pla

ce

me

nt

- R

eve

nu

e

& P

an

el

GC

S/P

WL

GG

CR

$0

$0

$0

$7

5,0

00

$7

5,0

00

$1

50

,00

0$0

$0

$0

35

Me

ter

Re

pla

ce

me

nt

- R

eve

nu

e

& P

an

el

PP

KG

GC

R$0

$0

$0

$0

$0

$0

$1

38

,49

2$

36

,50

8$

17

5,0

00

36

Me

ter

Re

pla

ce

me

nt

- R

eve

nu

e

& P

an

el

LH

VG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

37

Me

ter

Re

pla

ce

me

nt

- R

eve

nu

e

& P

an

el

TB

DG

GC

R$0

$0

$0

$0

$0

$0

$0

$0

$0

38

Re

lay R

ep

lace

me

nts

-

RA

S/U

nit D

rop

pin

gG

CS

-FL

GG

GC

R$

90

,00

0$

10

,00

0$

10

0,0

00

$0

$0

$0

$0

$0

$0

39

GC

S N

ew

Me

ters

fo

r th

e

Vis

ito

r C

en

ter

GC

SG

GC

R$

31

,12

6$0

$3

1,1

26

$0

$0

$0

$0

$0

$0

40

PR

C-0

02

-2 D

igita

l M

on

ito

rin

g

Eq

uip

me

nt

Up

gra

de

s &

Te

am

Ad

ditio

ns

PP

KG

GC

R$

90

,15

0$

79

,85

0$

17

0,0

00

$1

00

,00

0$

75

,00

0$

17

5,0

00

$0

$0

$0

41

Re

lay R

ep

lace

me

nts

- L

ine

Re

lays,

69

kV

PP

KG

GC

R$0

$0

$0

$1

00

,00

0$

10

0,0

00

$2

00

,00

0$0

$0

$0

42

Re

lay R

ep

lace

me

nts

- T

ran

sfe

r

Bre

ake

r &

Bu

s D

iff

PP

KG

GC

R$0

$0

$0

$9

0,0

00

$1

00

,00

0$

19

0,0

00

$0

$0

$0

43

Re

lay R

ep

lace

me

nts

-

Tra

nsfo

rme

r (K

U1

A &

KU

2A

)P

PK

GG

CR

$5

4,7

70

$5

,23

0$

60

,00

0$0

$0

$0

$0

$0

$0

44

PR

C-0

02

-2 D

igita

l M

on

ito

rin

g

Eq

uip

me

nt

Up

gra

de

s &

Te

am

Ad

ditio

ns

TB

DG

GC

R$0

$0

$0

$0

$0

$0

$1

35

,58

4$

64

,41

6$

20

0,0

00

45

Re

lay R

ep

lace

me

nts

- L

ine

&

RT

U (

RT

AC

)K

AY

GG

CR

$0

$0

$0

$0

$0

$0

$0

$0

$0

CO

LO

RA

DO

RIV

ER

ST

OR

AG

E P

RO

JE

CT

G5

3 -

Pro

tec

tio

n P

roje

cts

Pre

par

ed 6

/1/2

017

46

FY

17

PD

F

Y1

7 N

PD

F

Y1

8 P

D

FY

18

NP

D

FY

19

PD

F

Y1

9 N

PD

BO

UL

DE

R C

AN

YO

N

RE

F.

NO

. P

RO

JE

CT

DE

SC

RIP

TIO

NL

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$0

$0

$0

$0

$0

$0

$0

28

Re

pla

ce

RG

S 2

30

kV

Bre

ake

rs

(10

86

, 6

82

, 7

86

)R

GS

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$0

$0

$0

$0

$0

$0

$0

$0

$0

29

Re

pla

ce

RG

S 2

30

kV

Bre

ake

rs

(88

2,

98

2)

RG

SG

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D$0

$0

$0

$0

$0

$0

$0

$0

$0

G5

00

0 T

OT

AL

S$0

$0

$0

$0

$0

$0

$0

$0

$0

PA

RK

ER

DA

VIS

Pre

par

ed 6

/1/2

017

49

FY

17

PD

F

Y1

7 N

PD

F

Y1

8 P

D

FY

18

NP

D

FY

19

PD

F

Y1

9 N

PD

BO

UL

DE

R C

AN

YO

N

RE

F.

NO

. P

RO

JE

CT

DE

SC

RIP

TIO

NL

OC

AT

ION

S

PO

WE

R

SY

ST

EM

FY

17

BU

DG

ET

SU

BM

ISS

ION

FY

18

BU

DG

ET

SU

BM

ISS

ION

FY

19

BU

DG

ET

SU

BM

ISS

ION

EL

EC

TR

ICIA

NS

30

Te

st

Eq

uip

me

nt

MO

VP

GG

PD

$0

$0

$0

$0

$1

20

,00

0$

12

0,0

00

$0

$1

20

,00

0$

12

0,0

00

31

Wo

od

Po

le P

rog

ram

G

LA

WM

SG

GP

D$

1,4

40

,83

5$

95

,10

0$

1,5

35

,93

5$

65

0,0

00

$2

,15

0,0

00

$2

,80

0,0

00

$2

,27

1,2

25

$7

28

,77

5$

3,0

00

,00

0

32

Wo

od

Po

le P

rog

ram

B

LY

KN

BG

GP

D$

55

,00

0$

48

6,0

00

$5

41

,00

0$0

$0

$0

$0

$0

$0

33

Wo

od

Po

le P

rog

ram

S

GR

OR

AG

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D$

10

,87

0$188

$1

1,0

58

$0

$0

$0

$0

$0

$0

34

PA

D K

X6

A a

nd

KX

4A

Tra

ns.

Bu

sh

ing

Re

pla

ce

me

nt

PA

DG

GP

D$

4,1

05

$3

15

,00

0$

31

9,1

05

$1

80

,00

0$

20

,00

0$

20

0,0

00

$0

$0

$0

35

"DA

D"

- D

isco

nn

ects

Re

pla

ce

me

nts

Ba

ys 3

/6P

AD

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$2

,00

0$0

$2

,00

0$0

$0

$0

$0

$0

$0

36

"BL

Y"

- H

VA

C U

nit

Re

pla

ce

me

nt

BL

Y

0

03

1B

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$7

,11

0$0

$7

,11

0$0

$0

$0

$0

$0

$0

37

"HE

N"

- H

VA

C U

nit

Re

pla

ce

me

nt

HE

N

0

00

9B

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$9

,39

0$0

$9

,39

0$0

$0

$0

$0

$0

$0

38

"PA

D"

- H

VA

C U

nit

Re

pla

ce

me

nt

PA

D

0

06

7B

GG

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$9

,44

7$0

$9

,44

7$0

$0

$0

$0

$0

$0

39

"PH

X"

- H

VA

C U

nit

Re

pla

ce

me

nt

PH

X

0

01

7B

GG

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$9

,21

5$0

$9

,21

5$0

$0

$0

$0

$0

$0

40

"RG

S"

- H

VA

C U

nit

Re

pla

ce

me

nt

RG

S

0

00

7B

GG

PD

$4

,23

2$0

$4

,23

2$0

$0

$0

$0

$0

$0

41

23

0kV

Oil

Bre

ake

r

Re

pla

ce

me

nt

PA

D 4

82

(T

AM

),

pu

rch

ase

20

18

, in

sta

ll 2

01

9

(co

ntin

ge

nt

up

on

co

nstr

uctio

n

PA

D R

eb

uild

pro

ject)

PA

DG

GP

D$0

$0

$0

$0

$0

$0

$0

$1

75

,00

0$

17

5,0

00

42

23

0kV

Oil

Bre

ake

r

Re

pla

ce

me

nt

PA

D 7

82

(T

AM

),

pu

rch

ase

20

18

, in

sta

ll 2

01

9

(co

ntin

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nt

up

on

co

nstr

uctio

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PA

D R

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ject)

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15

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$0

$0

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0$

17

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00

43

(2)

Arie

l D

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$1

50

K F

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6$

29

0,0

66

$0

$0

$0

$0

$0

$0

44

Lin

e T

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PH

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32

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$0

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$0

$0

$0

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45

(2)

Co

mp

act

Te

leh

an

dle

rsP

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$0

$0

$0

$0

$0

$0

$0

$0

$0

46

UP

FIT

TW

O S

EM

I

TR

AC

TO

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PH

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$5

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00

$5

0,0

00

$0

$0

$0

$0

$0

$0

47

FL

IR U

V C

AM

ER

AP

HS

GG

PD

$0

$8

0,3

10

$8

0,3

10

$0

$0

$0

$0

$0

$0

48

Ae

ria

l M

an

lift

60

ftP

HS

GG

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$0

$0

$0

$0

$1

20

,00

0$

12

0,0

00

$0

$0

$0

49

Ae

ria

l M

an

lift

80

ftP

HS

GG

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$0

$0

$0

$0

$1

40

,00

0$

14

0,0

00

$0

$0

$0

50

50

KW

Ge

ne

rato

rP

HS

GG

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$0

$7

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38

$7

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38

$0

$0

$0

$0

$0

$0

PA

RK

ER

DA

VIS

Pre

par

ed 6

/1/2

017

50

FY

17

PD

F

Y1

7 N

PD

F

Y1

8 P

D

FY

18

NP

D

FY

19

PD

F

Y1

9 N

PD

BO

UL

DE

R C

AN

YO

N

RE

F.

NO

. P

RO

JE

CT

DE

SC

RIP

TIO

NL

OC

AT

ION

S

PO

WE

R

SY

ST

EM

FY

17

BU

DG

ET

SU

BM

ISS

ION

FY

18

BU

DG

ET

SU

BM

ISS

ION

FY

19

BU

DG

ET

SU

BM

ISS

ION

LIN

EM

EN

51

Bu

cke

t T

ruck 4

0 f

t (2

-ea

ch

)P

HS

GG

PD

$0

$0

$0

$0

$1

50

,00

0$

15

0,0

00

$0

$1

50

,00

0$

15

0,0

00

52

Ba

re H

an

d B

ucke

t T

ruck 1

25

ftP

HS

GG

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$0

$0

$0

$0

$0

$0

$8

00

,00

0$

80

0,0

00

53

Bu

ll D

oze

rP

HS

GG

PD

$0

$0

$0

$0

$0

$0

$0

$3

80

,00

0$

38

0,0

00

54

Gra

der

PH

SG

GP

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$3

19

,96

2$

31

9,9

62

$0

$0

$0

$0

$0

$0

55

Re

ar

Ste

er

Tra

iler

PH

SG

GP

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$0

$0

$0

$0

$0

$0

$0

$0

56

Pre

ssu

re D

igg

er

PH

SG

GP

D$0

$0

$0

$0

$5

00

,00

0$

50

0,0

00

$0

$0

$0

57

Dis

trib

utio

n L

ine

Tru

ck

PH

SG

GP

D$0

$0

$0

$0

$3

36

,00

0$

33

6,0

00

$0

$0

$0

58

Co

mp

act

Te

leh

an

dle

rP

HS

GG

PD

$0

$0

$0

$0

$1

00

,00

0$

10

0,0

00

$0

$0

$0

59

UT

V (

2-e

ach

)P

HS

GG

PD

$0

$0

$0

$0

$3

0,0

00

$3

0,0

00

$0

$0

$0

60

Bu

cke

t T

ruck (

Re

pla

ce

12

5ft

Alte

c)

PH

SG

GP

D$0

$0

$0

$0

$0

$0

$0

$0

$0

61

MO

VP

- T

BD

PH

SG

GP

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$0

$0

$0

$0

$0

$0

$0

$0

G5

20

0 T

OT

AL

S

$1

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2,2

04

$2

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3,3

19

$3

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5,5

23

$8

30

,00

0$

3,6

66

,00

0$

4,4

96

,00

0$

2,2

71

,22

5$

2,5

28

,77

5$

4,8

00

,00

0

G5

3 -

Co

mm

un

ica

tio

n P

roje

cts

62

Te

st

Eq

uip

me

nt

MO

VP

GG

PD

$0

$4

55

,62

2$

45

5,6

22

$0

$1

00

,00

0$

10

0,0

00

$0

$1

00

,00

0$

10

0,0

00

63

Co

mm

Site

Bu

ildin

g

Re

pla

ce

me

nt

MT

LG

GP

D$0

$0

$0

$0

$0

$0

$8

3,5

37

$0

$8

3,5

37

64

DA

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ep

lace

me

nts

WT

K/M

TM

GG

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$1

10

,00

0$

14

0,0

00

$2

50

,00

0$

12

2,0

00

$1

20

,00

0$

24

2,0

00

$0

$0

$0

65

DA

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ep

lace

me

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CT

P/M

ED

GG

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$0

$0

$0

$8

0,0

00

$1

20

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0$

20

0,0

00

$3

3,8

91

$2

03

,63

3$

23

7,5

24

66

OP

GW

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nsta

llatio

n (

In S

tud

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Ph

ase

)

LA

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IMP

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GG

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$2

0,8

00

$4

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0$

25

,00

0$0

$0

$0

$0

$0

$0

67

Po

we

r S

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m R

ep

lace

me

nt

(Mic

row

ave

Bld

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att

erie

s)

PH

SG

GP

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$0

$0

$1

5,0

00

$2

0,0

00

$3

5,0

00

$0

$0

$0

68

Po

we

r S

yste

m R

ep

lace

me

nt

(Co

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Ce

nte

r B

att

erie

s)

PH

SG

GP

D$0

$0

$0

$0

$0

$0

$3

6,4

38

$2

,50

0$

38

,93

8

69

Po

we

r S

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m R

ep

lace

me

nt

TB

DG

GP

D$0

$0

$0

$0

$0

$0

$0

$0

$0

70

Op

tica

l M

ux R

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lace

me

nts

(FO

P)

FO

PG

GP

D$

11

,00

0$

39

,00

0$

50

,00

0$

11

,00

0$

39

,00

0$

50

,00

0$0

$0

$0

71

RT

U R

ep

lace

me

nts

PA

DG

GP

D$

55

,00

0$0

$5

5,0

00

$0

$0

$0

$0

$0

$0

72

Ra

dio

R

ep

lace

me

nts

(F

Y1

6

Ca

rryo

ve

r)P

AD

GG

PD

$4

6,0

00

$4

,00

0$

50

,00

0$0

$0

$0

$0

$0

$0

73

OA

ISY

S E

qp

Re

pla

ce

me

nt/

Vo

ice

Re

co

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r

(FY

16

Ca

rryo

ve

r)

PA

DG

GP

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8,9

98

$5

6,8

02

$6

5,8

00

$0

$0

$0

$0

$0

$0

74

GP

K -

Cis

co

SO

NE

T

Re

pla

ce

me

nt

GP

KG

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27

,07

0$0

$2

7,0

70

$0

$0

$0

$0

$0

$0

75

YP

O-

LA

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Ra

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Re

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ce

me

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L

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YP

OG

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25

,23

4$0

$2

5,2

34

$0

$0

$0

$0

$0

$0

76

GT

H/H

LT

/MC

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CK

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ptica

l

Mu

x R

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lace

me

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GT

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$0

$128

$0

$0

$0

$0

$0

$0

72

RT

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ep

lace

me

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TB

DG

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$0

$0

$1

01

,26

0$

48

,74

0$

15

0,0

00

$1

01

,26

0$

48

,74

0$

15

0,0

00

73

Ra

dio

Re

pla

ce

me

nts

(JU

S)

JU

SG

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D$0

$0

$0

$0

$0

$0

$5

9,3

26

$6

0,6

74

$1

20

,00

0

PA

RK

ER

DA

VIS

Pre

par

ed 6

/1/2

017

51

FY

17

PD

F

Y1

7 N

PD

F

Y1

8 P

D

FY

18

NP

D

FY

19

PD

F

Y1

9 N

PD

BO

UL

DE

R C

AN

YO

N

RE

F.

NO

. P

RO

JE

CT

DE

SC

RIP

TIO

NL

OC

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S

PO

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SY

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EM

FY

17

BU

DG

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SU

BM

ISS

ION

FY

18

BU

DG

ET

SU

BM

ISS

ION

FY

19

BU

DG

ET

SU

BM

ISS

ION

74

WIN

/CIP

7 S

ecu

rity

Re

lay

En

cry

ptio

nM

UL

TI-

SIT

ES

GG

PD

$3

68

,79

4$

17

,05

6$

38

5,8

50

$7

7,2

47

$2

2,7

53

$1

00

,00

0$

77

,24

7$

22

,75

3$

10

0,0

00

75

DM

S U

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rad

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NH

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OP

GG

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$2

5,0

00

$0

$2

5,0

00

$0

$0

$0

$0

$0

$0

76

Re

lay R

ep

lace

me

nts

-

Su

bsta

tio

nE

D2

GG

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$1

19

,89

8$

30

,10

2$

15

0,0

00

$0

$0

$0

$0

$0

$0

77

WM

3 -

We

llto

n M

oh

aw

k

Pu

mp

ing

Pla

nt

Up

gra

de

sW

M1

&W

M3

GG

PD

$70

$0

$70

$0

$0

$0

$0

$0

$0

78

PH

S -

Po

we

r S

yste

m

Re

pla

ce

me

nt

(Co

mm

Ctr

)P

HS

GG

PD

$234

$234

$0

$0

$0

$0

$0

$0

79

MT

L -

Co

mm

Site

Re

pla

ce

me

nts

MT

LG

GP

D$

51

,12

5$

2,9

00

$5

4,0

25

$0

$0

$0

$0

$0

$0

80

ME

D D

' -

Ba

sle

r R

ela

y

Re

pla

ce

me

nts

ME

DG

GP

D$

1,2

57

$1

,25

7$0

$0

$0

$0

$0

$0

81

MT

M_

CT

P -

JU

S M

icro

wa

ve

Re

pla

ce

me

nts

MT

M_

CP

TG

GP

D$

3,4

42

$3

,44

2$0

$0

$0

$0

$0

$0

82

Re

lay R

ep

lace

me

nts

- L

ine

HE

N/M

ED

GG

PD

$2

5,0

00

$2

5,0

00

$5

0,0

00

$9

5,0

00

$5

,00

0$

10

0,0

00

$0

$0

$0

83

Re

lay R

ep

lace

me

nts

- L

ine

PH

X/L

IBG

GP

D$

25

,19

5$

24

,80

5$

50

,00

0$

95

,00

0$

5,0

00

$1

00

,00

0$0

$0

$0

84

Me

ter

Pro

gra

mT

BD

GG

PD

$0

$0

$0

$9

5,0

00

$5

,00

0$

10

0,0

00

$1

00

,63

7$

10

,00

0$

11

0,6

37

85

PR

C-0

02

-2 D

ME

Up

gra

de

s &

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ns

TB

DG

GP

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$0

$0

$9

5,0

00

$5

,00

0$

10

0,0

00

$9

5,0

00

$5

,00

0$

10

0,0

00

86

Re

lay R

ep

lace

me

nts

-

Un

de

rfre

qu

en

cy

WM

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53

APPENDICES DSW ORG charts

Senior Vice President and

DSW Regional Manager

G0000

Ron Moulton

Sylvia Gallardo (Admin Asst)

Energy Management &

Marketing G0200

John Paulsen

Management Svs

G1000

Leonard Mathieu

Maintenance

G5000

Jimmy Kendrick

Power Marketing

G6000

Jack Murray

Financial Management

G8000

Ethel Redhair

Environment G0400

Linda Marianito

Safety G0700

Troy Henry

Supervisory Facilities &

Property Mgmt Spec

Vacant: New

Procurement G1500

Susan Ethridge

Transmission Lines & Subs

Maintenance G5200

Brett Moad

Protection & Communications

Maintenance G5300

Teresita Amaro

Engineering & Construction

G5600

Gary Lachvayder

Budget & Alternative

Finance G8100

Anthony Camp

Accounting G8200

A. Beth Kozik

Rates G6100

Scott Lund

Power Contracts & Energy

Services G6200

Vacant Vice: Young

Resource Planning and

Settlements G6300

Tina Ramsey


January 1, 2017

OVERVIEW

Transmission

Services

J7000

Robert Easton

J7200

J7300

J7400

Power Systems

Operations

J4000

Darren Buck

J4100

J4200

J4800

J4900

Information

Technology

J2600

Michael Paris

FULL TIME FLOAT

PERMANENTOrg Author'd FTP Students Temp Appr.

Code FTE Term

G0000 29 0 0 0 0

G1000 16 2 0 0 0

G5000 125 8 0 0 0

G6000 28 1 0 0 0

G8000 16 2 0 0 0

Total 214 13 0 0 0

OH

0

0

0

0

0

0


January 1, 2017

MAINTENANCE

G5000

Vice President of Transmission System Asset

Management for Desert Southwest Region

GS-340-15

Jimmy Kendrick

Maintenance Management Specialist GS-301-13

Nancy Ruiz

Reliability Compliance Specialist GS-1101-13

Jeffrey Smith

Asset Management Specialist GS-301-13

Valerie Berk

Electrical Engineer (Project Manager) GS-850-13

Tony Guinane

Transmission Lines &

Substation Maintenance

G5200

Protection &

Communication

Maintenance

G5300

Engineering and

Construction

G5600

G5000

Authorized

FTE

Float

FTP

125 0

Float

Student

0G5000

G5600

G5300

G5200

5

52

027

0

0

41

0

2

Total 0

Float

Apprentice

0

0

0

0

8

1

5

0

0

0

0

OH

0

DESERT SOUTHWEST REGIONApril 2017

TRANSMISSION LINES & SUBSTATIONS MAINTENANCE

G5200

Supervisory Transmission Lines & Substations Maintenance Manager GS-301-14 Brett Moad Vacant Vice: Strawn

Veg & Access Rd Spec GS-401-13 Steven Narolski

Power System Maint Spec GS-301-12 Melissa Wise Abel Betancourt James Leach Vacant Vice: Ruiz Jr.

LINEMAN

Foreman III Lineman WB-2801 Steven Yeats

Lineman Aerial Obs WB-2801 David Katich

Foreman II Lineman WB-2801 Timothy Hibbs

Lineman WB-2801 Troy Meier Aaron Byford John Sheridan Richard Galindo Alex Hernandez Brandon Mullen

Foreman II Lineman WB-2801 Vacant Vice: Mortensen F

Lineman WB-2801 Scott Cuningham Alex Robles Lyle Hager Kai Bothwell Horacio Adriano Victor Van

Heavy Equip Oper WB-5715 Gary Fletcher

PHOENIX

Foreman II Electrician WB-2810 John Oja

Electrician WB-2810 Chris Flynn Policarpio Cachin Michael Lyle

PAGE

Foreman II Electrician WB-2810 Anthony Lucero

Electrician WB-2810 Julie Couts

Electrician CIT WB-2810 Randy Hammit

PARKER

Foreman II Electrician WB-2810 Randy Gates

Electrician WB-2810 Miguel Rodriguez

ELECTRICIANS Foreman III Electrician WB-2810 Grover Bray

MEAD

Foreman II Electrician WB-2810 Randy Strand

Foreman I Electrician WB-2810 Robert Conklin

Electrician WB-2810 Michael Lagarde David Sorrell Marvin Moone Paula Sibbley

COOLIDGE

Foreman II Electrician WB-2810 Steven Aiello Electrician WB-2810 Fernando Alcaraz Martin Brister

GILA

Foreman II Electrician WB-2810 Rodney Chaffee

Electrician WB-2810 John Hall S. (Scooter) Godwin William Koger

DAVIS Foreman II Electrician WB-2810 Ronald Payne

Electrician WB-2810 Charles Muir

Yuma Foreman II Lineman WB-2801 Brian Heisler

Lineman WB-2801 Kevin Halone Nicholas Beutel Richard Mortensen Heavy Equip Oper WB-5715 Vacant New F

AuthorizedFTE

FloatFTP

52 1

G5200

0

Float Student

0

FloatApprentice

OH

0

COMMUNICATIONS

SupervisoryElectronicsEngineerGS‐855‐13SilviaC.Perez

ElectronicsEngineerGS‐855‐13

StevenBrown

ElectronicsEngineerGS‐855‐12/13Vacant(VicePerez)NathanielLeeJonOtteman

ElectronicsEngineerGS‐855‐12KevinTitch

COMMUNICATIONS

FOREMANIIICraftsmanWB‐2610TimothyAlme

PHOENIX

FOREMANIIP&CCraftsmanWB‐2610DavidTodd

ForemanIP&CCraftsmanWB‐2610RichardSmith

ElectronicEquipmentCraftsmanWB‐2610MichaelLindquistPeteGutierrez

RichardPetersonStevenErickson

DESERTSOUTHWESTREGIONPROTECTION&COMMUNICATIONSMAINTENANCE

May1,2017

PROTECTION&CONTROL

SupervisoryElectricalEngineer

GS‐850‐13ZacharyEyasu

ElectricalEngineerGS‐850‐13

GregShumakerSheilaKeating(PT)

ElectricalEngineerGS‐850‐12/13MuhammadTayyabVacant(ViceEyasu)

ElectricalEngineerGS‐850‐5/7/9/11/12ArthurRuizJr.(May2017)

PROTECTION&CONTROL

FOREMANIIICraftsmanWB‐2610Vacant(ViceCaldwell)

PHOENIX

FOREMANIIP&CCraftsmanWB‐2610DomenicBarone

ForemanIP&CCraftsmanWB‐2610RichardMorgan

P&CCraftsmanCITWB‐2610AmandaMoore

Meter&RelayCraftsmanWB‐2610DenverThomasBrianJarvis

Meter&RelayCITCraftsmanWB‐2610JohnP.Grantham(Page)

MEAD

FOREMANIIP&CCraftsmanWB‐2610Mary(Jodi)Harmon

P&CCraftsmanCITWB‐2610DemarcoBrooks

Meter&RelayCraftsmanWB‐2610Vacant(Vice‐Miller)

BryanKinderVacant(ViceMontoya)

COOLIDGE

FOREMANIIP&CCraftsmanWB‐2610JonBryan

Meter&RelayCraftsmanWB‐2610JohnD.Pereza

P&CCraftsmanCITWB‐2610GerardoQuiros

GILA

FOREMANIIP&CCraftsmanWB‐2610RoyFreeman

Meter&RelayCraftsmanWB‐2610Vacant(ViceBall)

Meter&RelayCITWB‐2610FernandoSepulveda

PROTECTION&COMMUNICATIONMAINTENANCEG5300

SupervisoryProtection&CommunicationMaintenanceManagerGS‐301‐14

TeresitaD.Amaro

PowerSystemMaintenanceSpecGS‐301‐12StevenSmith

MaintenanceManagementSpecGS‐301‐12Vacant(ViceHarper)

AuthorizedFTE

FloatFTP

41 5

G5300

0

FloatStudent

0

FloatApprentice OH

0

P&CCraftsmanWB‐2610DavidPence(Mead)

Harold(Scott)Gettinger(Phoenix)

ElectronicEquipmentCraftsmanWB‐2610DanaBurnham(Coolidge)ThomasMcElroy(Gila)RichardPotter(Mead)

ThomasBurhyte(Phoenix)


ENGINEERING & CONSTRUCTIONG5600

Engineering & Construction Manager GS-301-14 Gary Lachvayder

Realty Specialist GS-1170-11 Joey James Giustino Vice: Baumgardt

Electrical Engineering Technician GS-802-11 Kelvin Ellis

Field ConstructionG5610

Lead Civil Engineer GS-810-13 Robert Toenjes

Electrical Engineer GS-850-13 Vacant Vice: Toenjes Gerald Hartill

Civil Engineer GS-810-12 Brent Allen Vacant Vice: Albarran-Garcia

Construction Representative GS-809-12 James Jennings

Construction Representative GS-809-11 Lawrence Merchant George McIlveen Edward Stoll F Michael Fyffe

Office ConstructionG5620

Lead Civil Engineer GS-810-13 Roger Moody

Civil Engineer GS-801-13 David Pflanz

Civil Engineer GS-810-12 Jason White Curtis Williams Vacant Vice: Pflanz

Civil Engineering Technician GS-802-11 Richard Duarte Rick Schuler Electrical Engineer GS-850-13 Omar Cobos

Electrical Engineer GS-850-12 Jorge Alva

EngineeringG5630

Engineer Team Lead GS-801-13 Donald Byron

Project Manager GS-301-13 Michael Garcia Michael Baird F Vacant Vice: Mueller Vacant Vice: Rhoades Project Manager GS-801-13 Roger Wright

AuthorizedFTE

FloatFTP

27 2

G5600

--

FloatStudent

OH

0

DESERT SOUTHWEST REGIONMay 1, 2017

POWER MARKETINGG6000

Vice President of Power Marketing for Desert Southwest Region GS-340-15 Jack Murray

Public Utilities Spec (Tech Expert) GS-1130-14 Michael Simonton

RatesG6100

Supervisory Public Utilities Spec GS-1130-14 Scott Lund

Public Utilities Spec GS-1130-13 Florence Brooks Todd Statler Financial Program Analyst GS-501-13 Sandra Jacobs

Public Utilities Spec GS-1130-12 Christina Vides Kevin Schaefer Ebony Dennis

Financial Program Analyst GS-501-12 Charis Schaeffer

Public Utilities Technician GS-1101-7 James Moore

Power Contracts & Energy ServicesG6200

Supervisory Public Utilities Spec GS-1130-14 Patricia Weeks

General Engineer GS-801-13 Hoai Nam Le Ryan Nicholson

Public Utilities Spec GS-1130-13 Audrey Colletti Vacant Vice: Weeks Public Utilities Spec GS-1130-12 Kathryn Sheets Tasha May Troy Stine

Resource Planning and SettlementsG6300

Supervisory Public Utilities Spec GS-1130-14 Tina Ramsey

General Engineer GS-801-13 Xavier Gonzalez

Operations Support Spec GS-301-13 William Beenau

Public Utilities Spec (Metering) GS-1130-13 Stephen Paquette

Public Utilities Spec GS-1130-13 Rose Statler

Public Utilities Spec GS-1130-12 Melissa Cody Laura Ramirez Lonnie Waters Vacant: New

G6000

AuthorizedFTE

FloatFTP

28 0

FloatStudent

0G6000

G6300

G6200

G6100

2

9

0 9

0

0

8

0

0

Total 0

OH

0

0

0

0

0

0

0


FINANCIAL MANAGEMENTG8000

Financial Manager GS-505-14 Ethel Redhair

Budget & Alternative FinanceG8100

Supervisory Budget Analyst GS560-13 Anthony Camp

Budget Analyst GS-560-12 Andrew Pierce Richard Metcalf Robbin Rinker Cherie Cottrell F

Financial Program Analyst GS-501-12 Mark Krause

AccountingG8200

Supervisory Accountant GS-510-13 A. Beth Kozik

Accountant GS-510-12 Gregory Gonzales Kristi Beshaw Paul Hill Chenguang Wang Shannon Joya Accountant GS-510-9/11/12 Dawn Hanby F

Public Utilities Specialist GS-1130-12 Charis Schaefer Tamara Densmore Public Utilities Specialist GS-1130-11 Dawn Hanby Beatrice Brown Herder

G8000

AuthorizedFTE

FloatFTP

16 0

FloatStudent

0G8000

G8200

G8100

1

5

0

0

10

0

Total 0

OH

0

0

0

2

1

1

Documents

DESERT SOUTHWEST REGION TEN-YEAR PLAN Customer … · 1 desert southwest region ten-year plan customer preview meeting fiscal year 2018-2027 mid-cycle customer meeting: june 7, 2017